10-Q

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, 2024
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 Two North Ninth Street Allentown, PA 18101-1179 (610) 774-5151	23-2758192
1-905	PPL Electric Utilities Corporation (Exact name of Registrant as specified in its charter) Pennsylvania Two North Ninth Street Allentown, PA 18101-1179 (610) 774-5151	23-0959590
1-2893	Louisville Gas and Electric Company (Exact name of Registrant as specified in its charter) Kentucky 220 West Main Street Louisville, KY 40202-1377 (502) 627-2000	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

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	☒

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, 737,740,859 shares outstanding at April 26, 2024.

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 26, 2024.

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 26, 2024.

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 26, 2024.

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.

PPL CORPORATION

PPL ELECTRIC UTILITIES CORPORATION

LOUISVILLE GAS AND ELECTRIC COMPANY

KENTUCKY UTILITIES COMPANY

FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2024

Table of Contents

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	4
			Condensed Consolidated Statements of Comprehensive Income	5
			Condensed Consolidated Statements of Cash Flows	6
			Condensed Consolidated Balance Sheets	7
			Condensed Consolidated Statements of Equity	9
		PPL Electric Utilities Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	11
			Condensed Consolidated Statements of Cash Flows	12
			Condensed Consolidated Balance Sheets	13
			Condensed Consolidated Statements of Equity	15
		Louisville Gas and Electric Company
			Condensed Statements of Income	17
			Condensed Statements of Cash Flows	18
			Condensed Balance Sheets	19
			Condensed Statements of Equity	21
		Kentucky Utilities Company
			Condensed Statements of Income	23
			Condensed Statements of Cash Flows	24
			Condensed Balance Sheets	25
			Condensed Statements of Equity	27

	Combined Notes to Condensed Financial Statements (Unaudited)
		Index to Combined Notes to Condensed Financial Statements		28
		1.   Interim Financial Statements		28
		2.   Segment and Related Information		29
		3.   Revenue from Contracts with Customers		30
		4.   Earnings Per Share		32
		5.   Income Taxes		32
		6.   Utility Rate Regulation		34
		7.   Financing Activities		40
		8.   Acquisitions, Developments and Divestitures		41
		9.   Defined Benefits		42
		10. Commitments and Contingencies		43
		11. Related Party Transactions		48
		12. Other Income (Expense) - net		49
		13. Fair Value Measurements		49
		14. Derivative Instruments and Hedging Activities		52
		15. Asset Retirement Obligations		58
		16. Accumulated Other Comprehensive Income (Loss)		59
		17. New Accounting Guidance Pending Adoption		59
	Item 2.  Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		61
			Introduction	61
			Business Strategy	63
			Financial and Operational Developments	63
		Results of Operations		65
			PPL Corporation and Subsidiaries - Statement of Income Analysis and Segment Earnings	66
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis	73
			Louisville Gas and Electric Company - Statement of Income Analysis	74
			Kentucky Utilities Company - Statement of Income Analysis	75
		Financial Condition		76
			Liquidity and Capital Resources	76
			Risk Management	80
			Related Party Transactions	82
			Acquisitions, Development and Divestitures	82
			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

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

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.

RIE - Rhode Island Energy, the name under which Narragansett Electric continues to provide services since its acquisition by PPL and its subsidiary, PPL Rhode Island Holdings on May 25, 2022.

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Other terms and abbreviations

£ - British pound sterling.

2023 Form 10-K - Annual Report to the SEC on Form 10-K for the year ended December 31, 2023.

Act 11 - Act 11 of 2012 that became effective in April 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.

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.

COVID-19 - the disease caused by the novel coronavirus identified in 2019 that caused a global pandemic.

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.

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.

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 198 MW and 442 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.

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.

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

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.

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PP&E - property, plant and equipment.

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.

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.

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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 2023 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:

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

•pandemic health events or other catastrophic events such as fires, 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;

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

•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;

•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;

•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 and their subsidiaries and the energy industry;

•our ability to attract and retain qualified employees;

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

•the effect of any business or industry restructuring;

•development of new projects, markets and technologies;

•performance of new ventures;

•collective labor bargaining negotiations and labor costs;

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•risks related to wildfires, including costs of potential regulatory penalties 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,
	2024		2023
Operating Revenues	$	2,304	$	2,415
Operating Expenses
Operation
Fuel	209		201
Energy purchases	520		734
Other operation and maintenance	626		559
Depreciation	316		313
Taxes, other than income	88		110
Total Operating Expenses	1,759		1,917
Operating Income	545		498
Other Income (Expense) - net (Note 12)	22		30
Interest Expense	179		164
Income Before Income Taxes	388		364
Income Taxes	81		79
Net Income	$	307	$	285
Earnings Per Share of Common Stock:
Basic and Diluted
Net Income Available to PPL Common Shareowners	$	0.42	$	0.39
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	737,512		736,829
Diluted	738,820		737,698

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

4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Net income	$	307	$	285
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		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		1
Comprehensive income	$	309	$	286

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

5

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Cash Flows from Operating Activities
Net income	$	307	$	285
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	316		313
Amortization	24		17
Defined benefit plans - (income) expense	(15)		(18)
Deferred income taxes and investment tax credits	72		77
Other	3		8
Change in current assets and current liabilities
Accounts receivable	(75)		(94)
Accounts payable	(221)		(63)
Unbilled revenues	57		109
Fuel, materials and supplies	33		10
Prepayments	(108)		(83)
Taxes payable	(47)		(42)
Regulatory assets and liabilities, net	(61)		(46)
Accrued interest	90		67
Other	(103)		(14)
Other operating activities
Defined benefit plans - funding	(5)		(3)
Other assets	(1)		(61)
Other liabilities	16		(32)
Net cash provided by operating activities	282		430
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(596)		(499)
Other investing activities	5		(4)
Net cash used in investing activities	(591)		(503)
Cash Flows from Financing Activities
Issuance of long-term debt	1,148		3,127
Retirement of long-term debt	—		(1,750)
Payment of common stock dividends	(177)		(171)
Net increase (decrease) in short-term debt	(701)		(985)
Other financing activities	(22)		(44)
Net cash provided by financing activities	248		177
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(61)		104
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	382		357
Cash, Cash Equivalents and Restricted Cash at End of Period	$	321	$	461
Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	253	$	257

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, 2024		December 31, 2023
Assets
Current Assets
Cash and cash equivalents	$	276	$	331
Accounts receivable (less reserve: 2024, $146; 2023, $123)
Customer	999		950
Other	271		271
Unbilled revenues (less reserve: 2024, $4; 2023, $4)	371		428
Fuel, materials and supplies	477		505
Prepayments	212		103
Regulatory assets	330		293
Other current assets	101		51
Total Current Assets	3,037		2,932
Property, Plant and Equipment
Regulated utility plant	39,031		38,608
Less:  accumulated depreciation - regulated utility plant	9,327		9,156
Regulated utility plant, net	29,704		29,452
Non-regulated property, plant and equipment	71		72
Less:  accumulated depreciation - non-regulated property, plant and equipment	24		23
Non-regulated property, plant and equipment, net	47		49
Construction work in progress	1,996		1,917
Property, Plant and Equipment, net	31,747		31,418
Other Noncurrent Assets
Regulatory assets	1,859		1,874
Goodwill	2,247		2,247
Other intangibles	304		306
Other noncurrent assets (less reserve for accounts receivable: 2024, $3; 2023 $2)	437		459
Total Other Noncurrent Assets	4,847		4,886
Total Assets	$	39,631	$	39,236

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

7

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Liabilities and Equity
Current Liabilities
Short-term debt	$	291	$	992
Long-term debt due within one year	1		1
Accounts payable	903		1,104
Taxes	83		130
Interest	214		124
Dividends	186		173
Regulatory liabilities	223		225
Other current liabilities	474		591
Total Current Liabilities	2,375		3,340
Long-term Debt	15,753		14,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	3,195		3,105
Investment tax credits	113		114
Accrued pension obligations	255		275
Asset retirement obligations	127		133
Regulatory liabilities	3,351		3,340
Other deferred credits and noncurrent liabilities	404		385
Total Deferred Credits and Other Noncurrent Liabilities	7,445		7,352
Commitments and Contingent Liabilities (Notes 6 and 10)
Equity
Common stock - $0.01 par value (a)	8		8
Additional paid-in capital	12,314		12,326
Treasury stock	(931)		(948)
Earnings reinvested	2,828		2,710
Accumulated other comprehensive loss	(161)		(163)
Total Equity	14,058		13,933
Total Liabilities and Equity	$	39,631	$	39,236

(a)1,560,000 shares authorized, 770,013 shares issued and 737,736 shares outstanding at March 31, 2024. 1,560,000 shares authorized, 770,013 shares issued and 737,130 shares outstanding at December 31, 2023.

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

8

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		Noncontrolling interests		Total
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
December 31, 2022	736,487	$	8	$	12,317	$	(967)	$	2,681	$	(124)	$	3	$	13,918
Treasury stock issued	580			2		17								19
Stock-based compensation				(9)										(9)
Net income								285						285
Dividends and dividend equivalents (b)								(178)						(178)
Other comprehensive income (loss)										1				1
March 31, 2023	737,067	$	8	$	12,310	$	(950)	$	2,788	$	(123)	$	3	$	14,036

(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 $0.2575 for the three months ended March 31, 2024 and $0.2400 for the three months ended March 31, 2023.

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

9

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10

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Operating Revenues	$	770	$	891
Operating Expenses
Operation
Energy purchases	214		358
Other operation and maintenance	181		162
Depreciation	99		99
Taxes, other than income	36		44
Total Operating Expenses	530		663
Operating Income	240		228
Other Income (Expense) - net (Note 12)	9		12
Interest Income from Affiliate	10		—
Interest Expense	62		57
Income Before Income Taxes	197		183
Income Taxes	48		45
Net Income (a)	$	149	$	138

(a)Net income equals comprehensive income.

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

11

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Cash Flows from Operating Activities
Net income	$	149	$	138
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	99		99
Amortization	12		9
Defined benefit plans - expense (income)	(11)		(10)
Deferred income taxes and investment tax credits	32		26
Other	(7)		(5)
Change in current assets and current liabilities
Accounts receivable	(33)		(115)
Accounts payable	(59)		30
Unbilled revenues	30		20
Materials and supplies	(4)		(17)
Prepayments	(110)		(77)
Regulatory assets and liabilities, net	(28)		(12)
Taxes payable	(48)		(36)
Accrued interest	35		15
Other	(26)		17
Other operating activities
Defined benefit plans - funding	(1)		(1)
Other assets	—		(22)
Other liabilities	(2)		(20)
Net cash provided by operating activities	28		39
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(229)		(155)
Expenditures for intangible assets	(1)		(1)
Notes receivable from affiliates	(554)		—
Other investing activities	4		—
Net cash used in investing activities	(780)		(156)
Cash Flows from Financing Activities
Issuance of long-term debt	649		1,329
Retirement of long-term debt	—		(1,150)
Contributions from parent	675		200
Payment of common stock dividends to parent	(88)		(74)
Net decrease in short-term debt	(509)		(145)
Debt issuance costs	(5)		(12)
Net cash provided by (used in) financing activities	722		148
Net Increase in Cash, Cash Equivalents and Restricted Cash	(30)		31
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	51		25
Cash, Cash Equivalents and Restricted Cash at End of Period	$	21	$	56
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	146	$	142

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

12

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Assets
Current Assets
Cash and cash equivalents	$	21	$	51
Accounts receivable (less reserve: 2024, $57; 2023, $46)
Customer	450		434
Other	10		8
Accounts receivable from affiliates	10		10
Notes receivable from affiliate	554		—
Unbilled revenues (less reserve: 2024, $2; 2023, $2)	119		149
Materials and supplies	103		99
Prepayments	155		44
Regulatory assets	84		57
Other current assets	33		17
Total Current Assets	1,539		869
Property, Plant and Equipment
Regulated utility plant	15,740		15,575
Less: accumulated depreciation - regulated utility plant	3,889		3,822
Regulated utility plant, net	11,851		11,753
Construction work in progress	744		680
Property, Plant and Equipment, net	12,595		12,433
Other Noncurrent Assets
Regulatory assets	592		598
Intangibles	269		269
Other noncurrent assets (less reserve for accounts receivable: 2024, $3; 2023, $2)	121		125
Total Other Noncurrent Assets	982		992
Total Assets	$	15,116	$	14,294

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

13

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Liabilities and Equity
Current Liabilities
Short-term debt	$	—	$	509
Accounts payable	404		454
Accounts payable to affiliates	52		44
Taxes	3		51
Interest	78		43
Regulatory liabilities	90		91
Other current liabilities	82		100
Total Current Liabilities	709		1,292
Long-term Debt	5,211		4,567
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,608		1,573
Regulatory liabilities	839		836
Other deferred credits and noncurrent liabilities	110		123
Total Deferred Credits and Other Noncurrent Liabilities	2,557		2,532
Commitments and Contingent Liabilities (Notes 6 and 10)
Equity
Common stock - no par value (a)	364		364
Additional paid-in capital	4,715		4,040
Earnings reinvested	1,560		1,499
Total Equity	6,639		5,903
Total Liabilities and Equity	$	15,116	$	14,294

(a)170,000 shares authorized; 66,368 shares issued and outstanding at March 31, 2024 and December 31, 2023.

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

14

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, 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
December 31, 2022	66,368	$	364	$	4,084	$	1,303	$	5,751
Net income						138		138
Capital contributions from parent				200				200
Dividends declared						(74)		(74)
March 31, 2023	66,368	$	364	$	4,284	$	1,367	$	6,015

(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.

15

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16

CONDENSED STATEMENTS OF INCOME

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Operating Revenues
Retail and wholesale	$	460	$	461
Electric revenue from affiliate	16		13
Total Operating Revenues	476		474
Operating Expenses
Operation
Fuel	86		79
Energy purchases	71		84
Energy purchases from affiliate	1		1
Other operation and maintenance	88		91
Depreciation	76		75
Taxes, other than income	13		12
Total Operating Expenses	335		342
Operating Income	141		132
Other Income (Expense) - net	2		2
Interest Expense	26		25
Income Before Income Taxes	117		109
Income Taxes	24		23
Net Income (a)	$	93	$	86

(a)Net income equals comprehensive income.

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

17

CONDENSED STATEMENTS OF CASH FLOWS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Cash Flows from Operating Activities
Net income	$	93	$	86
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	76		75
Amortization	3		3
Defined benefit plans - expense (income)	1		—
Deferred income taxes and investment tax credits	2		—
Change in current assets and current liabilities
Accounts receivable	(19)		28
Accounts receivable from affiliates	(11)		14
Accounts payable	6		(35)
Accounts payable to affiliates	34		31
Unbilled revenues	16		33
Fuel, materials and supplies	13		41
Regulatory assets and liabilities, net	(21)		21
Taxes payable	(26)		(27)
Accrued interest	23		18
Other	(19)		(11)
Other operating activities
Defined benefit plans - funding	(1)		—
Expenditures for asset retirement obligations	(2)		(2)
Other assets	—		(10)
Other liabilities	(2)		(1)
Net cash provided by operating activities	166		264
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(92)		(86)
Net increase in notes receivable with affiliates	(28)		(9)
Net cash used in investing activities	(120)		(95)
Cash Flows from Financing Activities
Issuance of long-term debt	—		399
Retirement of long-term debt	—		(300)
Net increase (decrease) in short-term debt	28		(179)
Payment of common stock dividends to parent	(37)		(31)
Return of capital to parent	(51)		(120)
Other financing activities	—		(3)
Net cash used in financing activities	(60)		(234)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(14)		(65)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	44		93
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	30	$	28
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	35	$	46

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

18

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Assets
Current Assets
Cash and cash equivalents	$	8	$	18
Accounts receivable (less reserve: 2024, $5; 2023, $6)
Customer	121		116
Other	24		17
Unbilled revenues (less reserve: 2024, $0; 2023, $0)	72		88
Accounts receivable from affiliates	40		29
Notes receivable from affiliates	28		—
Fuel, materials and supplies	130		143
Prepayments	11		11
Regulatory assets	14		7
Other current assets	6		—
Total Current Assets	454		429
Property, Plant and Equipment
Regulated utility plant	7,715		7,669
Less: accumulated depreciation - regulated utility plant	1,599		1,549
Regulated utility plant, net	6,116		6,120
Construction work in progress	342		312
Property, Plant and Equipment, net	6,458		6,432
Other Noncurrent Assets
Regulatory assets	388		395
Goodwill	389		389
Other intangibles	17		18
Other noncurrent assets	92		90
Total Other Noncurrent Assets	886		892
Total Assets	$	7,798	$	7,753

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

19

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Liabilities and Equity
Current Liabilities
Short-term debt	$	28	$	—
Accounts payable	121		115
Accounts payable to affiliates	83		49
Customer deposits	35		34
Taxes	15		41
Price risk management liabilities	1		1
Regulatory liabilities	2		16
Interest	44		21
Asset retirement obligations	13		13
Other current liabilities	32		47
Total Current Liabilities	374		337
Long-term Debt	2,469		2,469
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	782		776
Investment tax credits	30		31
Price risk management liabilities	4		6
Asset retirement obligations	71		72
Regulatory liabilities	824		827
Other deferred credits and noncurrent liabilities	67		63
Total Deferred Credits and Other Noncurrent Liabilities	1,778		1,775
Commitments and Contingent Liabilities (Notes 6 and 10)
Stockholder's Equity
Common stock - no par value (a)	424		424
Additional paid-in capital	1,942		1,993
Earnings reinvested	811		755
Total Equity	3,177		3,172
Total Liabilities and Equity	$	7,798	$	7,753

(a)75,000 shares authorized; 21,294 shares issued and outstanding at March 31, 2024 and December 31, 2023.

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

20

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, 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
December 31, 2022	21,294	$	424	$	2,087	$	655	$	3,166
Net income						86		86
Return of capital to parent				(120)				(120)
Dividends declared						(31)		(31)
March 31, 2023	21,294	$	424	$	1,967	$	710	$	3,101

(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.

21

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22

CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Operating Revenues
Retail and wholesale	$	524	$	498
Electric revenue from affiliate	1		1
Total Operating Revenues	525		499
Operating Expenses
Operation
Fuel	123		122
Energy purchases	6		6
Energy purchases from affiliate	16		13
Other operation and maintenance	102		109
Depreciation	99		98
Taxes, other than income	12		10
Total Operating Expenses	358		358
Operating Income	167		141
Other Income (Expense) - net	2		2
Interest Expense	34		33
Income Before Income Taxes	135		110
Income Taxes	27		22
Net Income (a)	$	108	$	88

(a)Net income equals comprehensive income.

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

23

CONDENSED STATEMENTS OF CASH FLOWS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2024		2023
Cash Flows from Operating Activities
Net income	$	108	$	88
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	99		98
Amortization	5		5
Defined benefit plans - (income)	(1)		—
Deferred income taxes and investment tax credits	(1)		(1)
Other	(1)		(1)
Change in current assets and current liabilities
Accounts receivable	(21)		16
Accounts payable	(13)		(16)
Accounts payable to affiliates	52		2
Unbilled revenues	6		25
Fuel, materials and supplies	8		(8)
Regulatory assets and liabilities, net	1		8
Taxes payable	(17)		(11)
Accrued interest	32		26
Other	(7)		2
Other operating activities
Defined benefit plans - funding	(1)		—
Expenditures for asset retirement obligations	(2)		(5)
Other assets	8		(13)
Other liabilities	(3)		(1)
Net cash provided by operating activities	252		214
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(148)		(141)
Net cash used in investing activities	(148)		(141)
Cash Flows from Financing Activities
Net increase in notes payable to affiliates	37		9
Issuance of long-term debt	—		399
Retirement of long-term debt	—		(300)
Net decrease in short-term debt	(48)		(101)
Payment of common stock dividends to parent	(47)		(35)
Return of capital to parent	(50)		(54)
Other financing activities	—		(3)
Net cash used in financing activities	(108)		(85)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(4)		(12)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	38		21
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	34	$	9
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	44	$	60

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

24

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Assets
Current Assets
Cash and cash equivalents	$	12	$	14
Accounts receivable (less reserve: 2024, $3; 2023, $2)
Customer	152		143
Other	19		12
Unbilled revenues (less reserve: 2024, $0; 2023, $0)	91		97
Fuel, materials and supplies	177		185
Prepayments	11		13
Regulatory assets	7		3
Other current assets	2		1
Total Current Assets	471		468
Property, Plant and Equipment
Regulated utility plant	10,038		9,896
Less: accumulated depreciation - regulated utility plant	2,547		2,476
Regulated utility plant, net	7,491		7,420
Construction work in progress	594		604
Property, Plant and Equipment, net	8,085		8,024
Other Noncurrent Assets
Regulatory assets	435		439
Goodwill	607		607
Other intangibles	18		19
Other noncurrent assets	157		157
Total Other Noncurrent Assets	1,217		1,222
Total Assets	$	9,773	$	9,714

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

25

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2024		December 31, 2023
Liabilities and Equity
Current Liabilities
Short-term debt	$	45	$	93
Notes payable to affiliates	37		—
Accounts payable	70		80
Accounts payable to affiliates	123		72
Customer deposits	38		35
Taxes	15		32
Regulatory liabilities	6		1
Interest	56		24
Asset retirement obligations	16		13
Other current liabilities	44		52
Total Current Liabilities	450		402
Long-term Debt	3,064		3,064
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	917		912
Investment tax credits	83		83
Asset retirement obligations	48		53
Regulatory liabilities	1,016		1,018
Other deferred credits and noncurrent liabilities	32		30
Total Deferred Credits and Other Noncurrent Liabilities	2,096		2,096
Commitments and Contingent Liabilities (Notes 6 and 10)
Stockholder's Equity
Common stock - no par value (a)	308		308
Additional paid-in capital	2,983		3,033
Earnings reinvested	872		811
Total Equity	4,163		4,152
Total Liabilities and Equity	$	9,773	$	9,714

(a)80,000 shares authorized; 37,818 shares issued and outstanding at March 31, 2024 and December 31, 2023.

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

26

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, 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
December 31, 2022	37,818	$	308	$	3,041	$	689	$	4,038
Net income						88		88
Return of capital to parent				(54)				(54)
Dividends declared						(35)		(35)
March 31, 2023	37,818	$	308	$	2,987	$	742	$	4,037

(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.

27

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		x	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, 2023 is derived from that Registrant's 2023 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 2023 Form 10-K. The results of operations for the three months ended March 31, 2024 are not necessarily indicative of the results to be expected for the full year ending December 31, 2024 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: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated. PPL's segments are determined by geographic location.

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

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

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

"Corporate and Other" primarily includes corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results.

Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended March 31 are as follows:

	Three Months
	2024		2023
Operating Revenues from external customers
Kentucky Regulated	$	984	$	960
Pennsylvania Regulated	770		891
Rhode Island Regulated	549		565
Corporate and Other	1		(1)
Total	$	2,304	$	2,415
Net Income (Loss)
Kentucky Regulated	$	190	$	166
Pennsylvania Regulated	149		138
Rhode Island Regulated	64		54
Corporate and Other	(96)		(73)
Total	$	307	$	285

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

	March 31, 2024		December 31, 2023
Assets
Kentucky Regulated	$	17,074	$	17,029
Pennsylvania Regulated	15,116		14,294
Rhode Island Regulated	6,614		6,515
Corporate and Other (a)	827		1,398
Total	$	39,631	$	39,236

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

(PPL Electric, LG&E and KU)

PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment. Each of LG&E and KU operate as a single operating and reportable segment.

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3. Revenue from Contracts with Customers

(All Registrants)

See Note 3 in the Registrants' 2023 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.

	2024 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)	$	2,304	$	770	$	476	$	525
Revenues derived from:
Alternative revenue programs (b)	7		(3)		2		5
Other (c)	(8)		(5)		(1)		(1)
Revenues from Contracts with Customers	$	2,303	$	762	$	477	$	529
	2023 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)	$	2,415	$	891	$	474	$	499
Revenues derived from:
Alternative revenue programs (b)	36		1		1		—
Other (c)	(4)		(2)		(1)		(1)
Revenues from Contracts with Customers	$	2,447	$	890	$	474	$	498

(a)PPL includes $549 million for the three months ended March 31, 2024 and $565 million for the three months ended March 31, 2023 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)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.

(c)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
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
2023
PA Regulated	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
KY Regulated	443		274		164		60		7		11		—		959
RI Regulated	229		101		9		215		—		—		45		599
Corp and Other	—		—		—		(1)		—		—		—		(1)
Total PPL	$	1,209	$	503	$	193	$	287	$	7	$	11	$	237	$	2,447

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	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL Electric
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
2023	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
LG&E
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
2023	$	241	$	152	$	49	$	16	$	—	$	16	$	—	$	474
KU
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529
2023	$	202	$	123	$	115	$	44	$	7	$	7	$	—	$	498

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. 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.

As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location 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
	2024		2023
PPL (a)	$	42	$	21
PPL Electric (a)	28		10
LG&E	1		1
KU	1		—

(a)    2024 includes amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information.

The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers.

	PPL		PPL Electric		LG&E		KU
Contract liabilities at December 31, 2023	$	43	$	29	$	6	$	7
Contract liabilities at March 31, 2024	30		20		5		5
Revenue recognized during the three months ended March 31, 2024 that was included in the contract liability balance at December 31, 2023	25		11		6		7
Contract liabilities at December 31, 2022	$	34	$	23	$	5	$	6
Contract liabilities at March 31, 2023	46		35		5		5
Revenue recognized during the three months ended March 31, 2023 that was included in the contract liability balance at December 31, 2022	17		6		5		6

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.

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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.

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
	2024		2023
Income (Numerator)
Net income attributable to PPL	$	307	$	285
Less amounts allocated to participating securities	—		1
Net income available to PPL common shareowners - Basic and Diluted	$	307	$	284
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	737,512		736,829
Add: Dilutive share-based payment awards (a)	1,308		869
Weighted-average shares - Diluted EPS	738,820		737,698
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.42	$	0.39

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

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
	2024	2023
Stock-based compensation awards	—	534

5. Income Taxes

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

(PPL)
	Three Months
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	81	$	76
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	17		22
Utility rate-making tax adjustments (a)	(5)		(5)
Amortization of excess deferred federal and state income taxes	(13)		(12)
Other	1		(2)
Total increase (decrease)	—		3
Total income tax expense (benefit)	$	81	$	79

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across all PPL utilities 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.

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(PPL Electric)
	Three Months
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	41	$	38
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14		14
Utility rate-making tax adjustments (a)	(4)		(4)
Amortization of excess deferred federal and state income taxes	(2)		(2)
Other	(1)		(1)
Total increase (decrease)	7		7
Total income tax expense (benefit)	$	48	$	45

(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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	25	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	4		4
Amortization of excess deferred federal and state income taxes	(3)		(3)
Other	(2)		(1)
Total increase (decrease)	(1)		—
Total income tax expense (benefit)	$	24	$	23

(KU)
	Three Months
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	28	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(5)		(4)
Other	(1)		(1)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	27	$	22

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.

Transfer of Certain Credits under the Inflation Reduction Act (PPL)

On April 25, 2024, the IRS released the final Internal Revenue Code Section 6418 regulations related to the transfer of certain credits under the Inflation Reduction Act. The regulations were published in the Federal Register on April 30, 2024, and will be effective on July 1, 2024. PPL is currently reviewing the final regulations to determine what impact the guidance may have on their financial statements.

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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, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Assets:
Rate adjustment mechanisms	$	129	$	118	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	15		14		—		—		—		—		—		—
Derivative instruments	29		51		—		—		—		—		—		—
Smart meter rider	6		6		6		6		—		—		—		—
Universal service rider	8		—		8		—		—		—		—		—
Storm damage costs	33		12		33		12		—		—		—		—
Gas supply clause	4		—		—		—		4		—		—		—
Fuel adjustment clause	12		4		—		—		6		3		6		—
Transmission service charge	36		43		26		31		—		—		—		—
Transmission formula rate	15		5		—		—		—		—		—		—
Distribution system improvement charge	8		7		8		7		—		—		—		—
Other	35		33		3		1		4		4		1		3
Total current regulatory assets	$	330	$	293	$	84	$	57	$	14	$	7	$	7	$	3
Noncurrent Regulatory Assets:
Defined benefit plans	$	880	$	887	$	417	$	417	$	212	$	217	$	134	$	136
Plant outage costs	36		38		—		—		9		10		27		28
Net metering	123		112		—		—		—		—		—		—
Environmental cost recovery	97		99		—		—		—		—		—		—
Storm costs	96		97		—		—		14		15		14		14
Unamortized loss on debt	22		22		3		3		10		10		7		7
Interest rate swaps	5		7		—		—		5		7		—		—
Terminated interest rate swaps	56		58		—		—		33		34		23		24
Accumulated cost of removal of utility plant	171		178		171		178		—		—		—		—
AROs	288		289		—		—		76		76		212		213
Derivatives instruments	4		8		—		—		—		—		—		—
Other	81		79		1		—		29		26		18		17
Total noncurrent regulatory assets	$	1,859	$	1,874	$	592	$	598	$	388	$	395	$	435	$	439

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	PPL				PPL Electric				LG&E				KU
	March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Liabilities:
Generation supply charge	$	64	$	51	$	64	$	51	$	—	$	—	$	—	$	—
Tax Cuts and Jobs Act customer refund	—		5		—		5		—		—		—		—
Act 129 compliance rider	12		15		12		15		—		—		—		—
Transmission formula rate	17		21		14		18		—		—		—		—
Rate adjustment mechanism	68		72		—		—		—		—		—		—
Energy efficiency	25		23		—		—		—		—		—		—
Gas supply clause	—		15		—		—		—		15		—		—
Other	37		23		—		2		2		1		6		1
Total current regulatory liabilities	$	223	$	225	$	90	$	91	$	2	$	16	$	6	$	1
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,008	$	996	$	—	$	—	$	309	$	306	$	402	$	399
Power purchase agreement - OVEC	16		19		—		—		11		13		5		6
Net deferred taxes	1,960		1,977		759		763		454		459		517		523
Defined benefit plans	256		252		80		73		20		20		60		59
Terminated interest rate swaps	56		57		—		—		28		29		28		28
Energy efficiency	18		5		—		—		—		—		—		—
Other	37		34		—		—		2		—		4		3
Total noncurrent regulatory liabilities	$	3,351	$	3,340	$	839	$	836	$	824	$	827	$	1,016	$	1,018

Regulatory Matters

Rhode Island Activities (PPL)

Rate Case Proceedings

Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC.

The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5.

Advanced Metering Functionality (AMF)

In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory.

35

On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters.

Grid Modernization

RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023, to discuss the scope of the RIPUC’s review of the GMP and its potential impact future electric ISR plans. RIE cannot predict the outcome of this matter.

Petition for Deferral of Credit Card Fees

On January 31, 2024, RIE filed a petition to request approval to recognize regulatory assets related to the credit card, debit card, and related fees (Electronic Transaction Fees) that RIE has waived and will continue to waive on a going forward basis pursuant to the RIPUC orders in RIPUC Docket No. 5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its next base distribution rate case for the amortization/recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. The Rhode Island Division of Public Utilities and Carriers (the Division) and Intervenor testimony is due two weeks following the filing of RIE's Revised 2022 Earnings Reports, which RIE intends to file in the second quarter of 2024. RIE's rebuttal testimony is due two weeks following the Division's filing of its testimony. No hearings have been scheduled at this time. RIE simultaneously filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges pending in Docket No. 5154. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter.

FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan

At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. The RIPUC has not taken any action to date on this issue, including in its recent action on the FY 2025 Gas ISR Plan.

FY 2024 Gas ISR Plan

At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below.

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FY 2025 Gas ISR Plan

On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), plus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

FY 2024 Electric ISR Plan

The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend.

On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below.

FY 2025 Electric ISR Plan

On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

Kentucky Activities (PPL, LG&E and KU)

KPSC Investigation Related to Winter Storm Elliott

On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties have been granted intervenor status for the proceeding and a hearing on the matter is scheduled for May 23, 2024. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition.

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Pennsylvania Activities (PPL and PPL Electric)

PAPUC investigation into billing issues

On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC’s Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric’s hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E have 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The final approval of the Settlement Agreement is pending the issuance of the PAPUC's order and PPL Electric and I&E's decision on whether to accept the modifications. PPL Electric cannot predict the outcome of this matter.

PPL Electric incurred costs related to the billing issues of $15 million and $3 million for the three-month periods ended March 31, 2024 and March 31, 2023. PPL Electric will not seek regulatory recovery of these costs.

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. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. PPL Electric cannot predict the outcome of this matter.

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 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 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 proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April

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24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. 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 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 a PAPUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three months ended March 31, 2024 and 2023, PPL Electric purchased $419 million and $358 million of accounts receivable from alternative suppliers.

(PPL)

In 2021 and 2022, the RIPUC approved various components of a Purchase of Receivables Program (POR) in Rhode Island for effect on April 1, 2022. Municipal aggregators and non-regulated power producers (collectively, Competitive Suppliers) are eligible to participate in accordance with RIE's approved electric tariffs for municipal aggregation and non-regulated power producers. Under the POR program, RIE will purchase the Competitive Suppliers' accounts receivables, including existing receivables, at discounted rates, regardless of whether RIE has collected the owed monies from customers. The program is intended to make RIE whole through the implementation of a discount rate or Standard Complete Bill Percentage (SCBP) paid by Competitive Suppliers. RIE calculates the SCBP for each customer class and files the calculations with the RIPUC for review and approval by February 15 of each year. At an Open Meeting on March 26, 2024, the RIPUC approved the SCBP for effect beginning on April 1, 2024, for a one-year period.

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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, 2024									December 31, 2023
	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. 2028	$	1,250	$	—	$	218	$	1,032	$	—	$	390
Bilateral Credit Facility	Feb. 2025	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2025	100		—		13		87		—		13
Total PPL Capital Funding Credit Facilities		$	1,450	$	—	$	231	$	1,219	$	—	$	403
PPL Electric
Syndicated Credit Facility	Dec. 2028	$	650	$	—	$	1	$	649	$	—	$	511
Total PPL Electric Credit Facilities		$	650	$	—	$	1	$	649	$	—	$	511
LG&E
Syndicated Credit Facility	Dec. 2028	$	500	$	—	$	28	$	472	$	—	$	—
Total LG&E Credit Facilities		$	500	$	—	$	28	$	472	$	—	$	—
KU
Syndicated Credit Facility	Dec. 2028	$	400	$	—	$	45	$	355	$	—	$	93
Total KU Credit Facilities		$	400	$	—	$	45	$	355	$	—	$	93

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

(b)The PPL Capital Funding $1.25 billion syndicated credit facility includes a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding at March 31, 2024. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At December 31, 2023, the borrowing sublimit for RIE was $250 million and a $1 billion sublimit for PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million 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.

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(All Registrants)

PPL Capital Funding, RIE, PPL Electric, LG&E and KU 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, 2024							December 31, 2023
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a) (b)	5.51%	$	1,350	$	218	$	1,132	5.66%	$	365
RIE (b)		400		—		400		5.72%	25
PPL Electric		650		—		650		5.67%	510
LG&E	5.49%	500		28		472			—
KU	5.49%	400		45		355		5.64%	93
Total		$	3,300	$	291	$	3,009		$	993

(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, which has a total capacity of $1.25 billion. At March 31, 2024, the borrowing sublimits were $400 million for RIE and $850 million for PPL Capital Funding. At December 31, 2023, the borrowing sublimits under the facility were $250 million at RIE and $1 billion at 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.

Long-term Debt

(PPL)

In March 2024, RIE issued $500 million of 5.35% Senior Notes due 2034. RIE received proceeds of $496 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes.

(PPL and PPL Electric)

In January 2024, PPL Electric issued $650 million of 4.85% First Mortgage Bonds due 2034. PPL Electric received proceeds of $644 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes.

Dividends

In February 2024, PPL declared a quarterly cash dividend on its common stock, payable April 1, 2024, of 25.75 cents per share (equivalent to $1.03 per annum).

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) for approximately $3.8 billion. Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE).

In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA and Narragansett Electric have entered into a transition services agreement (TSA), pursuant to which the National Grid entities have 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 is for an initial two-year

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term and certain aspects have been extended to the third quarter of 2024. TSA costs of $48 million and $58 million were incurred during the three months ended March 31, 2024 and 2023.

Commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island

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 2023 Form 10-K for a complete listing of those commitments. PPL incurred the following expenses related to some of the remaining commitments:

•RIE will 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) incurring costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $81 million and $54 million for the three months ended March 31, 2024 and 2023.

•RIE will not seek to recover in rates any markup charged by National Grid USA and/or its affiliates under the TSA which were $1 million and $2 million for the three months ended March 31, 2024 and 2023.

Developments (PPL, LG&E and KU)

Mill Creek Unit 5 Construction

In December 2022, LG&E and KU filed a Certificate of Public Convenience and Necessity (CPCN) with the KPSC requesting approval to construct a 640 MW net summer rating Natural Gas Combined Cycle (NGCC) combustion turbine at LG&E’s Mill Creek Generating Station. In November 2023, the KPSC issued an order approving the request as well as the requested AFUDC accounting treatment for associated financing costs relating to the NGCC. The new NGCC facility will be jointly owned by LG&E (31%) and KU (69%). In February 2024, LG&E and KU entered into agreements to begin construction. Total project costs are estimated at approximately $1.0 billion, including AFUDC. Commercial operation of the facility is anticipated to begin mid-2027.

See Note 7 in PPL's 2023 Form 10-K for additional information on the CPCN filing.

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
	2024		2023
PPL
Service cost	$	9	$	9
Interest cost	46		46
Expected return on plan assets	(75)		(78)
Amortization of:
Prior service cost	1		2
Actuarial loss	2		—
Net periodic defined benefit costs (credits)	$	(17)	$	(21)

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	Other Postretirement Benefits
	Three Months
	2024		2023
PPL
Service cost	$	1	$	2
Interest cost	7		7
Expected return on plan assets	(7)		(8)
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.

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.

On January 19, 2023, the Rhode Island Division of Public Utilities and Carriers (the Division) filed a motion to dismiss RIPUC Docket No. 22-05-EE without prejudice. As grounds for its motion, the Division stated that sufficient evidence exists in the docket to warrant an independent summary investigation by the Division, to include an audit of RIE. If the Division finds sufficient grounds, the Division may proceed to a formal hearing regarding the matters under investigation. Upon the conclusion of its investigation, the Division will provide the RIPUC with a report outlining the Division’s findings and final decision. On January 30, 2023, the Rhode Island Attorney General filed an objection to the Division’s motion to dismiss; RIE and National Grid USA each filed responses with the RIPUC requesting that any additional action taken by the RIPUC or the Division be considered after National Grid USA completes its internal investigation report, which National Grid USA filed with the RIPUC on March 10, 2023. On February 24, 2023, the Division initiated the independent summary investigation that it had referenced in its motion to dismiss. The RIPUC held a hearing on March 28, 2023 to hear oral arguments regarding the Division’s motion to dismiss and subsequently denied the motion. On November 27, 2023, the Division filed testimony recommending the RIPUC disallow a portion of the performance incentive awarded from 2012 through 2021. On January 19, 2024, the Division and the Rhode Island Attorney General filed their respective briefs recommending that the RIPUC assess financial penalties on the Company. The Division also recommended that the RIPUC consider further regulatory investigations and analysis within each of the energy efficiency dockets from 2012 through 2020, to confirm the accuracy of claimed savings and to document all conduct and actions that would trigger penalties. On April 2, 2024, the RIPUC issued an amended order that expressly expands the scope of the proceeding to address issues of accountability and the question of whether statutory penalties should be assessed against RIE relating to the manipulation of the reporting of invoices affecting the recovery of past shareholder incentives and the resulting impact on RIE’s customers. This proceeding remains open and, in parallel, the

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Division’s summary investigation remains ongoing. At this time, it is not possible to predict the final outcome or determine the total amount of any additional liabilities that may be incurred by RIE in connection with this matter or the Division’s summary investigation. RIE does not expect this matter will have a material adverse effect on its results of operations, financial position or cash flows.

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. Discussions between KU and the KEEC are ongoing.

Water/Waste (PPL, LG&E and KU)

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. Legal challenges to the final rule were consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. In October 2020, the EPA published final revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). On April 25, 2024, the EPA released a pre-publication version of 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. The final rule is currently under evaluation by PPL, LG&E, and KU, but could potentially result in significant operational changes and additional controls for LG&E and KU plants. 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. The CCR Rule imposes 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 July 2018, the EPA issued a final rule extending the deadline for closure of certain impoundments and adopting other substantive changes. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed certain deficiencies identified by the court and proposed amendments to change the closure deadline. In August 2020, the EPA published a final rule extending the deadline to initiate closure to April 11, 2021, while providing for certain extensions. PPL, LG&E, and KU are monitoring the EPA’s ongoing efforts to refine and implement the regulatory program under the CCR Rule. 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

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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 April 25, 2024, the EPA released a pre-publication version of a final rule establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities (legacy impoundments). The 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 PPL 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 management units that have previously completed remedial action and closure and certain beneficial use projects to additional federal regulatory requirements. 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 substantial. 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.

LG&E and KU received KPSC approval for a compliance plan 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.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 15 for additional information. Further 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.

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 coal gas manufacturing 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 coal gas manufacturing. 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 coal gas manufacturing 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, 2024 and December 31, 2023, PPL Electric had a recorded liability of $8 million, representing its best estimate of the probable loss incurred to remediate these sites.

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(PPL)

RIE is a potentially responsible party for a share of clean-up costs at certain sites including former manufactured gas plant (MGP) 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 MGP 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, 2024 and December 31, 2023, PPL had a recorded liability of $98 million and $99 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 from other 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 (TSA) released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that the TSA has determined to be critical. The TSA 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 TSA security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive, revised in July of 2023, requires refinement

46

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, 2024. "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, 2024			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	$	121	(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, a PPL indirect U.K. subsidiary, 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. Pursuant to the agreement, 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, pursuant to the agreement, subject to certain adjustments plus the support obligations provided by PPL under sale-leaseback financings.

(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 $86 million at March 31, 2024, consisting of LG&E's share of $60 million and KU's share of $26 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LG&E's and KU's 2023 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.

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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 coverage provides maximum aggregate coverage of $231 million. This insurance may be applicable to obligations under certain of these contractual arrangements.

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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, 2024, CEP Reserves had $554 million of borrowings outstanding. At December 31, 2023, CEP Reserves had no borrowings outstanding. 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 applicable 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, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be 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, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $37 million. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. At December 31, 2023, KU had no borrowings outstanding from LG&E and/or LKE.

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12. Other Income (Expense) - net

(PPL)

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

	Three Months
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	8	$	17
Interest income	9		9
AFUDC - equity component	9		6
Charitable contributions	(2)		(1)
Miscellaneous	(2)		(1)
Other Income (Expense) - net	$	22	$	30

(PPL Electric)

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

	Three Months
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	4	$	5
Interest income	1		4
AFUDC - equity component	5		4
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	9	$	12

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 2023 Form 10-K for information on the levels in the fair value hierarchy.

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Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

	March 31, 2024								December 31, 2023
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	276	$	276	$	—	$	—	$	331	$	331	$	—	$	—
Restricted cash and cash equivalents (a)	45		45		—		—		51		51		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	321		321		—		—		382		382		—		—
Special use funds (a):
Money market fund	2		2		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	7		—		—		—		9		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		2		—		—		18		1		—		—
Price risk management assets (d):
Gas contracts	1		—		1		—		1		—		1		—
Total assets	$	338	$	323	$	1	$	—	$	401	$	383	$	1	$	—
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Gas contracts	34		—		33		1		60		—		41		19
Total price risk management liabilities	$	39	$	—	$	38	$	1	$	67	$	—	$	48	$	19
PPL Electric
Assets
Cash and cash equivalents	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
Total assets	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	8	$	8	$	—	$	—	$	18	$	18	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		26		26		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	30		30		—		—		44		44		—		—
Total assets	$	30	$	30	$	—	$	—	$	44	$	44	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	14	$	14	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		24		24		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	34		34		—		—		38		38		—		—
Total assets	$	34	$	34	$	—	$	—	$	38	$	38	$	—	$	—

(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.

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(d)Current portion is included in "Other current asset" 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
2024
Balance at beginning of period	$	19
Settlements	(18)
Balance at end of period	$	1

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. 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 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 in 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, 2024				December 31, 2023
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	15,754	$	15,016	$	14,612	$	14,031
PPL Electric	5,211		5,023		4,567		4,475
LG&E	2,469		2,344		2,469		2,369
KU	3,064		2,832		3,064		2,861

(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 forward starting interest rate swaps to hedge changes 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 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. 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 a counterparty's credit ratings fall below investment grade, their tangible net worth falls below specified percentages or its 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, 2024 and December 31, 2023.

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, 2024.

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, 2024 and 2023, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At March 31, 2024, 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. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023. At March 31, 2024, 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, 2024, RIE held contracts with notional volumes of 41 Bcf that range in maturity from 2024 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 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 and certain RIE commodity gas contracts that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023.

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See Note 1 in each Registrant's 2023 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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	$	—	$	1	$	—	$	1
Gas contracts (a)	1		30		1		51
Total current	1		31		1		52
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	—		4		—		6
Gas contracts (a)	—		4		—		9
Total noncurrent	—		8		—		15
Total derivatives	$	1	$	39	$	1	$	67

(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, 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 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, 2023.

	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
Interest rate swaps	Interest expense	$	—
Gas contracts	Energy purchases	(2)
	Other income (expense) - net	1
	Total	$	(1)
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 assets - current	28
	Regulatory assets - noncurrent	(7)
	Total	$	20

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)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2023.

	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	$	164
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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	1
Total current	—		1		—		1
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		6
Total noncurrent	—		4		—		6
Total derivatives	$	—	$	5	$	—	$	7

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

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, 2023. 

	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)

(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, 2024
Derivatives
PPL	$	1	$	—	$	—	$	1	$	39	$	—	$	—	$	39
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, 2023
Derivatives
PPL	$	1	$	—	$	—	$	1	$	67	$	—	$	—	$	67
LG&E	—		—		—		—		7		—		—		7

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, such amounts would 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, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features was $28 million. At March 31, 2024, the aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $29 million.

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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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, 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)
December 31, 2022	$	3	$	2	$	(5)	$	(124)	$	(124)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		1		—		(1)		1
March 31, 2023	$	4	$	3	$	(5)	$	(125)	$	(123)

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	2024		2023		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.

17. New Accounting Guidance Pending Adoption

(All Registrants)

Improvements to Reportable Segment Disclosures

In November 2023, the FASB issued ASU 2023-07 which improves reportable segment disclosure requirements, primarily through enhanced disclosures about segment expenses. The standard also requires public entities to disclose the title and position of the Chief Operating Decision Maker (CODM) and explain how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. Disclosure of certain segment-related disclosures that previously were required only on an annual basis will be required in interim periods. In addition, public entities

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that have a single reportable segment are required to provide disclosures required by the new ASU and existing segment disclosure in Topic 280 (Segment Reporting).

For public business entities, this guidance will be applied retrospectively to all prior periods presented in the financial statements and will be effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted.

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

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.

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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' 2023 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, 2024 with the same period in 2023. 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 includes corporate level financing

62

costs, certain unallocated costs, and certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric.

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 to achieve industry-leading performance in safety, reliability, customer satisfaction and operational efficiency; to advance a clean energy transition while maintaining affordability and reliability; to maintain a strong financial foundation and create long-term value for our shareowners; to foster a diverse and exceptional workplace; and to build strong communities in areas that we serve.

Central to PPL's and the other Registrants' strategy is recovering capital project costs efficiently through various rate-making mechanisms, including periodic base rate case proceedings using forward test years, annual FERC formula rate mechanisms and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, in addition to FERC formula rates, the KPSC has adopted a series of regulatory mechanisms (ECR, DSM, GLT, fuel adjustment clause, and gas supply clause) and recovery on construction work-in-progress that reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs. In Pennsylvania, FERC formula rates, DSIC mechanism, Smart Meter Rider and other recovery mechanisms operate to reduce regulatory lag and provide for timely recovery of and a return on, as appropriate, prudently incurred costs. In Rhode Island, FERC formula rates, the gas cost adjustment, net metering, infrastructure, safety and reliability (ISR) and revenue decoupling mechanisms and other rate adjustment mechanisms operate to reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs.

Financial and Operational Developments

Transfer of Certain Credits under the Inflation Reduction Act (PPL)

On April 25, 2024, the IRS released the final Internal Revenue Code Section 6418 regulations related to the transfer of certain credits under the Inflation Reduction Act. The regulations were published in the Federal Register on April 30, 2024, and will be effective on July 1, 2024. PPL is currently reviewing the final regulations to determine what impact the guidance may have on their financial statements.

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 1,200 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, is expected to be retired in 2024. Mill Creek Unit 2, with 297 MW of capacity, is expected to be retired in 2027, subject to certain conditions. See Note 6 to the Financial Statements for additional information.

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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 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 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 proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April 24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. 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 2025 Gas ISR Plan

On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), plus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

FY 2025 Electric ISR Plan

On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

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Advanced Metering Functionality (AMF)

In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory.

On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters.

Rate Case Proceedings (KU)

On April 30, 2024, KU filed a request with the VSCC for an annual increase in Virginia base electricity rates of approximately $9 million. KU's request is based on an authorized 10.5 % return on equity. Subject to regulatory review and approval, new rates would become effective February 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. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. PPL Electric cannot predict the outcome of this matter.

Labor Union Agreements

(PPL)

Labor agreement negotiations with the Rhode Island UWUA commenced in March 2024. In April 2024, a tentative agreement was reached. A vote on the agreement has been scheduled and is currently expected to take place prior to the expiration of the contracts in May 2024. The current contracts cover over 530 employees. RIE cannot predict the outcome of this matter.

(PPL and KU)

In August 2023, KU and the IBEW local failed to reach agreement on an annual wage reopener under their existing labor agreement, which expires on August 1, 2024. The agreement covers approximately 60 employees. The parties are currently operating under the terms of a general wage increase unilaterally implemented by KU. The IBEW local has filed certain unfair labor practice claims with the U.S. Department of Labor and approved a strike authorization vote. KU expects to begin negotiating their new contract during July 2024, ahead of the August expiration.

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, 2024 with the same period in 2023. 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, 2024 with the same period in 2023.

(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
	2024		2023		$ Change
Operating Revenues	$	2,304	$	2,415	$	(111)
Operating Expenses
Operation
Fuel	209		201		8
Energy purchases	520		734		(214)
Other operation and maintenance	626		559		67
Depreciation	316		313		3
Taxes, other than income	88		110		(22)
Total Operating Expenses	1,759		1,917		(158)
Operating Income	545		498		47
Other Income (Expense) - net	22		30		(8)
Interest Expense	179		164		15
Income Before Income Taxes	388		364		24
Income Taxes	81		79		2
Net Income	$	307	$	285	$	22

Operating Revenues

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

	Three Months
PPL Electric distribution price (a)	$	3
PPL Electric distribution volume (b)	11
PPL Electric PLR (c)	(156)
PPL Electric transmission formula rate (d)	18
LG&E volumes (b)	12
LG&E fuel and other energy purchases (e)	(9)
KU volumes (b)	20
KU fuel and other energy purchases (f)	4
RIE energy purchases and other recoveries (g)	(36)
RIE capital investments	13
Other	9
Total	$	(111)

(a)The increase 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 2024 at PPL Electric.

66

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

(d)The increase was primarily due to returns on additional transmission capital investments and delayed implementation of moving to a calendar year rate in 2023, partially offset by the prior year point to point border rate settlement variance.

(e)The decrease was primarily due to lower recoveries of energy purchases, partially offset by higher recoveries of fuel expense.

(f)The increase was primarily due to higher recoveries of fuel and energy purchases due to higher commodity costs and volumes.

(g)The decrease was primarily due to lower recoveries of energy purchases and gross earnings tax, partially offset by higher recoveries of gas maintenance expenses.

Energy Purchases

Energy purchases decreased $214 million for the three months ended March 31, 2024 compared with 2023, primarily due to lower PLR prices of $108 million and lower PLR volumes of $33 million at PPL Electric, a decrease in commodity costs of $21 million at LG&E and a decrease in commodity costs of $57 million at RIE, partially offset by an increase in volumes of $7 million due to weather at LG&E.

Other Operation and Maintenance

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

	Three Months
PPL Electric bad debts	$	18
PPL Electric operations costs	(10)
RIE gas maintenance expense	45
RIE energy efficiency program expense	11
RIE pension expense	(10)
Transition costs associated with RIE	27
Other	(14)
Total	$	67

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)	$	(30)
Property tax expense	8
Total	$	(22)

(a)The decrease was primarily related to the RIE Gross Earnings Tax Holiday Credit.

Interest Expense

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

	Three Months
Long-term debt (a)	$	16
Other	(1)
Total	$	15

(a)    The increase was primarily due to increased borrowings. See Note 7 to the Financial Statements for additional information.

Segment Earnings

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

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	Three Months
	2024		2023		$ Change
Kentucky Regulated	$	190	$	166	$	24
Pennsylvania Regulated	149		138		11
Rhode Island Regulated	64		54		10
Corporate and Other (a)	(96)		(73)		(23)
Net Income (Loss)	$	307	$	285	$	22

(a)Primarily represents financing and certain other costs incurred at the corporate level that have not been allocated or assigned to the segments, which are presented to reconcile segment information to PPL's consolidated results.

Earnings from Ongoing Operations

Management utilizes "Earnings from Ongoing Operations" as a non-GAAP financial measure that should not be considered as an alternative to net income, an indicator of operating performance determined in accordance with GAAP. PPL believes that Earnings from Ongoing Operations is useful and meaningful to investors because it provides management's view of PPL's earnings performance as another criterion in making investment decisions. In addition, PPL's management uses Earnings from Ongoing Operations in measuring achievement of certain corporate performance goals, including targets for certain executive incentive compensation. Other companies may use different measures to present financial performance.

Earnings from Ongoing Operations is adjusted for the impact of special items. Special items are presented in the financial tables on an after-tax basis with the related income taxes on special items separately disclosed. Income taxes on special items, when applicable, are calculated based on the statutory tax rate of the entity where the activity is recorded. Special items may include items such as:

• Gains and losses on sales of assets not in the ordinary course of business.

• Impairment charges.

• Significant workforce reduction and other restructuring effects.

• Acquisition and divestiture-related adjustments.

• 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
	2024		2023		$ Change
Kentucky Regulated	$	191	$	167	$	24
Pennsylvania Regulated	161		137		24
Rhode Island Regulated	78		71		7
Corporate and Other	(28)		(23)		(5)
Earnings from Ongoing Operations	$	402	$	352	$	50

See "Reconciliation of Earnings from Ongoing Operations" below for a reconciliation of this non-GAAP financial measure to Net Income.

Kentucky Regulated Segment

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

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

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	Three Months
	2024		2023		$ Change
Operating Revenues	$	984	$	960	$	24
Fuel	209		201		8
Energy purchases	77		90		(13)
Other operation and maintenance	202		209		(7)
Depreciation	176		173		3
Taxes, other than income	25		23		2
Total operating expenses	689		696		(7)
Other Income (Expense) - net	3		3		—
Interest Expense	60		58		2
Income Taxes	48		43		5
Net Income	190		166		24
Less: Special Items	(1)		(1)		—
Earnings from Ongoing Operations	$	191	$	167	$	24

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
		2024		2023
Strategic corporate initiatives, net of tax of $0, $0 (a)	Other operation and maintenance	$	(1)	$	(1)
Total Special Items		$	(1)	$	(1)

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

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

	Three Months
Operating Revenues	$	24
Fuel	(8)
Energy purchases	13
Other operation and maintenance	7
Depreciation	(3)
Taxes, other than income	(2)
Other Income (Expense) - net	—
Interest Expense	(2)
Income Taxes	(5)
Earnings from Ongoing Operations	24
Special Items, after-tax	—
Net Income	$	24

•Higher operating revenues primarily due to an increase in sales volumes related to weather.

•Higher fuel expense primarily due to a $13 million increase in generation volumes primarily due to weather, partially offset by a $5 million decrease in commodity costs.

•Lower energy purchases primarily due to a $21 million decrease in commodity costs, partially offset by an $8 million increase in volumes primarily due to weather.

Pennsylvania Regulated Segment

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

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

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	Three Months
	2024		2023		$ Change
Operating Revenues	$	770	$	891	$	(121)
Energy purchases	214		358		(144)
Other operation and maintenance	181		162		19
Depreciation	99		99		—
Taxes, other than income	36		44		(8)
Total operating expenses	530		663		(133)
Other Income (Expense) - net	9		12		(3)
Interest Income from Affiliate	10		—		10
Interest Expense	62		57		5
Income Taxes	48		45		3
Net Income	149		138		11
Less: Special Items	(12)		1		(13)
Earnings from Ongoing Operations	$	161	$	137	$	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.

	Income Statement Line Item	Three Months
		2024		2023
PA tax rate change (a)	Income Taxes	$	—	$	1
PPL Electric billing issue, net of tax of $4 (b)	Other operation and maintenance	(11)		—
Strategic corporate initiatives, net of tax of $0 (c)	Other operation and maintenance	(1)		—
Total Special Items		$	(12)	$	1

(a)Impact of Pennsylvania state tax reform. See Note 5 to the Financial Statements for additional information.

(b)Certain expenses related to billing issues. See Note 6 to the Financial Statements for additional information.

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

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

	Three Months
Operating Revenues	$	(121)
Energy purchases	144
Other operation and maintenance	(3)
Depreciation	—
Taxes, other than income	8
Other Income (Expense) - net	(3)
Interest income from affiliate	10
Interest Expense	(5)
Income Taxes	(6)
Earnings from Ongoing Operations	24
Special Items, after-tax	(13)
Net Income	$	11

•Lower operating revenues primarily due to $156 million of lower PLR, partially offset by an $18 million increase in transmission formula rate returns and an $11 million increase in distribution volumes primarily due to weather and higher 2024 usage.

•Lower energy purchases primarily due to $108 million of lower PLR prices and $33 million of lower PLR volumes.

•Higher operation and maintenance expense primarily due to an $8 million increase in storm costs and a $5 million increase in vegetation management costs, partially offset by a $10 million decrease in operations costs.

•Lower taxes, other than income primarily due to lower gross receipts tax.

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•Higher interest income from affiliate primarily due to interest income on a short-term note receivable with an affiliated company.

Rhode Island Regulated Segment

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

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

	Three Months
	2024		2023		$ Change
Operating Revenues	$	549	$	565	$	(16)
Energy purchases	229		286		(57)
Other operation and maintenance	156		120		36
Depreciation	41		39		2
Taxes, other than income	27		43		(16)
Total operating expenses	453		488		(35)
Other Income (Expense) - net	7		10		(3)
Interest Expense	24		19		5
Income Taxes	15		14		1
Net Income	64		54		10
Less: Special Items	(14)		(17)		3
Earnings from Ongoing Operations	$	78	$	71	$	7

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
		2024		2023
Acquisition integration, net of tax of $4, $5 (a)	Other operation and maintenance	$	(14)	$	(17)
Total Special Items		$	(14)	$	(17)

(a)Primarily includes certain TSA costs for IT systems that will not be part of PPL's ongoing operations.

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

	Three Months
Operating Revenues	$	(16)
Energy purchases	57
Other operation and maintenance	(40)
Depreciation	(2)
Taxes, other than income	16
Other Income (Expense) - net	(3)
Interest Expense	(5)
Income Taxes	—
Earnings from Ongoing Operations	7
Special Items, after-tax	3
Net Income	$	10

•Lower operating revenues primarily due to a $57 million decrease in recovery of energy purchases, a $22 million decrease in recovery of gross earnings tax and a $10 million decrease in recovery of pension expenses, partially offset by a $45 million increase in recovery of gas maintenance expenses, a $13 million increase related to capital investments, an $11

71

million increase in recovery of energy efficiency program expenses and a $7 million increase related to transmission formula rates.

•Lower energy purchases primarily due to a decrease in commodity costs.

•Higher operation and maintenance expense primarily due to a $45 million increase in gas maintenance expenses and an $11 million increase in energy efficiency program expenses, partially offset by a $10 million decrease in pension expenses.

•Higher interest expense primarily due to increased short-term borrowings.

•Lower taxes, other than income primarily due to a $22 million decrease in gross earnings tax, partially offset by a $6 million increase in property tax.

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.

	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 TSA 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. See Note 6 to the Financial Statements for additional information.

	2023 Three Months
	KY Regulated		PA Regulated		RI Regulated		Corporate and Other		Total
Net Income (Loss)	$	166	$	138	$	54	$	(73)	$	285
Less: Special Items (expense) benefit:
Talen litigation costs, net of tax of $0 (a)	—		—		—		(1)		(1)
Strategic corporate initiatives, net of tax of $0, $0 (b)	(1)		—		—		(1)		(2)
Acquisition integration, net of tax of $5, $12 (c)	—		—		(17)		(44)		(61)
PA tax rate change (d)	—		1		—		—		1
Sale of Safari Holdings, net of tax of $0 (e)	—		—		—		(4)		(4)
Total Special Items	(1)		1		(17)		(50)		(67)
Earnings from Ongoing Operations	$	167	$	137	$	71	$	(23)	$	352

(a)PPL incurred legal expenses related to litigation with its former affiliate, Talen Montana.

(b)Costs incurred primarily in connection with corporate centralization efforts.

(c)Rhode Island Regulated primarily includes certain TSA 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.

(d)Impact of Pennsylvania state tax reform. See Note 5 to the Financial Statements for additional information.

(e)Final closing adjustments related to the sale of Safari Holdings.

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PPL Electric: Statement of Income Analysis

Statement of Income Analysis

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

	Three Months
	2024		2023		$ Change
Operating Revenues	$	770	$	891	$	(121)
Operating Expenses
Operation
Energy purchases	214		358		(144)
Other operation and maintenance	181		162		19
Depreciation	99		99		—
Taxes, other than income	36		44		(8)
Total Operating Expenses	530		663		(133)
Operating Income	240		228		12
Other Income (Expense) - net	9		12		(3)
Interest Income from Affiliate	10		—		10
Interest Expense	62		57		5
Income Before Income Taxes	197		183		14
Income Taxes	48		45		3
Net Income	$	149	$	138	$	11

Operating Revenues

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

	Three Months
Distribution price (a)	$	3
Distribution volume (b)	11
PLR (c)	(156)
Transmission formula rate (d)	18
Other	3
Total	$	(121)

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

(b)The increase was primarily due to weather and other higher usage in 2024.

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

(d)The increase was primarily due to returns on additional transmission capital investments and delayed implementation of moving to a calendar year rate in 2023, partially offset by the prior year point to point border rate settlement variance.

Energy Purchases

Energy purchases decreased $144 million for the three months ended March 31, 2024 compared with 2023, primarily due to lower PLR prices of $108 million and lower PLR volumes of $33 million.

Other Operation and Maintenance

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

	Three Months
Vegetation management expense	$	5
Storm costs	8
Operations costs	(10)
Bad debts	18
Other	(2)
Total	$	19

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Taxes, other than income

Taxes, other than income decreased $8 million for the three months ended March 31, 2024 compared with 2023, primarily due to lower gross receipts tax.

Interest Income from Affiliate

Interest income from affiliate increased $10 million for the three months ended March 31, 2024 compared with 2023, primarily due to interest income on a short-term note receivable with an affiliated company.

LG&E: Statement of Income Analysis

Statement of Income Analysis

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

	Three Months
	2024		2023		$ Change
Operating Revenues
Retail and wholesale	$	460	$	461	$	(1)
Electric revenue from affiliate	16		13		3
Total Operating Revenues	476		474		2
Operating Expenses
Operation
Fuel	86		79		7
Energy purchases	71		84		(13)
Energy purchases from affiliate	1		1		—
Other operation and maintenance	88		91		(3)
Depreciation	76		75		1
Taxes, other than income	13		12		1
Total Operating Expenses	335		342		(7)
Operating Income	141		132		9
Other Income (Expense) - net	2		2		—
Interest Expense	26		25		1
Income Before Income Taxes	117		109		8
Income Taxes	24		23		1
Net Income	$	93	$	86	$	7

Operating Revenues

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

	Three Months
Fuel and other energy purchases (a)	$	(6)
Volumes (b)	12
Other	(4)
Total	$	2

(a)The decrease was primarily due to lower recoveries of energy purchases, partially offset by higher recoveries of fuel expense.

(b)The increase was primarily due to weather.

Fuel

Fuel expense increased $7 million for the three months ended March 31, 2024 compared with 2023, primarily due to an increase in volumes due to weather.

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Energy Purchases

Energy purchases decreased $13 million for the three months ended March 31, 2024 compared with 2023, primarily due to a $21 million decrease in commodity costs, partially offset by a $7 million increase in volumes due to weather.

KU: Statement of Income Analysis

Statement of Income Analysis

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

	Three Months
	2024		2023		$ Change
Operating Revenues
Retail and wholesale	$	524	$	498	$	26
Electric revenue from affiliate	1		1		—
Total Operating Revenues	525		499		26
Operating Expenses
Operation
Fuel	123		122		1
Energy purchases	6		6		—
Energy purchases from affiliate	16		13		3
Other operation and maintenance	102		109		(7)
Depreciation	99		98		1
Taxes, other than income	12		10		2
Total Operating Expenses	358		358		—
Operating Income	167		141		26
Other Income (Expense) - net	2		2		—
Interest Expense	34		33		1
Income Before Income Taxes	135		110		25
Income Taxes	27		22		5
Net Income	$	108	$	88	$	20

Operating Revenues

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

	Three Months
Fuel and other energy purchases (a)	$	4
Volumes (b)	20
Other	2
Total	$	26

(a)The increase was primarily due to higher recoveries of fuel and energy purchases due to higher commodity costs and volumes.

(b)The increase was primarily due to weather.

Other Operation and Maintenance

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

	Three Months
Plant operations and maintenance	$	(3)
Other	(4)
Total	$	(7)

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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, 2024
Cash and cash equivalents	$	276	$	21	$	8	$	12
Short-term debt	291		—		28		45
Long-term debt due within one year	1		—		—		—
Notes payable to affiliates			—		—		37
December 31, 2023
Cash and cash equivalents	$	331	$	51	$	18	$	14
Short-term debt	992		509		—		93
Long-term debt due within one year	1		—		—		—
Notes payable to affiliates			—		—		—

(PPL)

The Statements of Cash Flows separately report the cash flows of discontinued operations. The "Operating Activities", "Investing Activities" and "Financing Activities" sections below include only the cash flows of continuing operations.

(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
2024
Operating activities	$	282	$	28	$	166	$	252
Investing activities	(591)		(780)		(120)		(148)
Financing activities	248		722		(60)		(108)
2023
Operating activities	$	430	$	39	$	264	$	214
Investing activities	(503)		(156)		(95)		(141)
Financing activities	177		148		(234)		(85)
Change - Cash Provided (Used)
Operating activities	$	(148)	$	(11)	$	(98)	$	38
Investing activities	(88)		(624)		(25)		(7)
Financing activities	71		574		174		(23)

Operating Activities

The components of the change in cash provided by (used in) operating activities for the three months ended March 31, 2024 compared with 2023 were as follows.

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	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Net income	$	22	$	11	$	7	$	20
Non-cash components	3		6		4		—
Working capital	(279)		(68)		(117)		(3)
Defined benefit plan funding	(2)		—		(1)		(1)
Other operating activities	108		40		9		22
Total	$	(148)	$	(11)	$	(98)	$	38

(PPL)

PPL's cash provided by operating activities in 2024 decreased $148 million compared with 2023.

•Net income increased $22 million between the periods and included an increase in non-cash charges of $3 million.

•The $279 million decrease in cash from changes in working capital was primarily due to a decrease in accounts payable and other current liabilities (primarily due to timing of payments) and an increase in unbilled revenues (primarily due to weather).

•The $108 million increase in cash provided by other operating activities was driven primarily by an increase in regulatory liabilities and a decrease in other assets (primarily related to a decrease in costs associated with work optimization and management projects).

(PPL Electric)

PPL Electric's cash provided by operating activities in 2024 decreased $11 million compared with 2023.

•Net income increased $11 million between the periods and included an increase in non-cash components of $6 million. The increase in non-cash components was primarily due to an increase in deferred income taxes and investment tax credits (primarily due to book versus tax plant timing differences).

•The $68 million decrease in cash from changes in working capital was primarily due to a decrease in accounts payable and other current liabilities and an increase in prepayments (primarily due to timing of payments), partially offset by a decrease in accounts receivable (primarily due to timing).

•The $40 million increase in cash provided by other operating activities was driven primarily by a decrease in other assets (primarily related to a decrease in costs associated with work optimization and management projects).

(LG&E)

LG&E's cash provided by operating activities in 2024 decreased $98 million compared with 2023.

•Net income increased $7 million between the periods and included an increase in non-cash components of $4 million.

•The $117 million decrease in cash from changes in working capital was primarily due to an increase in accounts receivable, unbilled revenues and fuel, materials and supplies (primarily due to weather), and an increase in net regulatory assets (primarily due to the timing of rate recovery mechanisms), partially offset by an increase in accounts payable (primarily due to timing of payments).

•The $9 million increase in cash provided by other operating activities was driven by an increase in other assets (primarily related to deferred storm costs recorded as noncurrent regulatory assets in the prior year).

(KU)

KU's cash provided by operating activities in 2024 increased $38 million compared with 2023.

•Net income increased $20 million between the periods. Non-cash components were consistent between periods.

•The $3 million decrease in cash from changes in working capital was primarily due to an increase in accounts receivable and unbilled revenues (primarily due to weather), an increase in net regulatory assets (primarily due to the

77

timing of rate recovery mechanisms), partially offset by an increase in accounts payable to affiliates (primarily due to timing of payments) and a decrease in fuel, materials and supplies (primarily due to weather).

•The $22 million increase in cash provided by other operating activities was driven by an increase in other assets (primarily related to deferred storm costs recorded as noncurrent regulatory assets in the prior year).

Investing Activities

(All Registrants)

The components of the change in cash provided by (used in) investing activities for the three months ended March 31, 2024 compared with 2023 were as follows.

	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Expenditures for PP&E	$	(97)	$	(74)	$	(6)	$	(7)
Notes receivable from affiliate	—		(554)		(19)		—
Other investing activities	9		4		—		—
Total	$	(88)	$	(624)	$	(25)	$	(7)

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 an increase in distribution projects.

For PPL Electric, the change in "Notes receivable from affiliate" activity resulted from the funding of $554 million to 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, 2024 compared with 2023 were as follows.

	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	(229)	$	470	$	(99)	$	(99)
Dividends	(6)		(14)		(6)		(12)
Capital contributions/distributions, net	—		475		69		4
Change in short-term debt, net	284		(364)		207		53
Net increase (decrease) in notes payable with affiliate	—		—		—		28
Other financing activities	22		7		3		3
Total	$	71	$	574	$	174	$	(23)

See Note 7 to the Financial Statements in this Form 10-Q for information on 2024 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 8 to the Financial Statements in the Registrants' 2023 Form 10-K for information on 2023 activity.

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, 2024, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:

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External 

	Committed Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity
PPL Capital Funding Credit Facilities (a)	$	1,350	$	—	$	218	$	1,132
PPL Electric Credit Facility	650		—		1		649
LG&E Credit Facilities	500		—		28		472
KU Credit Facilities	400		—		45		355
Total Credit Facilities (b)	$	2,900	$	—	$	292	$	2,608

(a)Includes a $1.25 billion syndicated credit facility with a $400 million borrowing sublimit for RIE and a $850 million 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 $1.25 billion available under the facility allocated to PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million 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 - 9%, 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	$	—	$	28	$	722
KU Money Pool (a)	650		37		45		568

(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, 2024:

	Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding (a)	$	1,350	$	218	$	1,132
Rhode Island Energy (a)	400		—		400
PPL Electric	650		—		650
LG&E	500		28		472
KU	400		45		355
Total PPL	$	3,300	$	291	$	3,009

(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 $1.25 billion, currently with a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding. PPL Capital Funding's Commercial paper program is also backed by a separate bilateral credit facility for $100 million.

Long-term Debt (All Registrants)

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

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Forecasted Uses of Cash (PPL)

Common Stock Dividends

In February 2024, PPL declared a quarterly common stock dividend, payable April 1, 2024, of 25.75 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 Contingent Features," including a discussion of the potential additional collateral requirements for PPL for derivative contracts in a net liability position at March 31, 2024.

(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' 2023 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.

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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, 2024.

	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, 2024 is shown below.

	10% Adverse Movement in Rates on Fair Value of Debt
PPL	$	630
PPL Electric	271
LG&E	94
KU	135

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 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. 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:

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•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. 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 grow 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' 2023 Form 10-K.

Credit Risk

See Notes 13 and14 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' 2023 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.

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' 2023 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' 2023 Form 10-K for information on projected environmental capital expenditures for 2024 through 2026. 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.

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The information below represents an update to “Item 1. Business – Environmental Matters” in the Registrants' 2023 Form 10-K.

Air

(PPL, LG&E and KU)

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: carbon monoxide, lead, nitrogen dioxide, ozone (contributed to by nitrogen oxide emissions), particulate matter and sulfur dioxide. In December 2020, the EPA released final actions keeping the existing NAAQS standard for particulate matter and ozone without change, but the EPA subsequently announced reconsideration of those decisions in June 2021. On March 6, 2024, the EPA finalized revisions to the particulate matter standard that lowers the primary standard for fine particulates. Based on the new standard, the EPA could potentially designate Jefferson County, Kentucky (Louisville) as being in nonattainment with the new particulate matter standard and require additional particulate matter reductions from sources including LG&E’s Mill Creek Station. The new particulate matter standard may also result in more stringent requirements for new generation located in nonattainment areas. 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. Additionally, the EPA reversed its previous approval of the Kentucky State Implementation Plan with respect to these requirements. In March 2023, the EPA Administrator 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, based on the installation time frame for certain selective catalytic reduction controls, subject to future specific allowance calculations. PPL, LG&E and KU are currently assessing the potential impact of the Good Neighbor Plan revisions on operations. The rules provide for reduced availability of NOx 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 response to judicial orders that stayed the EPA’s denial of certain state implementation plans, the EPA in July 2023 issued an interim stay of implementation of Good Neighbor Plan requirements for emission sources in several states including Kentucky. Legal challenges to CSAPR and related determinations remain pending and the U.S. Supreme Court will hear arguments on numerous stay applications filed by states and industry groups over the Good Neighbor Plan. In January 2023, the EPA released a proposed revision to increase the stringency of the current NAAQS for particulate matter. The EPA is continuing review of its previous determinations made in December 2020 to retain the existing NAAQS for ozone without change.

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.

Proposed 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 April 25, 2024, the EPA released a pre-publication version of a final rule increasing the stringency of MATS and further reducing emissions of certain hazardous air pollutants to reflect perceived developments in control technologies. PPL, LG&E, and KU are reviewing the final rule to determine its impact and do not expect significant operational changes or additional controls to be required.

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Proposed Greenhouse Gas Standards

On April 25, 2024, the EPA released a pre-publication version of 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). The standards would 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. 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.

New Accounting Guidance (All Registrants)

There has been no new accounting guidance adopted in 2024. See Note 17 to the Financial Statements for discussion of significant accounting guidance pending adoption as of March 31, 2024.

Other Matters

On March 6, 2024, the SEC adopted final rules that require registrants to disclose certain climate-related information in registration statements and annual reports. The final rules require registrants to disclose, among other things, material climate-related risks, activities to mitigate such risks and information about oversight by the registrant’s board of directors and management’s role in managing material climate-related risks. The final rule also requires registrants to provide information related to any climate-related targets or goals that are material to the registrant’s business, results of operations, or financial condition. A majority of the reporting requirements are applicable to the fiscal year beginning in 2025, with the addition of assurance reporting for greenhouse gas emissions starting in 2029 for large accelerated filers. Litigation challenging the new rule was filed by multiple parties in multiple jurisdictions, which have been consolidated and assigned to the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC announced that it is voluntarily staying the implementation of the climate disclosure regulations while the U.S. Court of Appeals considers the litigation. The Registrants are currently evaluating the impact of the final rules on their respective consolidated financial statements and related disclosures.

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' 2023 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, 2024, 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 2024 see:

•"Item 3. Legal Proceedings" in each Registrant's 2023 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' 2023 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

During the three months ended March 31, 2024, none of our directors or executive officers adopted, terminated or modified any Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as such terms are defined in Item 408 of Regulation

S-K.

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.

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4(a)	-	Supplemental Indenture No. 25, dated as of January 1, 2024, of PPL Electric Utilities Corporation to The Bank of New York Mellon, as Trustee (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated January 5, 2024)
4(b)	-	Sixth Supplemental Indenture, dated March 25, 2024, between The Narragansett Electric Company and The Bank of New York Mellon (Exhibit 4.2 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 25, 2024)
*10(a)	-	Commitment Extension Agreement and Amendment No. 2, dated as of February 29, 2024, 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 Borrower, PPL Corporation, as Guarantor, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender.
*10(b)	-	Commitment Extension Agreement and Amendment No. 2, dated as of February 29, 2024, to the Amended and Restated Revolving Credit Agreement, dated as of December 6, 2021, among PPL Electric Utilities Corporation, as the Borrower, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender.
*10(c)	-	Commitment Extension Agreement and Amendment No. 2, dated as of February 29, 2024, 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.
*10(d)	-	Commitment Extension Agreement and Amendment No. 2, dated as of February 29, 2024, 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.
Certifications pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended March 31, 2024, 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, 2024, 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:	May 1, 2024	/s/  Marlene C. Beers
		Marlene C. Beers Vice President and Controller
		(Principal Accounting Officer)
		PPL Electric Utilities Corporation
		(Registrant)
Date:	May 1, 2024	/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:	May 1, 2024	/s/  Christopher M. Garrett
		Christopher M. Garrett Vice President-Finance and Accounting
		(Principal Accounting and Financial Officer)

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EX-10.A

Execution Version COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (Commitment Extension Pursuant to Section 2.08(d) of Credit Agreement and Amendments Pursuant to Section 9.05 of Existing Credit Agreement) This COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (this “Agreement”) dated as of February 29, 2024, is entered into by and among PPL CAPITAL FUNDING, INC., a Delaware corporation (“Company”), The Narragansett Electric Company, a Rhode Island corporation (the “Designated Borrower” and together with the Company, each a “Borrower” and collectively, the “Borrowers”), PPL Corporation, a Pennsylvania corporation (“Guarantor”), the undersigned Lenders (as defined in the Credit Agreement) extending their 2027 Revolving Commitments (as defined in the Credit Agreement) (the “2027 Extending Lenders”), the Consenting Lenders (as defined below) party hereto and WELLS FARGO BANK, NATIONAL ASSOCIATION, as Administrative Agent (in such capacity, the “Administrative Agent”), Swingline Lender and Issuing Lender. Capitalized terms used and not otherwise defined herein shall have the meanings attributed to them in the Credit Agreement (as hereinafter defined). RECITALS A. Borrowers, Guarantor, the 2027 Extending Lenders, the Consenting Lenders and the Administrative Agent are parties to that certain Amended and Restated Revolving Credit Agreement dated as of December 6, 2021 (as amended by that certain Amendment No. 1 to Amended and Restated Revolving Credit Agreement, dated as March 30, 2023, and as further amended, restated, or otherwise modified from time to time prior to the date hereof, the “Existing Credit Agreement” and as amended hereby, the “Credit Agreement”). B. Pursuant to Section 2.08(d) of the Credit Agreement, the Borrowers desire to change the existing 2027 Termination Date, effective as of the Effective Date, from December 6, 2027 to December 6, 2028 and the 2027 Revolving Lenders party hereto constituting 2027 Extending Lenders and holding 2027 Revolving Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments agree to such extension. Pursuant to Section 2.08(d) of the Credit Agreement, Borrowers have requested an extension of the 2027 Termination Date (the “2027 Commitment Extension”) of the 2027 Revolving Commitments from December 6, 2027 to December 6, 2028, effective on the Effective Date. C. Each of the undersigned 2027 Extending Lenders has agreed to extend its 2027 Revolving Commitment in accordance with Section 1 hereto. D. Pursuant to Section 9.05 of the Credit Agreement, the Borrowers desire to amend the definition of “Quarterly Date” in Section 1.01 of the Existing Credit Agreement as set forth in Section 4 of this Agreement, and the Lenders party hereto constituting all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment (as defined below) (the “Consenting Lenders”) agree to such amendment. NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows: 1. Extension of Commitments. Effective as of the Effective Date, the 2027 Termination Date of the 2027 Revolving Commitment of each 2027 Extending Lender shall be extended to December 6, 2028 which, for purposes of Section 2.08(d)(ii) of the Credit Agreement, shall be the “Current Termination Date” with respect to the 2027 Revolving Commitments. Each 2027 Extending Lender hereby waives the notice periods, notice and timing requirements set forth in Section 2.08(d) of the Credit Agreement for the extension of the 2027 Termination Date. 2. Conditions Precedent to Effectiveness of Commitment Extension and Amendments. The Commitment Extensions and the amendments to the Existing Credit Agreement as set forth in Sections 3 to 5 hereunder shall be effective on and as of the first date on which the following conditions have been satisfied (the “Effective Date”):

2 1) Administrative Agent shall have received: a) counterparts of this Agreement, executed by each Borrower, Guarantor, each 2027 Extending Lender and the Consenting Lenders (which, for the avoidance of doubt, constitutes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment); b) an Extension Letter relating to the 2027 Commitment Extension as required by Section 2.08(d)(ii); c) a certificate of each Borrower dated the Effective Date and signed by an Authorized Officer of the applicable Borrower, certifying that: i) on such date, no Default under the Credit Agreement has occurred and is continuing; ii) the representations and warranties of such Borrower contained in the Credit Agreement are true and correct as of the Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and except for the representations and warranties in Section 5.04(c), Section 5.05 and Section 5.13 of the Credit Agreement; and iii) (A) In the case of the Company, no authorization, consent or approval of any Governmental Authority is required to be obtained by such Borrower to authorize the Commitment Extensions, or, (B) in the case of the Designated Borrower, any governmental, regulatory and third party approvals of any Governmental Authority required to be obtained by the Borrower to authorize the Commitment Extensions are attached thereto and remain in full force and effect. d) a certificate of the Guarantor dated the Effective Date signed by an Authorized Officer of the Guarantor, certifying that: i) on such date, no Default under the Credit Agreement has occurred and is continuing; ii) the representations and warranties of the Guarantor contained in the Credit Agreement are true and correct as of the Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and except for the representations and warranties in Section 5.04(c), Section 5.05, Section 5.13 and Section 5.15(a) of the Credit Agreement; and iii) no authorization, consent or approval of any Governmental Authority is required to be obtained by the Guarantor to authorize the Commitment Extensions. e) Opinions of (i) Bracewell LLP, counsel to each of the Loan Parties, and (ii) in-house counsel to the Loan Parties, addressed to the Administrative Agent and each Lender, dated the Effective Date, in form and substance satisfactory to the Administrative Agent. 2) Borrowers shall have paid all fees and expenses that are required to be paid as of the date set forth in that certain fee letter dated February 5, 2024, between the Borrowers and Wells Fargo Securities, LLC; 3) Lenders holding Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments of the Lenders on or prior to the Effective Date shall have agreed to extend the 2027 Termination Date in accordance with the terms hereof; and 4) the Master Assignment and Assumption Agreement (the “Master Assignment”), by and among the Borrowers, the Administrative Agent, Credit Suisse AG, New York Branch, as assignor of all of its Commitments and the Lenders party thereto as assignees, shall have been executed and is effective immediately prior to the Effective Date.

3 3. 2027 Termination Date Extension. Upon execution of this Agreement by the requisite Lenders under Sections 2.08(d) and 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “2027 Termination Date” in its entirety and replacing it with the following: ““2027 Termination Date” means the earlier to occur of (i) December 6, 2028, as may be extended from time to time pursuant to Section 2.08(d), and (ii) the date upon which all 2027 Revolving Commitments shall have been terminated in their entirety in accordance with this Agreement.” 4. Quarterly Date Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement (which, for the avoidance of doubt, includes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment), with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “Quarterly Date” in its entirety and replacing it with the following: ““Quarterly Date” means the tenth (10th) Business Day following the last day of each of March, June, September and December.” 5. Optional Extensions Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, the words “but on not more than two occasions during the term of the revolving credit facilities hereunder” in the first sentence of Section 2.08(d)(ii) of the Existing Credit Agreement is amended by replacing it with the following: “but (i) with respect to the 2026 Revolving Commitments, on not more than two occasions and (ii) with respect to the 2027 Revolving Commitments, on not more than one occasion, in each case, during the term of the revolving credit facilities hereunder”. 6. Commitments. Each party hereto acknowledges and agrees that as of the Effective Date, (a) Appendix A1 of the Credit Agreement is replaced with Appendix A1 of this Agreement, (b) Appendix A2 of the Credit Agreement is replaced with Appendix A2 of this Agreement, (a) Appendix A3 of the Credit Agreement is replaced with Appendix A3 of this Agreement, (a) Appendix A4 of the Credit Agreement is replaced with Appendix A4 of this Agreement. 7. Miscellaneous. (a) (i) Headings and captions may not be construed in interpreting provisions; (ii) this Agreement shall be governed by, and construed in accordance with, the law of the State of New York; and (iii) this Agreement may be executed in any number of counterparts with the same effect as if all signatories had signed the same document, and all of those counterparts must be construed together to constitute the same document. Delivery of an executed signature page of this Agreement by facsimile transmission or in electronic (i.e., “pdf” or “tif”) format shall be effective as delivery of a manually executed counterpart hereof. The words “execute,” “execution,” “signed,” “signature,” “delivery” and words of like import in or related to the Agreement shall be deemed to include electronic signatures or execution in the form of an electronic record, and contract formations on electronic platforms approved by the Agent, deliveries or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper- based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act. This Agreement shall become effective when each party hereto shall have received a counterpart hereof signed by the other parties hereto. (b) Upon and after the execution of this Agreement by each of the parties hereto, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Credit Agreement, and each reference in the other Loan Documents to “the Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Credit Agreement, shall mean and be a

4 reference to the Credit Agreement as modified hereby. This Agreement shall constitute a Loan Document. (c) The provisions set forth in Section 9.07 and 9.11 of the Credit Agreement are incorporated herein by reference, mutatis mutandis. 8. NO NOVATION; FULL FORCE AND EFFECT; RATIFICATION; ENTIRE AGREEMENT. NOTHING HEREIN CONTAINED SHALL BE CONSTRUED AS A NOVATION (OR A SUBSTITUTION, A PAYMENT AND REBORROWING, OR A TERMINATION) OF THE OBLIGATIONS OUTSTANDING UNDER THE CREDIT AGREEMENT OR INSTRUMENTS GUARANTEEING OR SECURING THE SAME. EXCEPT AS EXPRESSLY MODIFIED HEREIN, ALL OF THE TERMS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT ARE UNCHANGED AND REMAIN IN FULL FORCE AND EFFECT, AND, AS MODIFIED HEREBY, THE BORROWERS AND THE GUARANTOR CONFIRM AND RATIFY ALL OF THE TERMS, COVENANTS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT. THIS AGREEMENT SHALL CONSTITUTE A LOAN DOCUMENT FOR ALL PURPOSES OF THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS. THE EXECUTION, DELIVERY AND EFFECTIVENESS OF THIS AGREEMENT SHALL NOT, EXCEPT AS EXPRESSLY PROVIDED HEREIN, OPERATE AS A WAIVER OF ANY RIGHT, POWER OR REMEDY OF ANY LENDER OR THE ADMINISTRATIVE AGENT UNDER ANY OF THE LOAN DOCUMENTS, NOR, EXCEPT AS EXPRESSLY APPROVED HEREIN, CONSTITUTE A WAIVER OR AMENDMENT OF ANY PROVISION OF ANY OF THE LOAN DOCUMENTS. THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS, TOGETHER WITH THIS AGREEMENT, REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS, OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES. [Signature Pages to Follow]

Commitment Extension and Amendment Agreement - CF WELLS FARGO BANK, NATIONAL ASSOCIATION as Administrative Agent, Swingline Lender and Issuing Lender By: Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - CF WELLS FARGO BANK, NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - CF BANK OF AMERICA, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Dee Dee Farkas Title: Managing Director

MIZUHO BANK, LTD. as a 2027 Extending Lender and a Consenting Lender Name: Edward Sacks Title: Authorized Signatory Commitment Extension and Amendment Agreement - CF

Commitment Extension and Amendment Agreement - CF BANK OF MONTREAL as a 2027 Extending Lender and a Consenting Lender Name: Yash Gandhi Title: Vice President

Commitment Extension and Amendment Agreement - CF Canadian Imperial Bank of Commerce, New York Branch as a 2027 Extending Lender and a Consenting Lender Name: Amit Vasani Title: Managing Director

Commitment Extension and Amendment Agreement - CF GOLDMAN SACHS BANK USA as a 2027 Extending Lender and a Consenting Lender By: Name: Andrew Vernon Title: Authorized Signatory

Commitment Extension and Amendment Agreement - CF MORGAN STANLEY BANK, N.A. as a 2027 Extending Lender and a Consenting Lender By: Name: Michael King Title: Authorized Signatory

Commitment Extension and Amendment Agreement - CF ROYAL BANK OF CANADA as a 2027 Extending Lender and a Consenting Lender Name: Meg Donnelly Title: Authorized Signatory

Commitment Extension and Amendment Agreement - CF THE BANK OF NOVA SCOTIA as a 2027 Extending Lender and a Consenting Lender Name: David Dewar Title: Director

TRUIST BANK as a 2027 Extending Lender and a Consenting Lender Name: Title: Commitment Extension and Amendment Agreement - CF

U.S. BANK NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender By: _,:,-":;;;"?--i�::::::::===:::======•::::"" __ _ NGne: John Prigge Title: Senior Vice President Commitment Extension and Amendment Agreement - CF

SUMITOMO MITSUI BANKING CORPORATION as a 2027 Extending Lender and a Consenting Lender Name: Alkesh Nanavaty Title: Executive Director Commitment Extension and Amendment Agreement - CF

Commitment Extension and Amendment Agreement - CF Internal TD BANK, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Bernadette Collins Title: Senior Vice President

Commitment Extension and Amendment Agreement - CF THE BANK OF NEW YORK MELLON as a 2027 Extending Lender and a Consenting Lender Name: Molly H. Ross Title: Director

Commitment Extension and Amendment Agreement - CF Confidential BANCO SANTANDER, S.A., NEW YORK BRANCH, as a Consenting Lender Name: Andres Barbosa Title: Managing Director Name Arturo Prieto Title: Managing Director

Commitment Extension and Amendment Agreement - CF Appendix A1 2026 INITIAL COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $37,053,571.43 Total $37,053,571.43 2027 INITIAL COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $79,790,839.04 JPMorgan Chase Bank, N.A. $79,790,839.02 Bank of America, N.A. $79,790,839.02 Barclays Bank PLC $79,790,839.02 Mizuho Bank, Ltd. $79,790,839.02 Bank of Montreal $62,872,437.63 Canadian Imperial Bank of Commerce, New York Branch $62,872,437.63 Goldman Sachs Bank USA $62,872,437.63 Morgan Stanley Bank, N.A. $62,872,437.63 MUFG Bank, Ltd. $62,872,437.63 PNC Bank, National Association $62,872,437.63 Royal Bank of Canada $62,872,437.63 The Bank of Nova Scotia $62,872,437.63 Truist Bank $62,872,437.63 U.S. Bank National Association $62,872,437.63 First National Bank of Pennsylvania $37,053,571.43 Sumitomo Mitsui Banking Corporation $37,053,571.43 TD Bank, N.A. $37,053,571.43 The Bank of New York Mellon $37,053,571.43 The Huntington National Bank $37,053,571.43 Total $1,212,946,428.57

Commitment Extension and Amendment Agreement - CF Appendix A2 2026 PPL EU COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $19,267,857.14 Total $19,267,857.14 2027 PPL EU COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $41,491,236.30 JPMorgan Chase Bank, N.A. $41,491,236.29 Bank of America, N.A. $41,491,236.29 Barclays Bank PLC $41,491,236.29 Mizuho Bank, Ltd. $41,491,236.29 Bank of Montreal $32,693,667.57 Canadian Imperial Bank of Commerce, New York Branch $32,693,667.57 Goldman Sachs Bank USA $32,693,667.57 Morgan Stanley Bank, N.A. $32,693,667.57 MUFG Bank, Ltd. $32,693,667.57 PNC Bank, National Association $32,693,667.57 Royal Bank of Canada $32,693,667.57 The Bank of Nova Scotia $32,693,667.57 Truist Bank $32,693,667.57 U.S. Bank National Association $32,693,667.57 First National Bank of Pennsylvania $19,267,857.14 Sumitomo Mitsui Banking Corporation $19,267,857.14 TD Bank, N.A. $19,267,857.14 The Bank of New York Mellon $19,267,857.14 The Huntington National Bank $19,267,857.14 Total $630,732,142.86

Commitment Extension and Amendment Agreement - CF Appendix A3 2026 KU COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $11,857,142.86 Total $11,857,142.86 2027 KU COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $25,533,068.48 JPMorgan Chase Bank, N.A. $25,533,068.49 Bank of America, N.A. $25,533,068.49 Barclays Bank PLC $25,533,068.49 Mizuho Bank, Ltd. $25,533,068.49 Bank of Montreal $20,119,180.04 Canadian Imperial Bank of Commerce, New York Branch $20,119,180.04 Goldman Sachs Bank USA $20,119,180.04 Morgan Stanley Bank, N.A. $20,119,180.04 MUFG Bank, Ltd. $20,119,180.04 PNC Bank, National Association $20,119,180.04 Royal Bank of Canada $20,119,180.04 The Bank of Nova Scotia $20,119,180.04 Truist Bank $20,119,180.04 U.S. Bank National Association $20,119,180.04 First National Bank of Pennsylvania $11,857,142.86 Sumitomo Mitsui Banking Corporation $11,857,142.86 TD Bank, N.A. $11,857,142.86 The Bank of New York Mellon $11,857,142.86 The Huntington National Bank $11,857,142.86 Total $388,142,857.14

Commitment Extension and Amendment Agreement - CF Appendix A4 2026 LGE COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $14,821,428.57 Total $14,821,428.57 2027 LGE COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $31,916,335.64 JPMorgan Chase Bank, N.A. $31,916,335.61 Bank of America, N.A. $31,916,335.61 Barclays Bank PLC $31,916,335.61 Mizuho Bank, Ltd. $31,916,335.61 Bank of Montreal $25,148,975.05 Canadian Imperial Bank of Commerce, New York Branch $25,148,975.05 Goldman Sachs Bank USA $25,148,975.05 Morgan Stanley Bank, N.A. $25,148,975.05 MUFG Bank, Ltd. $25,148,975.05 PNC Bank, National Association $25,148,975.05 Royal Bank of Canada $25,148,975.05 The Bank of Nova Scotia $25,148,975.05 Truist Bank $25,148,975.05 U.S. Bank National Association $25,148,975.05 First National Bank of Pennsylvania $14,821,428.57 Sumitomo Mitsui Banking Corporation $14,821,428.57 TD Bank, N.A. $14,821,428.57 The Bank of New York Mellon $14,821,428.57 The Huntington National Bank $14,821,428.57 Total $485,178,571.43

EX-10.B

Execution Version COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (Commitment Extension Pursuant to Section 2.08(d) of Credit Agreement and Amendments Pursuant to Section 9.05 of Existing Credit Agreement) This COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (this “Agreement”) dated as of February 29, 2024, is entered into by and among PPL ELECTRIC UTILITIES CORPORATION, a Pennsylvania corporation (the “Borrower”), the undersigned Lenders (as defined in the Credit Agreement) extending their 2027 Revolving Commitments (as defined in the Credit Agreement) (the “2027 Extending Lenders”), the Consenting Lenders (as defined below) party hereto and WELLS FARGO BANK, NATIONAL ASSOCIATION, as Administrative Agent (in such capacity, the “Administrative Agent”), Swingline Lender and Issuing Lender. Capitalized terms used and not otherwise defined herein shall have the meanings attributed to them in the Credit Agreement (as hereinafter defined). RECITALS A. Borrower, the 2027 Extending Lenders, the Consenting Lenders and the Administrative Agent are parties to that certain Amended and Restated Revolving Credit Agreement dated as of December 6, 2021 (as amended by that certain Amendment No. 1 to Amended and Restated Revolving Credit Agreement, dated as March 30, 2023, and as further amended, restated, or otherwise modified from time to time prior to the date hereof, the “Existing Credit Agreement” and as amended hereby, the “Credit Agreement”). B. Pursuant to Section 2.08(d) of the Credit Agreement, the Borrower desires to change the existing 2027 Termination Date, effective as of the Effective Date, from December 6, 2027 to December 6, 2028 and the 2027 Revolving Lenders party hereto constituting 2027 Extending Lenders and holding 2027 Revolving Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments agree to such extension. Pursuant to Section 2.08(d) of the Credit Agreement, Borrower has requested an extension of the 2027 Termination Date (the “2027 Commitment Extension”) of the 2027 Revolving Commitments from December 6, 2027 to December 6, 2028, effective on the Effective Date. C. Each of the undersigned 2027 Extending Lenders has agreed to extend its 2027 Revolving Commitment in accordance with Section 1 hereto. D. Pursuant to Section 9.05 of the Credit Agreement, the Borrower desires to amend the definition of “Quarterly Date” in Section 1.01 of the Existing Credit Agreement as set forth in Section 4 of this Agreement, and the Lenders party hereto constituting all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment (as defined below) (the “Consenting Lenders”) agree to such amendment. NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows: 1. Extension of Commitments. Effective as of the Effective Date, the 2027 Termination Date of the 2027 Revolving Commitment of each 2027 Extending Lender shall be extended to December 6, 2028 which, for purposes of Section 2.08(d)(ii) of the Credit Agreement, shall be the “Current Termination Date” with respect to the 2027 Revolving Commitments. Each 2027 Extending Lender hereby waives the notice periods, notice and timing requirements set forth in Section 2.08(d) of the Credit Agreement for the extension of the 2027 Termination Date. 2. Conditions Precedent to Effectiveness of Commitment Extension and Amendments. The Commitment Extensions and the amendments to the Existing Credit Agreement as set forth in Sections 3 to 5 hereunder shall be effective on and as of the first date on which the following conditions have been satisfied (the “Effective Date”):

2 1) Administrative Agent shall have received: a) counterparts of this Agreement, executed by the Borrower, each 2027 Extending Lender and the Consenting Lenders (which, for the avoidance of doubt, constitutes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment); b) an Extension Letter relating to the 2027 Commitment Extension as required by Section 2.08(d)(ii); c) a certificate of the Borrower dated the Effective Date and signed by a Responsible Officer of the Borrower, certifying that: i) on such date, no Default under the Credit Agreement has occurred and is continuing; ii) the representations and warranties of the Borrower contained in the Credit Agreement are true and correct as of the Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and except for the representations and warranties in Section 5.04(c), Section 5.05 and Section 5.13 of the Credit Agreement; and iii) any governmental, regulatory and third party approvals of any Governmental Authority, including, without limitation, the PUC and/or FERC, required to be obtained by the Borrower to authorize the Commitment Extensions are attached thereto and remain in full force and effect. d) Opinions of (i) Bracewell LLP, counsel to the Borrower, and (ii) in-house counsel to the Borrower, addressed to the Administrative Agent and each Lender, dated the Effective Date, in form and substance satisfactory to the Administrative Agent. 2) Borrower shall have paid all fees and expenses that are required to be paid as of the date set forth in that certain fee letter dated February 5, 2024, between the Borrower and Wells Fargo Securities, LLC; 3) Lenders holding Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments of the Lenders on or prior to the Effective Date shall have agreed to extend the 2027 Termination Date in accordance with the terms hereof; and 4) the Master Assignment and Assumption Agreement (the “Master Assignment”), by and among the Borrower, the Administrative Agent, Credit Suisse AG, New York Branch, as assignor of all of its Commitments and the Lenders party thereto as assignees, shall have been executed and is effective immediately prior to the Effective Date. 3. 2027 Termination Date Extension. Upon execution of this Agreement by the requisite Lenders under Sections 2.08(d) and 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “2027 Termination Date” in its entirety and replacing it with the following: ““2027 Termination Date” means the earlier to occur of (i) December 6, 2028, as may be extended from time to time pursuant to Section 2.08(d), and (ii) the date upon which all 2027 Revolving Commitments shall have been terminated in their entirety in accordance with this Agreement.” 4. Quarterly Date Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement (which, for the avoidance of doubt, includes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment), with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “Quarterly Date” in its entirety and replacing it with the following:

3 ““Quarterly Date” means the tenth (10th) Business Day following the last day of each of March, June, September and December.” 5. Optional Extensions Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, the words “but on not more than two occasions during the term of the revolving credit facilities hereunder” in the first sentence of Section 2.08(d)(ii) of the Existing Credit Agreement is amended by replacing it with the following: “but (i) with respect to the 2026 Revolving Commitments, on not more than two occasions and (ii) with respect to the 2027 Revolving Commitments, on not more than one occasion, in each case, during the term of the revolving credit facilities hereunder”. 6. Commitments. Each party hereto acknowledges and agrees that as of the Effective Date, Appendix A of the Credit Agreement is replaced with Appendix A of this Agreement. 7. Miscellaneous. (a) (i) Headings and captions may not be construed in interpreting provisions; (ii) this Agreement shall be governed by, and construed in accordance with, the law of the State of New York; and (iii) this Agreement may be executed in any number of counterparts with the same effect as if all signatories had signed the same document, and all of those counterparts must be construed together to constitute the same document. Delivery of an executed signature page of this Agreement by facsimile transmission or in electronic (i.e., “pdf” or “tif”) format shall be effective as delivery of a manually executed counterpart hereof. The words “execute,” “execution,” “signed,” “signature,” “delivery” and words of like import in or related to the Agreement shall be deemed to include electronic signatures or execution in the form of an electronic record, and contract formations on electronic platforms approved by the Agent, deliveries or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper- based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act. This Agreement shall become effective when each party hereto shall have received a counterpart hereof signed by the other parties hereto. (b) Upon and after the execution of this Agreement by each of the parties hereto, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Credit Agreement, and each reference in the other Loan Documents to “the Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Credit Agreement, shall mean and be a reference to the Credit Agreement as modified hereby. This Agreement shall constitute a Loan Document. (c) The provisions set forth in Section 9.07 and 9.11 of the Credit Agreement are incorporated herein by reference, mutatis mutandis. 8. NO NOVATION; FULL FORCE AND EFFECT; RATIFICATION; ENTIRE AGREEMENT. NOTHING HEREIN CONTAINED SHALL BE CONSTRUED AS A NOVATION (OR A SUBSTITUTION, A PAYMENT AND REBORROWING, OR A TERMINATION) OF THE OBLIGATIONS OUTSTANDING UNDER THE CREDIT AGREEMENT OR INSTRUMENTS GUARANTEEING OR SECURING THE SAME. EXCEPT AS EXPRESSLY MODIFIED HEREIN, ALL OF THE TERMS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT ARE UNCHANGED AND REMAIN IN FULL FORCE AND EFFECT, AND, AS MODIFIED HEREBY, THE BORROWER CONFIRMS AND RATIFIES ALL OF THE TERMS, COVENANTS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT. THIS AGREEMENT SHALL CONSTITUTE A LOAN DOCUMENT FOR ALL PURPOSES OF THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS. THE EXECUTION, DELIVERY AND EFFECTIVENESS OF THIS AGREEMENT SHALL NOT, EXCEPT AS EXPRESSLY PROVIDED HEREIN, OPERATE AS A WAIVER OF ANY RIGHT, POWER OR REMEDY OF ANY LENDER OR

4 THE ADMINISTRATIVE AGENT UNDER ANY OF THE LOAN DOCUMENTS, NOR, EXCEPT AS EXPRESSLY APPROVED HEREIN, CONSTITUTE A WAIVER OR AMENDMENT OF ANY PROVISION OF ANY OF THE LOAN DOCUMENTS. THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS, TOGETHER WITH THIS AGREEMENT, REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS, OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES. [Signature Pages to Follow]

Commitment Extension and Amendment Agreement - EU WELLS FARGO BANK, NATIONAL ASSOCIATION as Administrative Agent, Swingline Lender and Issuing Lender By: Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement – EU WELLS FARGO BANK, NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender Name: Patrick Engel Title: Managing Director

JPMORGAN CHASE BANK, N.A., as a 2027 Extending Lender and a Consenting Lender Name: Khawaja Tariq Vice President Title: Commitment Extension and Amendment Agreement- EU

Commitment Extension and Amendment Agreement – EU BANK OF AMERICA, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Dee Dee Farkas Title: Managing Director

BARCLAYS BANK PLC as a 2027 Extending Lender and a Consenting Lender /) I Name: Title: Commitment Extension and Amendment Agreement- EU

MIZUHO BANK, LTD. as a 2027 Extending Lender and a Consenting Lender Name: Edward Sacks Title: Authorized Signatory Commitment Extension and Amendment Agreement – EU

Commitment Extension and Amendment Agreement – EU BANK OF MONTREAL as a 2027 Extending Lender and a Consenting Lender Name: Yash Gandhi Title: Vice President

Commitment Extension and Amendment Agreement – EU Canadian Imperial Bank of Commerce, New York Branch as a 2027 Extending Lender and a Consenting Lender Name: Amit Vasani Title: Managing Director

Commitment Extension and Amendment Agreement - EU GOLDMAN SACHS BANK USA as a 2027 Extending Lender and a Consenting Lender By: Name: Andrew Vernon Title: Authorized Signatory

Commitment Extension and Amendment Agreement - EU MORGAN STANLEY BANK, N.A. as a 2027 Extending Lender and a Consenting Lender By: Name: Michael King Title: Authorized Signatory

MUFG BANK, LTD., as a 2027 Extending Lender and a Consenting Lender ✓@� Name: Title: Viet-Linh Fujitaki Director Commitment Extension and Amendment Agreement - EU

PNC BANK, NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender Name: Ryan Rockwood Title: Vice President Commitment Extension and Amendment Agreement - EU

Commitment Extension and Amendment Agreement – EU ROYAL BANK OF CANADA as a 2027 Extending Lender and a Consenting Lender Name: Meg Donnelly Title: Authorized Signatory

Commitment Extension and Amendment Agreement – EU THE BANK OF NOVA SCOTIA as a 2027 Extending Lender and a Consenting Lender Name: David Dewar Title: Director

TRUISTBANK as a 2027 Extending Lender and a Consenting Lender Commitment Extension and Amendment Agreement - EU

U.S. BANK NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender �' By: Name: John Prigge Title: Senior Vice President Commitment Extension and Amendment Agreement• EU

FIRST NATIONAL BANK OF PENNSYLVANIA as a 2027 Extending Lender and a Consenting Lender Name: Title: ,v;dr;;J..,.41-,-il ,�---- Managing Director of Debt Capital Markets Commitment Extension and Amendment Agreement EU

SUMITOMO MITSUI BANKING CORPORATION as a 2027 Extending Lender and a Consenting Lender Name: Alkesh Nanavaty Title: Executive Director Commitment Extension and Amendment Agreement – EU

Commitment Extension and Amendment Agreement – EU TD BANK, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Bernadette Collins Title: Senior Vice President

Commitment Extension and Amendment Agreement – EU THE BANK OF NEW YORK MELLON as a 2027 Extending Lender and a Consenting Lender Name: Molly H. Ross Title: Director

THE HUNTINGTON NATIONAL BANK as a 2027 Extending Lender and a Consenting Lender Name: Christopher Olsen Title: Vice President Commitment Extension and Amendment Agreement - EU

Commitment Extension and Amendment Agreement – EU Confidential BANCO SANTANDER, S.A., NEW YORK BRANCH, as a Consenting Lender Name: Andres Barbosa Title: Managing Director Name: Arturo Prieto Title: Managing Director

Commitment Extension and Amendment Agreement - EU Appendix A 2026 REVOLVING COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $19,267,857.14 Total $19,267,857.14 2027 REVOLVING COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $41,491,236.30 JPMorgan Chase Bank, N.A. $41,491,236.29 Bank of America, N.A. $41,491,236.29 Barclays Bank PLC $41,491,236.29 Mizuho Bank, Ltd. $41,491,236.29 Bank of Montreal $32,693,667.57 Canadian Imperial Bank of Commerce, New York Branch $32,693,667.57 Goldman Sachs Bank USA $32,693,667.57 Morgan Stanley Bank, N.A. $32,693,667.57 MUFG Bank, Ltd. $32,693,667.57 PNC Bank, National Association $32,693,667.57 Royal Bank of Canada $32,693,667.57 The Bank of Nova Scotia $32,693,667.57 Truist Bank $32,693,667.57 U.S. Bank National Association $32,693,667.57 First National Bank of Pennsylvania $19,267,857.14 Sumitomo Mitsui Banking Corporation $19,267,857.14 TD Bank, N.A. $19,267,857.14 The Bank of New York Mellon $19,267,857.14 The Huntington National Bank $19,267,857.14 Total $630,732,142.86

EX-10.C

Execution Version COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (Commitment Extension Pursuant to Section 2.08(d) of Credit Agreement and Amendments Pursuant to Section 9.05 of Existing Credit Agreement) This COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (this “Agreement”) dated as of February 29, 2024, is entered into by and among LOUISVILLE GAS AND ELECTRIC COMPANY, a Kentucky corporation (the “Borrower”), the undersigned Lenders (as defined in the Credit Agreement) extending their 2027 Revolving Commitments (as defined in the Credit Agreement) (the “2027 Extending Lenders”), the Consenting Lenders (as defined below) party hereto and WELLS FARGO BANK, NATIONAL ASSOCIATION, as Administrative Agent (in such capacity, the “Administrative Agent”), Swingline Lender and Issuing Lender. Capitalized terms used and not otherwise defined herein shall have the meanings attributed to them in the Credit Agreement (as hereinafter defined). RECITALS A. Borrower, the 2027 Extending Lenders, the Consenting Lenders and the Administrative Agent are parties to that certain Amended and Restated Revolving Credit Agreement dated as of December 6, 2021 (as amended by that certain Amendment No. 1 to Amended and Restated Revolving Credit Agreement, dated as March 30, 2023, and as further amended, restated, or otherwise modified from time to time prior to the date hereof, the “Existing Credit Agreement” and as amended hereby, the “Credit Agreement”). B. Pursuant to Section 2.08(d) of the Credit Agreement, the Borrower desires to change the existing 2027 Termination Date, effective as of the Effective Date, from December 6, 2027 to December 6, 2028 and the 2027 Revolving Lenders party hereto constituting 2027 Extending Lenders and holding 2027 Revolving Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments agree to such extension. Pursuant to Section 2.08(d) of the Credit Agreement, Borrower has requested an extension of the 2027 Termination Date (the “2027 Commitment Extension”) of the 2027 Revolving Commitments from December 6, 2027 to December 6, 2028, effective on the Effective Date. C. Each of the undersigned 2027 Extending Lenders has agreed to extend its 2027 Revolving Commitment in accordance with Section 1 hereto. D. Pursuant to Section 9.05 of the Credit Agreement, the Borrower desires to amend the definition of “Quarterly Date” in Section 1.01 of the Existing Credit Agreement as set forth in Section 4 of this Agreement, and the Lenders party hereto constituting all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment (as defined below) (the “Consenting Lenders”) agree to such amendment. NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows: 1. Extension of Commitments. Effective as of the Effective Date, the 2027 Termination Date of the 2027 Revolving Commitment of each 2027 Extending Lender shall be extended to December 6, 2028 which, for purposes of Section 2.08(d)(ii) of the Credit Agreement, shall be the “Current Termination Date” with respect to the 2027 Revolving Commitments. Each 2027 Extending Lender hereby waives the notice periods, notice and timing requirements set forth in Section 2.08(d) of the Credit Agreement for the extension of the 2027 Termination Date. 2. Conditions Precedent to Effectiveness of Commitment Extension and Amendments. The Commitment Extensions and the amendments to the Existing Credit Agreement as set forth in Sections 3 to 5 hereunder shall be effective on and as of the first date on which the following conditions have been satisfied (the “Effective Date”):

2 1) Administrative Agent shall have received: a) counterparts of this Agreement, executed by the Borrower, each 2027 Extending Lender and the Consenting Lenders (which, for the avoidance of doubt, constitutes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment); b) an Extension Letter relating to the 2027 Commitment Extension as required by Section 2.08(d)(ii); c) a certificate of the Borrower dated the Effective Date and signed by a Responsible Officer of the Borrower, certifying that: i) on such date, no Default under the Credit Agreement has occurred and is continuing; ii) the representations and warranties of the Borrower contained in the Credit Agreement are true and correct as of the Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and except for the representations and warranties in Section 5.04(c), Section 5.05 and Section 5.13 of the Credit Agreement; and iii) any governmental, regulatory and third party approvals of any Governmental Authority, including, without limitation, the KPSC and/or FERC, required to be obtained by the Borrower to authorize the Commitment Extensions are attached thereto and remain in full force and effect. d) Opinions of (i) Bracewell LLP, counsel to the Borrower, and (ii) in-house counsel to the Borrower, addressed to the Administrative Agent and each Lender, dated the Effective Date, in form and substance satisfactory to the Administrative Agent. 2) Borrower shall have paid all fees and expenses that are required to be paid as of the date set forth in that certain fee letter dated February 5, 2024, between the Borrower and Wells Fargo Securities, LLC; 3) Lenders holding Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments of the Lenders on or prior to the Effective Date shall have agreed to extend the 2027 Termination Date in accordance with the terms hereof; and 4) the Master Assignment and Assumption Agreement (the “Master Assignment”), by and among the Borrower, the Administrative Agent, Credit Suisse AG, New York Branch, as assignor of all of its Commitments and the Lenders party thereto as assignees, shall have been executed and is effective immediately prior to the Effective Date. 3. 2027 Termination Date Extension. Upon execution of this Agreement by the requisite Lenders under Sections 2.08(d) and 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “2027 Termination Date” in its entirety and replacing it with the following: ““2027 Termination Date” means the earlier to occur of (i) December 6, 2028, as may be extended from time to time pursuant to Section 2.08(d), and (ii) the date upon which all 2027 Revolving Commitments shall have been terminated in their entirety in accordance with this Agreement.” 4. Quarterly Date Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement (which, for the avoidance of doubt, includes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment), with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “Quarterly Date” in its entirety and replacing it with the following:

3 ““Quarterly Date” means the tenth (10th) Business Day following the last day of each of March, June, September and December.” 5. Optional Extensions Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, the words “but on not more than two occasions during the term of the revolving credit facilities hereunder” in the first sentence of Section 2.08(d)(ii) of the Existing Credit Agreement is amended by replacing it with the following: “but (i) with respect to the 2026 Revolving Commitments, on not more than two occasions and (ii) with respect to the 2027 Revolving Commitments, on not more than one occasion, in each case, during the term of the revolving credit facilities hereunder”. 6. Commitments. Each party hereto acknowledges and agrees that as of the Effective Date, Appendix A of the Credit Agreement is replaced with Appendix A of this Agreement. 7. Miscellaneous. (a) (i) Headings and captions may not be construed in interpreting provisions; (ii) this Agreement shall be governed by, and construed in accordance with, the law of the State of New York; and (iii) this Agreement may be executed in any number of counterparts with the same effect as if all signatories had signed the same document, and all of those counterparts must be construed together to constitute the same document. Delivery of an executed signature page of this Agreement by facsimile transmission or in electronic (i.e., “pdf” or “tif”) format shall be effective as delivery of a manually executed counterpart hereof. The words “execute,” “execution,” “signed,” “signature,” “delivery” and words of like import in or related to the Agreement shall be deemed to include electronic signatures or execution in the form of an electronic record, and contract formations on electronic platforms approved by the Agent, deliveries or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper- based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act. This Agreement shall become effective when each party hereto shall have received a counterpart hereof signed by the other parties hereto. (b) Upon and after the execution of this Agreement by each of the parties hereto, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Credit Agreement, and each reference in the other Loan Documents to “the Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Credit Agreement, shall mean and be a reference to the Credit Agreement as modified hereby. This Agreement shall constitute a Loan Document. (c) The provisions set forth in Section 9.07 and 9.11 of the Credit Agreement are incorporated herein by reference, mutatis mutandis. 8. NO NOVATION; FULL FORCE AND EFFECT; RATIFICATION; ENTIRE AGREEMENT. NOTHING HEREIN CONTAINED SHALL BE CONSTRUED AS A NOVATION (OR A SUBSTITUTION, A PAYMENT AND REBORROWING, OR A TERMINATION) OF THE OBLIGATIONS OUTSTANDING UNDER THE CREDIT AGREEMENT OR INSTRUMENTS GUARANTEEING OR SECURING THE SAME. EXCEPT AS EXPRESSLY MODIFIED HEREIN, ALL OF THE TERMS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT ARE UNCHANGED AND REMAIN IN FULL FORCE AND EFFECT, AND, AS MODIFIED HEREBY, THE BORROWER CONFIRMS AND RATIFIES ALL OF THE TERMS, COVENANTS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT. THIS AGREEMENT SHALL CONSTITUTE A LOAN DOCUMENT FOR ALL PURPOSES OF THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS. THE EXECUTION, DELIVERY AND EFFECTIVENESS OF THIS AGREEMENT SHALL NOT, EXCEPT AS EXPRESSLY PROVIDED HEREIN, OPERATE AS A WAIVER OF ANY RIGHT, POWER OR REMEDY OF ANY LENDER OR

4 THE ADMINISTRATIVE AGENT UNDER ANY OF THE LOAN DOCUMENTS, NOR, EXCEPT AS EXPRESSLY APPROVED HEREIN, CONSTITUTE A WAIVER OR AMENDMENT OF ANY PROVISION OF ANY OF THE LOAN DOCUMENTS. THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS, TOGETHER WITH THIS AGREEMENT, REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS, OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES. [Signature Pages to Follow]

Commitment Extension and Amendment Agreement - LGE WELLS FARGO BANK, NATIONAL ASSOCIATION as Administrative Agent, Swingline Lender and Issuing Lender By: Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - LGE WELLS FARGO BANK, NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - LGE BANK OF AMERICA, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Dee Dee Farkas Title: Managing Director

MIZUHO BANK, LTD. as a 2027 Extending Lender and a Consenting Lender Name: Edward Sacks Title: Authorized Signatory Commitment Extension and Amendment Agreement - LGE

Commitment Extension and Amendment Agreement - LGE BANK OF MONTREAL as a 2027 Extending Lender and a Consenting Lender Name: Yash Gandhi Title: Vice President

Commitment Extension and Amendment Agreement - LGE Canadian Imperial Bank of Commerce, New York Branch as a 2027 Extending Lender and a Consenting Lender Name: Amit Vasani Title: Managing Director

Commitment Extension and Amendment Agreement - LGE GOLDMAN SACHS BANK USA as a 2027 Extending Lender and a Consenting Lender By: Name: Andrew Vernon Title: Authorized Signatory

Commitment Extension and Amendment Agreement - LGE MORGAN STANLEY BANK, N.A. as a 2027 Extending Lender and a Consenting Lender By: Name: Michael King Title: Authorized Signatory

Commitment Extension and Amendment Agreement - LGE ROYAL BANK OF CANADA as a 2027 Extending Lender and a Consenting Lender Name: Meg Donnelly Title: Authorized Signatory

Commitment Extension and Amendment Agreement - LGE THE BANK OF NOVA SCOTIA as a 2027 Extending Lender and a Consenting Lender Name: David Dewar Title: Director

TRUISTBANK as a 2027 Extending Lender and a Consenting Lender Name: Title: Commitment Extension and Amendment Agreement - LGE

U.S. BANK NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender By: a-.----. r Na� Title: Senior Vice President Commitment Extension and Amendment Agreement - LGE

SUMITOMO MITSUI BANKING CORPORATION as a 2027 Extending Lender and a Consenting Lender Name: Alkesh Nanavaty Title: Executive Director Commitment Extension and Amendment Agreement - LGE

Commitment Extension and Amendment Agreement - LGE TD BANK, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Bernadette Collins Title: Senior Vice President

Commitment Extension and Amendment Agreement - LGE THE BANK OF NEW YORK MELLON as a 2027 Extending Lender and a Consenting Lender Name: Molly H. Ross Title: Director

Commitment Extension and Amendment Agreement - LGE Confidential BANCO SANTANDER, S.A., NEW YORK BRANCH, as a Consenting Lender Name: Andres Barbosa Title: Managing Director Name: Arturo Prieto Title: Managing Director

Commitment Extension and Amendment Agreement - LGE Appendix A 2026 REVOLVING COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $14,821,428.57 Total $14,821,428.57 2027 REVOLVING COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $31,916,335.64 JPMorgan Chase Bank, N.A. $31,916,335.61 Bank of America, N.A. $31,916,335.61 Barclays Bank PLC $31,916,335.61 Mizuho Bank, Ltd. $31,916,335.61 Bank of Montreal $25,148,975.05 Canadian Imperial Bank of Commerce, New York Branch $25,148,975.05 Goldman Sachs Bank USA $25,148,975.05 Morgan Stanley Bank, N.A. $25,148,975.05 MUFG Bank, Ltd. $25,148,975.05 PNC Bank, National Association $25,148,975.05 Royal Bank of Canada $25,148,975.05 The Bank of Nova Scotia $25,148,975.05 Truist Bank $25,148,975.05 U.S. Bank National Association $25,148,975.05 First National Bank of Pennsylvania $14,821,428.57 Sumitomo Mitsui Banking Corporation $14,821,428.57 TD Bank, N.A. $14,821,428.57 The Bank of New York Mellon $14,821,428.57 The Huntington National Bank $14,821,428.57 Total $485,178,571.43

EX-10.D

Execution Version COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (Commitment Extension Pursuant to Section 2.08(d) of Credit Agreement and Amendments Pursuant to Section 9.05 of Existing Credit Agreement) This COMMITMENT EXTENSION AGREEMENT AND AMENDMENT NO. 2 TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (this “Agreement”) dated as of February 29, 2024, is entered into by and among KENTUCKY UTILITIES COMPANY, a Kentucky corporation and a Virginia corporation (the “Borrower”), the undersigned Lenders (as defined in the Credit Agreement) extending their 2027 Revolving Commitments (as defined in the Credit Agreement) (the “2027 Extending Lenders”), the Consenting Lenders (as defined below) party hereto and WELLS FARGO BANK, NATIONAL ASSOCIATION, as Administrative Agent (in such capacity, the “Administrative Agent”), Swingline Lender and Issuing Lender. Capitalized terms used and not otherwise defined herein shall have the meanings attributed to them in the Credit Agreement (as hereinafter defined). RECITALS A. Borrower, the 2027 Extending Lenders, the Consenting Lenders and the Administrative Agent are parties to that certain Amended and Restated Revolving Credit Agreement dated as of December 6, 2021 (as amended by that certain Amendment No. 1 to Amended and Restated Revolving Credit Agreement, dated as March 30, 2023, and as further amended, restated, or otherwise modified from time to time prior to the date hereof, the “Existing Credit Agreement” and as amended hereby, the “Credit Agreement”). B. Pursuant to Section 2.08(d) of the Credit Agreement, the Borrower desires to change the existing 2027 Termination Date, effective as of the Effective Date, from December 6, 2027 to December 6, 2028 and the 2027 Revolving Lenders party hereto constituting 2027 Extending Lenders and holding 2027 Revolving Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments agree to such extension. Pursuant to Section 2.08(d) of the Credit Agreement, Borrower has requested an extension of the 2027 Termination Date (the “2027 Commitment Extension”) of the 2027 Revolving Commitments from December 6, 2027 to December 6, 2028, effective on the Effective Date. C. Each of the undersigned 2027 Extending Lenders has agreed to extend its 2027 Revolving Commitment in accordance with Section 1 hereto. D. Pursuant to Section 9.05 of the Credit Agreement, the Borrower desires to amend the definition of “Quarterly Date” in Section 1.01 of the Existing Credit Agreement as set forth in Section 4 of this Agreement, and the Lenders party hereto constituting all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment (as defined below) (the “Consenting Lenders”) agree to such amendment. NOW, THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows: 1. Extension of Commitments. Effective as of the Effective Date, the 2027 Termination Date of the 2027 Revolving Commitment of each 2027 Extending Lender shall be extended to December 6, 2028 which, for purposes of Section 2.08(d)(ii) of the Credit Agreement, shall be the “Current Termination Date” with respect to the 2027 Revolving Commitments. Each 2027 Extending Lender hereby waives the notice periods, notice and timing requirements set forth in Section 2.08(d) of the Credit Agreement for the extension of the 2027 Termination Date. 2. Conditions Precedent to Effectiveness of Commitment Extension and Amendments. The Commitment Extensions and the amendments to the Existing Credit Agreement as set forth in Sections 3 to 5 hereunder shall be effective on and as of the first date on which the following conditions have been satisfied (the “Effective Date”):

2 1) Administrative Agent shall have received: a) counterparts of this Agreement, executed by the Borrower, each 2027 Extending Lender and the Consenting Lenders (which, for the avoidance of doubt, constitutes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment); b) an Extension Letter relating to the 2027 Commitment Extension as required by Section 2.08(d)(ii); c) a certificate of the Borrower dated the Effective Date and signed by a Responsible Officer of the Borrower, certifying that: i) on such date, no Default under the Credit Agreement has occurred and is continuing; ii) the representations and warranties of the Borrower contained in the Credit Agreement are true and correct as of the Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and except for the representations and warranties in Section 5.04(c), Section 5.05 and Section 5.13 of the Credit Agreement; and iii) any governmental, regulatory and third party approvals of any Governmental Authority, including, without limitation, the KPSC, VSCC and/or FERC, required to be obtained by the Borrower to authorize the Commitment Extensions are attached thereto and remain in full force and effect. d) Opinions of (i) Bracewell LLP, counsel to the Borrower, (ii) in-house counsel to the Borrower and (iii) Stoll Keenon Ogden PLLC, special counsel to the Borrower addressed to the Administrative Agent and each Lender, dated the Effective Date, in form and substance satisfactory to the Administrative Agent. 2) Borrower shall have paid all fees and expenses that are required to be paid as of the date set forth in that certain fee letter dated February 5, 2024, between the Borrower and Wells Fargo Securities, LLC; 3) Lenders holding Commitments that aggregate at least 51% of the aggregate 2027 Revolving Commitments of the Lenders on or prior to the Effective Date shall have agreed to extend the 2027 Termination Date in accordance with the terms hereof; and 4) the Master Assignment and Assumption Agreement (the “Master Assignment”), by and among the Borrower, the Administrative Agent, Credit Suisse AG, New York Branch, as assignor of all of its Commitments and the Lenders party thereto as assignees, shall have been executed and is effective immediately prior to the Effective Date. 3. 2027 Termination Date Extension. Upon execution of this Agreement by the requisite Lenders under Sections 2.08(d) and 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “2027 Termination Date” in its entirety and replacing it with the following: ““2027 Termination Date” means the earlier to occur of (i) December 6, 2028, as may be extended from time to time pursuant to Section 2.08(d), and (ii) the date upon which all 2027 Revolving Commitments shall have been terminated in their entirety in accordance with this Agreement.” 4. Quarterly Date Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement (which, for the avoidance of doubt, includes all Lenders under the Existing Credit Agreement immediately prior to the Effective Date but after giving effect to the Master Assignment), with effect from and including the Effective Date, Section 1.01 of the Existing Credit Agreement is amended by deleting the definition of “Quarterly Date” in its entirety and replacing it with the following:

3 ““Quarterly Date” means the tenth (10th) Business Day following the last day of each of March, June, September and December.” 5. Optional Extensions Amendment. Upon execution of this Agreement by the requisite Lenders under Section 9.05 of the Existing Credit Agreement, with effect from and including the Effective Date, the words “but on not more than two occasions during the term of the revolving credit facilities hereunder” in the first sentence of Section 2.08(d)(ii) of the Existing Credit Agreement is amended by replacing it with the following: “but (i) with respect to the 2026 Revolving Commitments, on not more than two occasions and (ii) with respect to the 2027 Revolving Commitments, on not more than one occasion, in each case, during the term of the revolving credit facilities hereunder”. 6. Commitments. Each party hereto acknowledges and agrees that as of the Effective Date, Appendix A of the Credit Agreement is replaced with Appendix A of this Agreement. 7. Miscellaneous. (a) (i) Headings and captions may not be construed in interpreting provisions; (ii) this Agreement shall be governed by, and construed in accordance with, the law of the State of New York; and (iii) this Agreement may be executed in any number of counterparts with the same effect as if all signatories had signed the same document, and all of those counterparts must be construed together to constitute the same document. Delivery of an executed signature page of this Agreement by facsimile transmission or in electronic (i.e., “pdf” or “tif”) format shall be effective as delivery of a manually executed counterpart hereof. The words “execute,” “execution,” “signed,” “signature,” “delivery” and words of like import in or related to the Agreement shall be deemed to include electronic signatures or execution in the form of an electronic record, and contract formations on electronic platforms approved by the Agent, deliveries or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper- based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act. This Agreement shall become effective when each party hereto shall have received a counterpart hereof signed by the other parties hereto. (b) Upon and after the execution of this Agreement by each of the parties hereto, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Credit Agreement, and each reference in the other Loan Documents to “the Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Credit Agreement, shall mean and be a reference to the Credit Agreement as modified hereby. This Agreement shall constitute a Loan Document. (c) The provisions set forth in Section 9.07 and 9.11 of the Credit Agreement are incorporated herein by reference, mutatis mutandis. 8. NO NOVATION; FULL FORCE AND EFFECT; RATIFICATION; ENTIRE AGREEMENT. NOTHING HEREIN CONTAINED SHALL BE CONSTRUED AS A NOVATION (OR A SUBSTITUTION, A PAYMENT AND REBORROWING, OR A TERMINATION) OF THE OBLIGATIONS OUTSTANDING UNDER THE CREDIT AGREEMENT OR INSTRUMENTS GUARANTEEING OR SECURING THE SAME. EXCEPT AS EXPRESSLY MODIFIED HEREIN, ALL OF THE TERMS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT ARE UNCHANGED AND REMAIN IN FULL FORCE AND EFFECT, AND, AS MODIFIED HEREBY, THE BORROWER CONFIRMS AND RATIFIES ALL OF THE TERMS, COVENANTS AND CONDITIONS OF THE EXISTING CREDIT AGREEMENT. THIS AGREEMENT SHALL CONSTITUTE A LOAN DOCUMENT FOR ALL PURPOSES OF THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS. THE EXECUTION, DELIVERY AND EFFECTIVENESS OF THIS AGREEMENT SHALL NOT, EXCEPT AS EXPRESSLY PROVIDED HEREIN, OPERATE AS A WAIVER OF ANY RIGHT, POWER OR REMEDY OF ANY LENDER OR

4 THE ADMINISTRATIVE AGENT UNDER ANY OF THE LOAN DOCUMENTS, NOR, EXCEPT AS EXPRESSLY APPROVED HEREIN, CONSTITUTE A WAIVER OR AMENDMENT OF ANY PROVISION OF ANY OF THE LOAN DOCUMENTS. THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS, TOGETHER WITH THIS AGREEMENT, REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS, OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO UNWRITTEN ORAL AGREEMENTS BETWEEN THE PARTIES. [Signature Pages to Follow]

Commitment Extension and Amendment Agreement - KU WELLS FARGO BANK, NATIONAL ASSOCIATION as Administrative Agent, Swingline Lender and Issuing Lender By: Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - KU WELLS FARGO BANK, NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender Name: Patrick Engel Title: Managing Director

Commitment Extension and Amendment Agreement - KU BANK OF AMERICA, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Dee Dee Farkas Title: Managing Director

MIZUHO BANK, LTD. as a 2027 Extending Lender and a Consenting Lender Name: Edward Sacks Title: Authorized Signatory Commitment Extension and Amendment Agreement - KU

Commitment Extension and Amendment Agreement - KU BANK OF MONTREAL as a 2027 Extending Lender and a Consenting Lender Name: Yash Gandhi Title: Vice President

Commitment Extension and Amendment Agreement - KU Canadian Imperial Bank of Commerce, New York Branch as a 2027 Extending Lender and a Consenting Lender Name: Amit Vasani Title: Managing Director

Commitment Extension and Amendment Agreement - KU GOLDMAN SACHS BANK USA as a 2027 Extending Lender and a Consenting Lender By: Name: Andrew Vernon Title: Authorized Signatory

Commitment Extension and Amendment Agreement - KU MORGAN STANLEY BANK, N.A. as a 2027 Extending Lender and a Consenting Lender By: Name: Michael King Title: Authorized Signatory

Commitment Extension and Amendment Agreement - KU ROYAL BANK OF CANADA as a 2027 Extending Lender and a Consenting Lender Name: Meg Donnelly Title: Authorized Signatory

Commitment Extension and Amendment Agreement - KU THE BANK OF NOVA SCOTIA as a 2027 Extending Lender and a Consenting Lender Name: David Dewar Title: Director

TRUISTBANK as a 2027 Extending Lender and a Consenting Lender Commitment Extension and Amendment Agreement - KU

U.S. BANK NATIONAL ASSOCIATION as a 2027 Extending Lender and a Consenting Lender By: --4".//4""�'-------'-· _�_: __ ____ _ Na& JohnPrigge Title: Senior Vice President Commitment Extension and Amendment Agreement - KU

SUMITOMO MITSUI BANKING CORPORATION as a 2027 Extending Lender and a Consenting Lender Name: Alkesh Nanavaty Title: Executive Director Commitment Extension and Amendment Agreement - KU

Commitment Extension and Amendment Agreement - KU TD BANK, N.A. as a 2027 Extending Lender and a Consenting Lender Name: Bernadette Collins Title: Senior Vice President

Commitment Extension and Amendment Agreement - KU THE BANK OF NEW YORK MELLON as a 2027 Extending Lender and a Consenting Lender Name: Molly H. Ross Title: Director

Commitment Extension and Amendment Agreement - KU Confidential BANCO SANTANDER, S.A., NEW YORK BRANCH, as a Consenting Lender Name: Andres Barbosa Title: Managing Director Name: Arturo Prieto Title: Managing Director

Commitment Extension and Amendment Agreement - KU Appendix A 2026 REVOLVING COMMITMENTS Lender Commitments Banco Santander, S.A., New York Branch $11,857,142.86 Total $11,857,142.86 2027 REVOLVING COMMITMENTS Lender Commitments Wells Fargo Bank, National Association $25,533,068.48 JPMorgan Chase Bank, N.A. $25,533,068.49 Bank of America, N.A. $25,533,068.49 Barclays Bank PLC $25,533,068.49 Mizuho Bank, Ltd. $25,533,068.49 Bank of Montreal $20,119,180.04 Canadian Imperial Bank of Commerce, New York Branch $20,119,180.04 Goldman Sachs Bank USA $20,119,180.04 Morgan Stanley Bank, N.A. $20,119,180.04 MUFG Bank, Ltd. $20,119,180.04 PNC Bank, National Association $20,119,180.04 Royal Bank of Canada $20,119,180.04 The Bank of Nova Scotia $20,119,180.04 Truist Bank $20,119,180.04 U.S. Bank National Association $20,119,180.04 First National Bank of Pennsylvania $11,857,142.86 Sumitomo Mitsui Banking Corporation $11,857,142.86 TD Bank, N.A. $11,857,142.86 The Bank of New York Mellon $11,857,142.86 The Huntington National Bank $11,857,142.86 Total $388,142,857.14

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:	May 1, 2024	/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:	May 1, 2024	/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:	May 1, 2024	/s/  Christine M. Martin
		Christine M. Martin
		President
		(Principal ExecutiveOfficer)
		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:	May 1, 2024	/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:	May 1, 2024	/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:	May 1, 2024	/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:	May 1, 2024	/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:	May 1, 2024	/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, 2024

    In connection with the quarterly report on Form 10-Q of PPL Corporation (the "Company") for the quarter ended March 31, 2024, 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:	May 1, 2024	/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, 2024

    In connection with the quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "Company") for the quarter ended March 31, 2024, 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:	May 1, 2024	/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, 2024

    In connection with the quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "Company") for the quarter ended March 31, 2024, 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:	May 1, 2024	/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, 2024

    In connection with the quarterly report on Form 10-Q of Kentucky Utilities Company (the "Company") for the quarter ended March 31, 2024, 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:	May 1, 2024	/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, 2024	Apr. 26, 2024
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	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Document Type	10-Q
Document Period End Date	Mar. 31, 2024
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		737,740,859
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
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	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
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	220 West Main Street
Entity Address, City or Town	Louisville,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40202-1377
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, 2024		Mar. 31, 2023
Operating Revenues
Operating Revenues		$ 2,304		$ 2,415
Operation
Fuel		209		201
Energy purchases		520		734
Other operation and maintenance		626		559
Depreciation		316		313
Taxes, other than income		88		110
Total Operating Expenses		1,759		1,917
Operating Income		545		498
Other Income (Expense) - net		22		30
Interest Expense		179		164
Income Taxes		81		79
Net Income (Loss)		$ 307		$ 285
Net Income:
Diluted (in dollars per share)		$ 0.42		$ 0.39
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		737,512		736,829
Diluted (in shares)		738,820		737,698
Income from Continuing Operations Before Income Taxes		$ 388		$ 364
Income (Loss) from Continuing Operations After Income Taxes, Basic		$ 0.42		$ 0.39
Income (Loss) from Continuing Operations after income taxes, Diluted		$ 0.42		$ 0.39
Rhode Island Regulated
Operating Revenues
Operating Revenues		$ 549		$ 565
Operation
Net Income (Loss)		64		54
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		770		891
Operation
Energy purchases		214		358
Other operation and maintenance		181		162
Depreciation		99		99
Taxes, other than income		36		44
Total Operating Expenses		530		663
Operating Income		240		228
Other Income (Expense) - net		9		12
Interest Expense		62		57
Income Taxes		48		45
Net Income (Loss)	[1]	149		138
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		197		183
PPL Electric Utilities Corp [Member] | Related Party
Operation
Interest Income from affiliate		10		0
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		476		474
Operation
Fuel		86		79
Energy purchases		71		84
Energy purchases from affiliate		1		1
Other operation and maintenance		88		91
Depreciation		76		75
Taxes, other than income		13		12
Total Operating Expenses		335		342
Operating Income		141		132
Other Income (Expense) - net		2		2
Interest Expense		26		25
Income Taxes		24		23
Net Income (Loss)		93	[2]	86
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		117		109
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		16		13
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		460		461
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		525		499
Operation
Fuel		123		122
Energy purchases		6		6
Energy purchases from affiliate		16		13
Other operation and maintenance		102		109
Depreciation		99		98
Taxes, other than income		12		10
Total Operating Expenses		358		358
Operating Income		167		141
Other Income (Expense) - net		2		2
Interest Expense		34		33
Income Taxes		27		22
Net Income (Loss)	[3]	108		88
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		135		110
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		1		1
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		$ 524		$ 498

[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, 2024	Mar. 31, 2023
Net income (loss)	$ 307	$ 285
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax	1	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	0	(1)
Total other comprehensive income (loss)	2	1
Comprehensive income (loss)	$ 309	$ 286

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
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, 2024		Mar. 31, 2023
Cash Flows from Operating Activities
Net income (loss)		$ 307		$ 285
Depreciation		316		313
Amortization		24		17
Defined benefit plans - (income) expense		(15)		(18)
Deferred income taxes and investment tax credits		72		77
Other		3		8
Change in current assets and current liabilities
Accounts receivable		(75)		(94)
Accounts payable		(221)		(63)
Unbilled revenues		57		109
Fuel, materials and supplies		33		10
Prepayments		(108)		(83)
Taxes payable		(47)		(42)
Regulatory assets and liabilities, net		(61)		(46)
Accrued interest		90		67
Other		(103)		(14)
Other operating activities
Defined benefit plans - funding		(5)		(3)
Other assets		(1)		(61)
Other liabilities		16		(32)
Net cash provided by operating activities		282		430
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(596)		(499)
Other investing activities		5		(4)
Net cash used in investing activities		(591)		(503)
Cash Flows from Financing Activities
Issuance of long-term debt		1,148		3,127
Retirement of long-term debt		0		(1,750)
Payment of common stock dividends		(177)		(171)
Net increase (decrease) in short-term debt		(701)		(985)
Other financing activities		(22)		(44)
Net cash provided by financing activities		248		177
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(61)		104
Cash and Cash Equivalents at Beginning of Period		331
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		382		357
Cash and Cash Equivalents at End of Period		276
Cash, Cash Equivalents and Restricted Cash at End of Period		321		461
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		253		257
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	149		138
Depreciation		99		99
Amortization		12		9
Defined benefit plans - (income) expense		(11)		(10)
Deferred income taxes and investment tax credits		32		26
Other		(7)		(5)
Change in current assets and current liabilities
Accounts receivable		(33)		(115)
Accounts payable		(59)		30
Unbilled revenues		30		20
Fuel, materials and supplies		(4)		(17)
Prepayments		(110)		(77)
Taxes payable		(48)		(36)
Regulatory assets and liabilities, net		(28)		(12)
Accrued interest		35		15
Other		(26)		17
Other operating activities
Defined benefit plans - funding		(1)		(1)
Other assets		0		(22)
Other liabilities		(2)		(20)
Net cash provided by operating activities		28		39
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(229)		(155)
Expenditures for intangible assets		(1)		(1)
Notes receivable from affiliates		(554)		0
Other investing activities		4		0
Net cash used in investing activities		(780)		(156)
Cash Flows from Financing Activities
Issuance of long-term debt		649		1,329
Retirement of long-term debt		0		(1,150)
Payment of common stock dividends to parent		(88)		(74)
Net increase (decrease) in short-term debt		(509)		(145)
Contributions from parent		675		200
Debt Issuance Costs		(5)		(12)
Net cash provided by financing activities		722		148
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(30)		31
Cash and Cash Equivalents at Beginning of Period		51
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51		25
Cash and Cash Equivalents at End of Period		21
Cash, Cash Equivalents and Restricted Cash at End of Period		21		56
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		146		142
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)		93	[2]	86
Depreciation		76		75
Amortization		3		3
Defined benefit plans - (income) expense		1		0
Deferred income taxes and investment tax credits		2		0
Change in current assets and current liabilities
Accounts receivable		(19)		28
Accounts receivable from affiliates		(11)		14
Accounts payable		6		(35)
Increase (Decrease) in Accounts Payable, Related Parties		34		31
Unbilled revenues		16		33
Fuel, materials and supplies		13		41
Taxes payable		(26)		(27)
Regulatory assets and liabilities, net		(21)		21
Accrued interest		23		18
Other		(19)		(11)
Other operating activities
Defined benefit plans - funding		(1)		0
Expenditures for asset retirement obligations		(2)		(2)
Other assets		0		(10)
Other liabilities		(2)		(1)
Net cash provided by operating activities		166		264
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(92)		(86)
Notes receivable from affiliates		(28)		(9)
Net cash used in investing activities		(120)		(95)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(300)
Payment of common stock dividends to parent		(37)		(31)
Net increase (decrease) in short-term debt		28		(179)
Return of capital to parent		(51)		(120)
Other financing activities		0		(3)
Net cash provided by financing activities		(60)		(234)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(14)		(65)
Cash and Cash Equivalents at Beginning of Period		18
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		44		93
Cash and Cash Equivalents at End of Period		8
Cash, Cash Equivalents and Restricted Cash at End of Period		30		28
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		35		46
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	108		88
Depreciation		99		98
Amortization		5		5
Defined benefit plans - (income) expense		(1)		0
Deferred income taxes and investment tax credits		(1)		(1)
Other		(1)		(1)
Change in current assets and current liabilities
Accounts receivable		(21)		16
Accounts payable		(13)		(16)
Increase (Decrease) in Accounts Payable, Related Parties		52		2
Unbilled revenues		6		25
Fuel, materials and supplies		8		(8)
Taxes payable		(17)		(11)
Regulatory assets and liabilities, net		1		8
Accrued interest		32		26
Other		(7)		2
Other operating activities
Defined benefit plans - funding		(1)		0
Expenditures for asset retirement obligations		(2)		(5)
Other assets		8		(13)
Other liabilities		(3)		(1)
Net cash provided by operating activities		252		214
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(148)		(141)
Net cash used in investing activities		(148)		(141)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(300)
Increase Decrease In Notes Payable To Affiliates		37		9
Payment of common stock dividends to parent		(47)		(35)
Net increase (decrease) in short-term debt		(48)		(101)
Return of capital to parent		(50)		(54)
Other financing activities		0		(3)
Net cash provided by financing activities		(108)		(85)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(4)		(12)
Cash and Cash Equivalents at Beginning of Period		14
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		38		21
Cash and Cash Equivalents at End of Period		12
Cash, Cash Equivalents and Restricted Cash at End of Period		34		9
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		$ 44		$ 60

[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, 2024	Dec. 31, 2023
Assets, Current [Abstract]
Cash and cash equivalents		$ 276	$ 331
Accounts receivable (less reserve:)
Customer		999	950
Other		271	271
Unbilled revenues		371	428
Fuel, materials and supplies		477	505
Prepayments		212	103
Regulatory Assets, Current		330	293
Other current assets		101	51
Total Current Assets		3,037	2,932
Property, Plant and Equipment
Regulated utility plant		39,031	38,608
Less:  accumulated depreciation - regulated utility plant		9,327	9,156
Regulated utility plant, net		29,704	29,452
Non-regulated property, plant and equipment		71	72
Less:  accumulated depreciation - non-regulated property, plant and equipment		24	23
Non-regulated property, plant and equipment, net		47	49
Construction work in progress		1,996	1,917
Property, Plant and Equipment, net		31,747	31,418
Other Noncurrent Assets
Regulatory assets		1,859	1,874
Goodwill		2,247	2,247
Other intangibles		304	306
Other noncurrent assets		437	459
Assets, Noncurrent		4,847	4,886
Total Assets		39,631	39,236
Current Liabilities
Short-term debt		291	992
Long-term debt due within one year		1	1
Accounts payable		903	1,104
Taxes		83	130
Interest		214	124
Dividends		186	173
Regulatory liabilities		223	225
Other current liabilities		474	591
Liabilities, Current, Total		2,375	3,340
Long-term Debt, Unclassified [Abstract]
Long-term Debt		15,753	14,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,195	3,105
Investment tax credits		113	114
Accrued pension obligations		255	275
Asset retirement obligations		127	133
Regulatory liabilities		3,351	3,340
Other deferred credits and noncurrent liabilities		404	385
Total Deferred Credits and Other Noncurrent Liabilities		7,445	7,352
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,314	12,326
Treasury Stock		(931)	(948)
Earnings reinvested		2,828	2,710
Accumulated other comprehensive loss		(161)	(163)
Total Equity		14,058	13,933
Total Liabilities and Equity		39,631	39,236
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		21	51
Accounts receivable (less reserve:)
Other		10	8
Unbilled revenues		119	149
Notes Receivable from affiliates		554	0
Fuel, materials and supplies		103	99
Prepayments		155	44
Regulatory Assets, Current		84	57
Other current assets		33	17
Total Current Assets		1,539	869
Property, Plant and Equipment
Regulated utility plant		15,740	15,575
Less:  accumulated depreciation - regulated utility plant		3,889	3,822
Regulated utility plant, net		11,851	11,753
Construction work in progress		744	680
Property, Plant and Equipment, net		12,595	12,433
Other Noncurrent Assets
Regulatory assets		592	598
Other intangibles		269	269
Other noncurrent assets		121	125
Assets, Noncurrent		982	992
Total Assets		15,116	14,294
Current Liabilities
Short-term debt		0	509
Taxes		3	51
Interest		78	43
Regulatory liabilities		90	91
Other current liabilities		82	100
Liabilities, Current, Total		709	1,292
Long-term Debt, Unclassified [Abstract]
Long-term Debt		5,211	4,567
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,608	1,573
Regulatory liabilities		839	836
Other deferred credits and noncurrent liabilities		110	123
Total Deferred Credits and Other Noncurrent Liabilities		2,557	2,532
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,715	4,040
Earnings reinvested		1,560	1,499
Total Equity		6,639	5,903
Total Liabilities and Equity		$ 15,116	$ 14,294
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]		CEP Reserves, Inc	CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		$ 10	$ 10
Notes Receivable from affiliates		554	0
Current Liabilities
Accounts payable		52	44
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		450	434
Current Liabilities
Accounts payable		404	454
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		8	18
Accounts receivable (less reserve:)
Other		24	17
Unbilled revenues		72	88
Fuel, materials and supplies		130	143
Prepayments		11	11
Regulatory Assets, Current		14	7
Other current assets		6	0
Total Current Assets		454	429
Property, Plant and Equipment
Regulated utility plant		7,715	7,669
Less:  accumulated depreciation - regulated utility plant		1,599	1,549
Regulated utility plant, net		6,116	6,120
Construction work in progress		342	312
Property, Plant and Equipment, net		6,458	6,432
Other Noncurrent Assets
Regulatory assets		388	395
Goodwill		389	389
Other intangibles		17	18
Other noncurrent assets		92	90
Assets, Noncurrent		886	892
Total Assets		7,798	7,753
Current Liabilities
Short-term debt		28	0
Taxes		15	41
Price risk management liabilities current		1	1
Interest		44	21
Current Customer Deposits		35	34
Regulatory liabilities		2	16
Asset Retirement Obligation, Current		13	13
Other current liabilities		32	47
Liabilities, Current, Total		374	337
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,469	2,469
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		782	776
Investment tax credits		30	31
Asset retirement obligations		71	72
Regulatory liabilities		824	827
Price risk management liabilities		4	6
Other deferred credits and noncurrent liabilities		67	63
Total Deferred Credits and Other Noncurrent Liabilities		1,778	1,775
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,942	1,993
Earnings reinvested		811	755
Total Equity		3,177	3,172
Total Liabilities and Equity		7,798	7,753
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		40	29
Notes Receivable from affiliates		28	0
Current Liabilities
Accounts payable		83	49
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		121	116
Current Liabilities
Accounts payable		121	115
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		12	14
Accounts receivable (less reserve:)
Customer		152	143
Other		19	12
Unbilled revenues		91	97
Fuel, materials and supplies		177	185
Prepayments		11	13
Regulatory Assets, Current		7	3
Other current assets		2	1
Total Current Assets		471	468
Property, Plant and Equipment
Regulated utility plant		10,038	9,896
Less:  accumulated depreciation - regulated utility plant		2,547	2,476
Regulated utility plant, net		7,491	7,420
Construction work in progress		594	604
Property, Plant and Equipment, net		8,085	8,024
Other Noncurrent Assets
Regulatory assets		435	439
Goodwill		607	607
Other intangibles		18	19
Other noncurrent assets		157	157
Assets, Noncurrent		1,217	1,222
Total Assets		9,773	9,714
Current Liabilities
Short-term debt		$ 45	$ 93
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 37	$ 0
Taxes		15	32
Interest		56	24
Current Customer Deposits		38	35
Regulatory liabilities		6	1
Asset Retirement Obligation, Current		16	13
Other current liabilities		44	52
Liabilities, Current, Total		450	402
Long-term Debt, Unclassified [Abstract]
Long-term Debt		3,064	3,064
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		917	912
Investment tax credits		83	83
Asset retirement obligations		48	53
Regulatory liabilities		1,016	1,018
Other deferred credits and noncurrent liabilities		32	30
Total Deferred Credits and Other Noncurrent Liabilities		2,096	2,096
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,983	3,033
Earnings reinvested		872	811
Total Equity		4,163	4,152
Total Liabilities and Equity		9,773	9,714
Kentucky Utilities Co [Member] | Related Party
Current Liabilities
Accounts payable		123	72
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 70	$ 80

[1] 1,560,000 shares authorized, 770,013 shares issued and 737,736 shares outstanding at March 31, 2024. 1,560,000 shares authorized, 770,013 shares issued and 737,130 shares outstanding at December 31, 2023.

[2] 170,000 shares authorized; 66,368 shares issued and outstanding at March 31, 2024 and December 31, 2023.

[3] 75,000 shares authorized; 21,294 shares issued and outstanding at March 31, 2024 and December 31, 2023.

[4] 80,000 shares authorized; 37,818 shares issued and outstanding at March 31, 2024 and December 31, 2023.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 146	$ 123
Unbilled revenues, reserve	4	4
Reserve for accounts receivable (noncurrent)	$ 3	$ 2
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)	770,013	770,013
Common stock shares outstanding (in shares)	737,736	737,130
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 57	$ 46
Unbilled revenues, reserve	2	2
Reserve for accounts receivable (noncurrent)	$ 3	$ 2
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	$ 6
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	$ 3	$ 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	Noncontrolling Interest	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	$ 13,918		$ 8		$ 12,317	$ 2,681		$ (124)	$ (967)	$ 3	$ 5,751		$ 364		$ 4,084	$ 1,303	$ 3,166		$ 424		$ 2,087	$ 655	$ 4,038		$ 308		$ 3,041	$ 689
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2400
Balance at beginning of period - shares at Dec. 31, 2022			736,487	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 19				2				$ 17
Stock Issued During Period, Shares, Treasury Stock Reissued									580
Stock-based compensation	(9)				(9)
Net income (loss)	285					285					138	[5]				138	86					86	88	[6]				88
Capital contributions from parent											200																(54)
Dividends and dividend equivalents	(178)	[7]				(178)	[7]									(74)						(31)						(35)
Dividends declared											(74)						(31)						(35)
Other comprehensive income (loss)	1							1
Balance at end of period - shares at Mar. 31, 2023			737,067	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Contributions from parent											200				200
Return of Capital to Parent																					(120)						(54)
Total Equity	14,036		$ 8		12,310	2,788		(123)	$ (950)	3	6,015		$ 364		4,284	1,367	3,101		$ 424		1,967	710	4,037		$ 308		2,987	742
Total Equity	$ 13,933		$ 8		12,326	2,710		(163)	(948)	0	$ 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		737,130	[1]							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 17				0				$ 17
Stock Issued During Period, Shares, Treasury Stock Reissued									606
Stock-based compensation	(12)				(12)
Net income (loss)	307					307					$ 149	[5]				149	$ 93	[8]				93	$ 108	[6]				108
Capital contributions from parent											675
Dividends and dividend equivalents	(189)	[7]				(189)	[7]									(88)						(37)						(47)
Dividends declared											$ (88)						$ (37)						$ (47)
Other comprehensive income (loss)	$ 2							2
Balance at end of period - shares at Mar. 31, 2024	737,736		737,736								66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Contributions from parent											$ 675				675
Return of Capital to Parent																					(51)						(50)
Total Equity	$ 14,058		$ 8		$ 12,314	$ 2,828		$ (161)	$ (931)	$ 0	$ 6,639		$ 364		$ 4,715	$ 1,560	$ 3,177		$ 424		$ 1,942	$ 811	$ 4,163		$ 308		$ 2,983	$ 872

[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 $0.2575 for the three months ended March 31, 2024 and $0.2400 for the three months ended March 31, 2023.

[8] Net income equals comprehensive income.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical) - vote	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Vote per share of PPL's common stock	1	1

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Segment and Related Information

3 Months Ended

Mar. 31, 2024

Segment Reporting [Abstract]

Segment and Related Information

2. Segment and Related Information

(PPL)

PPL is organized into three segments: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated. PPL's segments are determined by geographic location.

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

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

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

"Corporate and Other" primarily includes corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results.

Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended March 31 are as follows:

	Three Months
	2024		2023
Operating Revenues from external customers
Kentucky Regulated	$	984	$	960
Pennsylvania Regulated	770		891
Rhode Island Regulated	549		565
Corporate and Other	1		(1)
Total	$	2,304	$	2,415
Net Income (Loss)
Kentucky Regulated	$	190	$	166
Pennsylvania Regulated	149		138
Rhode Island Regulated	64		54
Corporate and Other	(96)		(73)
Total	$	307	$	285

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

	March 31, 2024		December 31, 2023
Assets
Kentucky Regulated	$	17,074	$	17,029
Pennsylvania Regulated	15,116		14,294
Rhode Island Regulated	6,614		6,515
Corporate and Other (a)	827		1,398
Total	$	39,631	$	39,236

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

(PPL Electric, LG&E and KU)

PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment. Each of LG&E and KU operate as a single operating and reportable segment.

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Earnings Per Share

3 Months Ended

Mar. 31, 2024

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.

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
	2024		2023
Income (Numerator)
Net income attributable to PPL	$	307	$	285
Less amounts allocated to participating securities	—		1
Net income available to PPL common shareowners - Basic and Diluted	$	307	$	284
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	737,512		736,829
Add: Dilutive share-based payment awards (a)	1,308		869
Weighted-average shares - Diluted EPS	738,820		737,698
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.42	$	0.39

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

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
	2024	2023
Stock-based compensation awards	—	534

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Income Taxes

3 Months Ended

Mar. 31, 2024

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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	81	$	76
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	17		22
Utility rate-making tax adjustments (a)	(5)		(5)
Amortization of excess deferred federal and state income taxes	(13)		(12)
Other	1		(2)
Total increase (decrease)	—		3
Total income tax expense (benefit)	$	81	$	79

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across all PPL utilities 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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	41	$	38
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14		14
Utility rate-making tax adjustments (a)	(4)		(4)
Amortization of excess deferred federal and state income taxes	(2)		(2)
Other	(1)		(1)
Total increase (decrease)	7		7
Total income tax expense (benefit)	$	48	$	45

(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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	25	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	4		4
Amortization of excess deferred federal and state income taxes	(3)		(3)
Other	(2)		(1)
Total increase (decrease)	(1)		—
Total income tax expense (benefit)	$	24	$	23

(KU)
	Three Months
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	28	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(5)		(4)
Other	(1)		(1)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	27	$	22

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.

Transfer of Certain Credits under the Inflation Reduction Act (PPL)

On April 25, 2024, the IRS released the final Internal Revenue Code Section 6418 regulations related to the transfer of certain credits under the Inflation Reduction Act. The regulations were published in the Federal Register on April 30, 2024, and will be effective on July 1, 2024. PPL is currently reviewing the final regulations to determine what impact the guidance may have on their financial statements.

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Utility Rate Regulation

3 Months Ended

Mar. 31, 2024

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, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Assets:
Rate adjustment mechanisms	$	129	$	118	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	15		14		—		—		—		—		—		—
Derivative instruments	29		51		—		—		—		—		—		—
Smart meter rider	6		6		6		6		—		—		—		—
Universal service rider	8		—		8		—		—		—		—		—
Storm damage costs	33		12		33		12		—		—		—		—
Gas supply clause	4		—		—		—		4		—		—		—
Fuel adjustment clause	12		4		—		—		6		3		6		—
Transmission service charge	36		43		26		31		—		—		—		—
Transmission formula rate	15		5		—		—		—		—		—		—
Distribution system improvement charge	8		7		8		7		—		—		—		—
Other	35		33		3		1		4		4		1		3
Total current regulatory assets	$	330	$	293	$	84	$	57	$	14	$	7	$	7	$	3
Noncurrent Regulatory Assets:
Defined benefit plans	$	880	$	887	$	417	$	417	$	212	$	217	$	134	$	136
Plant outage costs	36		38		—		—		9		10		27		28
Net metering	123		112		—		—		—		—		—		—
Environmental cost recovery	97		99		—		—		—		—		—		—
Storm costs	96		97		—		—		14		15		14		14
Unamortized loss on debt	22		22		3		3		10		10		7		7
Interest rate swaps	5		7		—		—		5		7		—		—
Terminated interest rate swaps	56		58		—		—		33		34		23		24
Accumulated cost of removal of utility plant	171		178		171		178		—		—		—		—
AROs	288		289		—		—		76		76		212		213
Derivatives instruments	4		8		—		—		—		—		—		—
Other	81		79		1		—		29		26		18		17
Total noncurrent regulatory assets	$	1,859	$	1,874	$	592	$	598	$	388	$	395	$	435	$	439

	PPL				PPL Electric				LG&E				KU
	March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Liabilities:
Generation supply charge	$	64	$	51	$	64	$	51	$	—	$	—	$	—	$	—
Tax Cuts and Jobs Act customer refund	—		5		—		5		—		—		—		—
Act 129 compliance rider	12		15		12		15		—		—		—		—
Transmission formula rate	17		21		14		18		—		—		—		—
Rate adjustment mechanism	68		72		—		—		—		—		—		—
Energy efficiency	25		23		—		—		—		—		—		—
Gas supply clause	—		15		—		—		—		15		—		—
Other	37		23		—		2		2		1		6		1
Total current regulatory liabilities	$	223	$	225	$	90	$	91	$	2	$	16	$	6	$	1
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,008	$	996	$	—	$	—	$	309	$	306	$	402	$	399
Power purchase agreement - OVEC	16		19		—		—		11		13		5		6
Net deferred taxes	1,960		1,977		759		763		454		459		517		523
Defined benefit plans	256		252		80		73		20		20		60		59
Terminated interest rate swaps	56		57		—		—		28		29		28		28
Energy efficiency	18		5		—		—		—		—		—		—
Other	37		34		—		—		2		—		4		3
Total noncurrent regulatory liabilities	$	3,351	$	3,340	$	839	$	836	$	824	$	827	$	1,016	$	1,018

Regulatory Matters

Rhode Island Activities (PPL)

Rate Case Proceedings

Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC.

The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5.

Advanced Metering Functionality (AMF)

In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory.

On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters.

Grid Modernization

RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023, to discuss the scope of the RIPUC’s review of the GMP and its potential impact future electric ISR plans. RIE cannot predict the outcome of this matter.

Petition for Deferral of Credit Card Fees

On January 31, 2024, RIE filed a petition to request approval to recognize regulatory assets related to the credit card, debit card, and related fees (Electronic Transaction Fees) that RIE has waived and will continue to waive on a going forward basis pursuant to the RIPUC orders in RIPUC Docket No. 5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its next base distribution rate case for the amortization/recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. The Rhode Island Division of Public Utilities and Carriers (the Division) and Intervenor testimony is due two weeks following the filing of RIE's Revised 2022 Earnings Reports, which RIE intends to file in the second quarter of 2024. RIE's rebuttal testimony is due two weeks following the Division's filing of its testimony. No hearings have been scheduled at this time. RIE simultaneously filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges pending in Docket No. 5154. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter.

FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan

At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. The RIPUC has not taken any action to date on this issue, including in its recent action on the FY 2025 Gas ISR Plan.

FY 2024 Gas ISR Plan

At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below.

FY 2025 Gas ISR Plan

On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), plus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

FY 2024 Electric ISR Plan

The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend.

On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below.

FY 2025 Electric ISR Plan

On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

Kentucky Activities (PPL, LG&E and KU)

KPSC Investigation Related to Winter Storm Elliott

On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties have been granted intervenor status for the proceeding and a hearing on the matter is scheduled for May 23, 2024. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition.

Pennsylvania Activities (PPL and PPL Electric)

PAPUC investigation into billing issues

On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC’s Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric’s hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E have 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The final approval of the Settlement Agreement is pending the issuance of the PAPUC's order and PPL Electric and I&E's decision on whether to accept the modifications. PPL Electric cannot predict the outcome of this matter.

PPL Electric incurred costs related to the billing issues of $15 million and $3 million for the three-month periods ended March 31, 2024 and March 31, 2023. PPL Electric will not seek regulatory recovery of these costs.

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. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. PPL Electric cannot predict the outcome of this matter.

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 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 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 proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April

24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. 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 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 a PAPUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three months ended March 31, 2024 and 2023, PPL Electric purchased $419 million and $358 million of accounts receivable from alternative suppliers.

(PPL)

In 2021 and 2022, the RIPUC approved various components of a Purchase of Receivables Program (POR) in Rhode Island for effect on April 1, 2022. Municipal aggregators and non-regulated power producers (collectively, Competitive Suppliers) are eligible to participate in accordance with RIE's approved electric tariffs for municipal aggregation and non-regulated power producers. Under the POR program, RIE will purchase the Competitive Suppliers' accounts receivables, including existing receivables, at discounted rates, regardless of whether RIE has collected the owed monies from customers. The program is intended to make RIE whole through the implementation of a discount rate or Standard Complete Bill Percentage (SCBP) paid by Competitive Suppliers. RIE calculates the SCBP for each customer class and files the calculations with the RIPUC for review and approval by February 15 of each year. At an Open Meeting on March 26, 2024, the RIPUC approved the SCBP for effect beginning on April 1, 2024, for a one-year period.

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Financing Activities

3 Months Ended

Mar. 31, 2024

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, 2024									December 31, 2023
	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. 2028	$	1,250	$	—	$	218	$	1,032	$	—	$	390
Bilateral Credit Facility	Feb. 2025	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2025	100		—		13		87		—		13
Total PPL Capital Funding Credit Facilities		$	1,450	$	—	$	231	$	1,219	$	—	$	403
PPL Electric
Syndicated Credit Facility	Dec. 2028	$	650	$	—	$	1	$	649	$	—	$	511
Total PPL Electric Credit Facilities		$	650	$	—	$	1	$	649	$	—	$	511
LG&E
Syndicated Credit Facility	Dec. 2028	$	500	$	—	$	28	$	472	$	—	$	—
Total LG&E Credit Facilities		$	500	$	—	$	28	$	472	$	—	$	—
KU
Syndicated Credit Facility	Dec. 2028	$	400	$	—	$	45	$	355	$	—	$	93
Total KU Credit Facilities		$	400	$	—	$	45	$	355	$	—	$	93

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

(b)The PPL Capital Funding $1.25 billion syndicated credit facility includes a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding at March 31, 2024. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At December 31, 2023, the borrowing sublimit for RIE was $250 million and a $1 billion sublimit for PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million 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.

(All Registrants)

PPL Capital Funding, RIE, PPL Electric, LG&E and KU 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, 2024							December 31, 2023
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a) (b)	5.51%	$	1,350	$	218	$	1,132	5.66%	$	365
RIE (b)		400		—		400		5.72%	25
PPL Electric		650		—		650		5.67%	510
LG&E	5.49%	500		28		472			—
KU	5.49%	400		45		355		5.64%	93
Total		$	3,300	$	291	$	3,009		$	993

(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, which has a total capacity of $1.25 billion. At March 31, 2024, the borrowing sublimits were $400 million for RIE and $850 million for PPL Capital Funding. At December 31, 2023, the borrowing sublimits under the facility were $250 million at RIE and $1 billion at 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.

Long-term Debt

(PPL)

In March 2024, RIE issued $500 million of 5.35% Senior Notes due 2034. RIE received proceeds of $496 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes.

(PPL and PPL Electric)

In January 2024, PPL Electric issued $650 million of 4.85% First Mortgage Bonds due 2034. PPL Electric received proceeds of $644 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes.

Dividends

In February 2024, PPL declared a quarterly cash dividend on its common stock, payable April 1, 2024, of 25.75 cents per share (equivalent to $1.03 per annum).

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Defined Benefits

3 Months Ended

Mar. 31, 2024

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
	2024		2023
PPL
Service cost	$	9	$	9
Interest cost	46		46
Expected return on plan assets	(75)		(78)
Amortization of:
Prior service cost	1		2
Actuarial loss	2		—
Net periodic defined benefit costs (credits)	$	(17)	$	(21)

	Other Postretirement Benefits
	Three Months
	2024		2023
PPL
Service cost	$	1	$	2
Interest cost	7		7
Expected return on plan assets	(7)		(8)
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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Related Party Transactions

3 Months Ended

Mar. 31, 2024

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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, 2024, CEP Reserves had $554 million of borrowings outstanding. At December 31, 2023, CEP Reserves had no borrowings outstanding. 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 applicable 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, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be 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, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $37 million. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. At December 31, 2023, KU had no borrowings outstanding from LG&E and/or LKE.

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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, 2024, CEP Reserves had $554 million of borrowings outstanding. At December 31, 2023, CEP Reserves had no borrowings outstanding. 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 applicable 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, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be 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, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $37 million. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. At December 31, 2023, KU had no borrowings outstanding from LG&E and/or LKE.

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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, 2024, CEP Reserves had $554 million of borrowings outstanding. At December 31, 2023, CEP Reserves had no borrowings outstanding. 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 applicable 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, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be 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, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $37 million. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. At December 31, 2023, KU had no borrowings outstanding from LG&E and/or LKE.

XML

Fair Value Measurements

3 Months Ended

Mar. 31, 2024

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 2023 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, 2024								December 31, 2023
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	276	$	276	$	—	$	—	$	331	$	331	$	—	$	—
Restricted cash and cash equivalents (a)	45		45		—		—		51		51		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	321		321		—		—		382		382		—		—
Special use funds (a):
Money market fund	2		2		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	7		—		—		—		9		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		2		—		—		18		1		—		—
Price risk management assets (d):
Gas contracts	1		—		1		—		1		—		1		—
Total assets	$	338	$	323	$	1	$	—	$	401	$	383	$	1	$	—
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Gas contracts	34		—		33		1		60		—		41		19
Total price risk management liabilities	$	39	$	—	$	38	$	1	$	67	$	—	$	48	$	19
PPL Electric
Assets
Cash and cash equivalents	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
Total assets	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	8	$	8	$	—	$	—	$	18	$	18	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		26		26		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	30		30		—		—		44		44		—		—
Total assets	$	30	$	30	$	—	$	—	$	44	$	44	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	14	$	14	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		24		24		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	34		34		—		—		38		38		—		—
Total assets	$	34	$	34	$	—	$	—	$	38	$	38	$	—	$	—

(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 asset" 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
2024
Balance at beginning of period	$	19
Settlements	(18)
Balance at end of period	$	1

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. 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 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 in 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, 2024				December 31, 2023
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	15,754	$	15,016	$	14,612	$	14,031
PPL Electric	5,211		5,023		4,567		4,475
LG&E	2,469		2,344		2,469		2,369
KU	3,064		2,832		3,064		2,861

(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.

XML

Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2024

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 forward starting interest rate swaps to hedge changes 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 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. 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 a counterparty's credit ratings fall below investment grade, their tangible net worth falls below specified percentages or its 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, 2024 and December 31, 2023.

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, 2024.

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, 2024 and 2023, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At March 31, 2024, 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. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023. At March 31, 2024, 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, 2024, RIE held contracts with notional volumes of 41 Bcf that range in maturity from 2024 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 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 and certain RIE commodity gas contracts that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023.

See Note 1 in each Registrant's 2023 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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	$	—	$	1	$	—	$	1
Gas contracts (a)	1		30		1		51
Total current	1		31		1		52
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	—		4		—		6
Gas contracts (a)	—		4		—		9
Total noncurrent	—		8		—		15
Total derivatives	$	1	$	39	$	1	$	67

(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, 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 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, 2023.

	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
Interest rate swaps	Interest expense	$	—
Gas contracts	Energy purchases	(2)
	Other income (expense) - net	1
	Total	$	(1)
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 assets - current	28
	Regulatory assets - noncurrent	(7)
	Total	$	20

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)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2023.

	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	$	164
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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	1
Total current	—		1		—		1
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		6
Total noncurrent	—		4		—		6
Total derivatives	$	—	$	5	$	—	$	7

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

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, 2023. 

	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)

(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, 2024
Derivatives
PPL	$	1	$	—	$	—	$	1	$	39	$	—	$	—	$	39
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, 2023
Derivatives
PPL	$	1	$	—	$	—	$	1	$	67	$	—	$	—	$	67
LG&E	—		—		—		—		7		—		—		7

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, such amounts would 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, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features was $28 million. At March 31, 2024, the aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $29 million.

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Asset Retirement Obligations

3 Months Ended

Mar. 31, 2024

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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Accumulated Other Comprehensive Income (Loss)

3 Months Ended

Mar. 31, 2024

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, 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)
December 31, 2022	$	3	$	2	$	(5)	$	(124)	$	(124)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		1		—		(1)		1
March 31, 2023	$	4	$	3	$	(5)	$	(125)	$	(123)

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	2024		2023		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, 2024

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, 2023 is derived from that Registrant's 2023 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 2023 Form 10-K. The results of operations for the three months ended March 31, 2024 are not necessarily indicative of the results to be expected for the full year ending December 31, 2024 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, 2024

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 2023 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, 2024		December 31, 2023
Cash and cash equivalents	$	276	$	331
Restricted cash - current (a)	45		1
Total Cash, Cash Equivalents and Restricted Cash	$	321	$	332

(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, 2024

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' 2023 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.

	2024 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)	$	2,304	$	770	$	476	$	525
Revenues derived from:
Alternative revenue programs (b)	7		(3)		2		5
Other (c)	(8)		(5)		(1)		(1)
Revenues from Contracts with Customers	$	2,303	$	762	$	477	$	529
	2023 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)	$	2,415	$	891	$	474	$	499
Revenues derived from:
Alternative revenue programs (b)	36		1		1		—
Other (c)	(4)		(2)		(1)		(1)
Revenues from Contracts with Customers	$	2,447	$	890	$	474	$	498

(a)PPL includes $549 million for the three months ended March 31, 2024 and $565 million for the three months ended March 31, 2023 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)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.

(c)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
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
2023
PA Regulated	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
KY Regulated	443		274		164		60		7		11		—		959
RI Regulated	229		101		9		215		—		—		45		599
Corp and Other	—		—		—		(1)		—		—		—		(1)
Total PPL	$	1,209	$	503	$	193	$	287	$	7	$	11	$	237	$	2,447

	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL Electric
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
2023	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
LG&E
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
2023	$	241	$	152	$	49	$	16	$	—	$	16	$	—	$	474
KU
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529
2023	$	202	$	123	$	115	$	44	$	7	$	7	$	—	$	498

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. 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.

As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location 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
	2024		2023
PPL (a)	$	42	$	21
PPL Electric (a)	28		10
LG&E	1		1
KU	1		—

(a)    2024 includes amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information.

The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers.

	PPL		PPL Electric		LG&E		KU
Contract liabilities at December 31, 2023	$	43	$	29	$	6	$	7
Contract liabilities at March 31, 2024	30		20		5		5
Revenue recognized during the three months ended March 31, 2024 that was included in the contract liability balance at December 31, 2023	25		11		6		7
Contract liabilities at December 31, 2022	$	34	$	23	$	5	$	6
Contract liabilities at March 31, 2023	46		35		5		5
Revenue recognized during the three months ended March 31, 2023 that was included in the contract liability balance at December 31, 2022	17		6		5		6

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.

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Acquisitions, Development and Divestitures

3 Months Ended

Mar. 31, 2024

Business Combinations [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) for approximately $3.8 billion. Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE).

In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA and Narragansett Electric have entered into a transition services agreement (TSA), pursuant to which the National Grid entities have 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 is for an initial two-year

term and certain aspects have been extended to the third quarter of 2024. TSA costs of $48 million and $58 million were incurred during the three months ended March 31, 2024 and 2023.

Commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island

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 2023 Form 10-K for a complete listing of those commitments. PPL incurred the following expenses related to some of the remaining commitments:

•RIE will 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) incurring costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $81 million and $54 million for the three months ended March 31, 2024 and 2023.

•RIE will not seek to recover in rates any markup charged by National Grid USA and/or its affiliates under the TSA which were $1 million and $2 million for the three months ended March 31, 2024 and 2023.

Developments (PPL, LG&E and KU)

Mill Creek Unit 5 Construction

In December 2022, LG&E and KU filed a Certificate of Public Convenience and Necessity (CPCN) with the KPSC requesting approval to construct a 640 MW net summer rating Natural Gas Combined Cycle (NGCC) combustion turbine at LG&E’s Mill Creek Generating Station. In November 2023, the KPSC issued an order approving the request as well as the requested AFUDC accounting treatment for associated financing costs relating to the NGCC. The new NGCC facility will be jointly owned by LG&E (31%) and KU (69%). In February 2024, LG&E and KU entered into agreements to begin construction. Total project costs are estimated at approximately $1.0 billion, including AFUDC. Commercial operation of the facility is anticipated to begin mid-2027.

See Note 7 in PPL's 2023 Form 10-K for additional information on the CPCN filing.

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Other Income (Expense) - net

3 Months Ended

Mar. 31, 2024

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
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	8	$	17
Interest income	9		9
AFUDC - equity component	9		6
Charitable contributions	(2)		(1)
Miscellaneous	(2)		(1)
Other Income (Expense) - net	$	22	$	30

(PPL Electric)

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

	Three Months
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	4	$	5
Interest income	1		4
AFUDC - equity component	5		4
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	9	$	12

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New Accounting Guidance Pending Adoption

3 Months Ended

Mar. 31, 2024

Accounting Policies [Abstract]

Accounting Standards Update and Change in Accounting Principle

17. New Accounting Guidance Pending Adoption

(All Registrants)

Improvements to Reportable Segment Disclosures

In November 2023, the FASB issued ASU 2023-07 which improves reportable segment disclosure requirements, primarily through enhanced disclosures about segment expenses. The standard also requires public entities to disclose the title and position of the Chief Operating Decision Maker (CODM) and explain how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. Disclosure of certain segment-related disclosures that previously were required only on an annual basis will be required in interim periods. In addition, public entities

that have a single reportable segment are required to provide disclosures required by the new ASU and existing segment disclosure in Topic 280 (Segment Reporting).

For public business entities, this guidance will be applied retrospectively to all prior periods presented in the financial statements and will be effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted.

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

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.

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Derivative Instruments and Hedging Activities (Policies)

3 Months Ended

Mar. 31, 2024

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, 2024

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, 2024		December 31, 2023
Cash and cash equivalents	$	276	$	331
Restricted cash - current (a)	45		1
Total Cash, Cash Equivalents and Restricted Cash	$	321	$	332

(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, 2024

Segment Reporting [Abstract]

Segment and Related Information

Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended March 31 are as follows:

	Three Months
	2024		2023
Operating Revenues from external customers
Kentucky Regulated	$	984	$	960
Pennsylvania Regulated	770		891
Rhode Island Regulated	549		565
Corporate and Other	1		(1)
Total	$	2,304	$	2,415
Net Income (Loss)
Kentucky Regulated	$	190	$	166
Pennsylvania Regulated	149		138
Rhode Island Regulated	64		54
Corporate and Other	(96)		(73)
Total	$	307	$	285

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

	March 31, 2024		December 31, 2023
Assets
Kentucky Regulated	$	17,074	$	17,029
Pennsylvania Regulated	15,116		14,294
Rhode Island Regulated	6,614		6,515
Corporate and Other (a)	827		1,398
Total	$	39,631	$	39,236

(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, 2024

Revenue from Contracts with Customers [Line Items]

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
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
2023
PA Regulated	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
KY Regulated	443		274		164		60		7		11		—		959
RI Regulated	229		101		9		215		—		—		45		599
Corp and Other	—		—		—		(1)		—		—		—		(1)
Total PPL	$	1,209	$	503	$	193	$	287	$	7	$	11	$	237	$	2,447

	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL Electric
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
2023	$	537	$	128	$	20	$	13	$	—	$	—	$	192	$	890
LG&E
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
2023	$	241	$	152	$	49	$	16	$	—	$	16	$	—	$	474
KU
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529
2023	$	202	$	123	$	115	$	44	$	7	$	7	$	—	$	498

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. 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.

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
	2024		2023
PPL (a)	$	42	$	21
PPL Electric (a)	28		10
LG&E	1		1
KU	1		—

(a)    2024 includes amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information.

Contract with Customer, Asset and Liability [Table Text Block]

The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers.

	PPL		PPL Electric		LG&E		KU
Contract liabilities at December 31, 2023	$	43	$	29	$	6	$	7
Contract liabilities at March 31, 2024	30		20		5		5
Revenue recognized during the three months ended March 31, 2024 that was included in the contract liability balance at December 31, 2023	25		11		6		7
Contract liabilities at December 31, 2022	$	34	$	23	$	5	$	6
Contract liabilities at March 31, 2023	46		35		5		5
Revenue recognized during the three months ended March 31, 2023 that was included in the contract liability balance at December 31, 2022	17		6		5		6

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2024

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
	2024		2023
Income (Numerator)
Net income attributable to PPL	$	307	$	285
Less amounts allocated to participating securities	—		1
Net income available to PPL common shareowners - Basic and Diluted	$	307	$	284
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	737,512		736,829
Add: Dilutive share-based payment awards (a)	1,308		869
Weighted-average shares - Diluted EPS	738,820		737,698
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.42	$	0.39

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

Common Stock Issuances

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
	2024	2023
Stock-based compensation awards	—	534

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2024

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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	81	$	76
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	17		22
Utility rate-making tax adjustments (a)	(5)		(5)
Amortization of excess deferred federal and state income taxes	(13)		(12)
Other	1		(2)
Total increase (decrease)	—		3
Total income tax expense (benefit)	$	81	$	79

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across all PPL utilities 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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	41	$	38
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14		14
Utility rate-making tax adjustments (a)	(4)		(4)
Amortization of excess deferred federal and state income taxes	(2)		(2)
Other	(1)		(1)
Total increase (decrease)	7		7
Total income tax expense (benefit)	$	48	$	45

(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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	25	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	4		4
Amortization of excess deferred federal and state income taxes	(3)		(3)
Other	(2)		(1)
Total increase (decrease)	(1)		—
Total income tax expense (benefit)	$	24	$	23

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
	2024		2023
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	28	$	23
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(5)		(4)
Other	(1)		(1)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	27	$	22

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Utility Rate Regulation (Tables)

3 Months Ended

Mar. 31, 2024

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, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Assets:
Rate adjustment mechanisms	$	129	$	118	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	15		14		—		—		—		—		—		—
Derivative instruments	29		51		—		—		—		—		—		—
Smart meter rider	6		6		6		6		—		—		—		—
Universal service rider	8		—		8		—		—		—		—		—
Storm damage costs	33		12		33		12		—		—		—		—
Gas supply clause	4		—		—		—		4		—		—		—
Fuel adjustment clause	12		4		—		—		6		3		6		—
Transmission service charge	36		43		26		31		—		—		—		—
Transmission formula rate	15		5		—		—		—		—		—		—
Distribution system improvement charge	8		7		8		7		—		—		—		—
Other	35		33		3		1		4		4		1		3
Total current regulatory assets	$	330	$	293	$	84	$	57	$	14	$	7	$	7	$	3
Noncurrent Regulatory Assets:
Defined benefit plans	$	880	$	887	$	417	$	417	$	212	$	217	$	134	$	136
Plant outage costs	36		38		—		—		9		10		27		28
Net metering	123		112		—		—		—		—		—		—
Environmental cost recovery	97		99		—		—		—		—		—		—
Storm costs	96		97		—		—		14		15		14		14
Unamortized loss on debt	22		22		3		3		10		10		7		7
Interest rate swaps	5		7		—		—		5		7		—		—
Terminated interest rate swaps	56		58		—		—		33		34		23		24
Accumulated cost of removal of utility plant	171		178		171		178		—		—		—		—
AROs	288		289		—		—		76		76		212		213
Derivatives instruments	4		8		—		—		—		—		—		—
Other	81		79		1		—		29		26		18		17
Total noncurrent regulatory assets	$	1,859	$	1,874	$	592	$	598	$	388	$	395	$	435	$	439

	PPL				PPL Electric				LG&E				KU
	March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Liabilities:
Generation supply charge	$	64	$	51	$	64	$	51	$	—	$	—	$	—	$	—
Tax Cuts and Jobs Act customer refund	—		5		—		5		—		—		—		—
Act 129 compliance rider	12		15		12		15		—		—		—		—
Transmission formula rate	17		21		14		18		—		—		—		—
Rate adjustment mechanism	68		72		—		—		—		—		—		—
Energy efficiency	25		23		—		—		—		—		—		—
Gas supply clause	—		15		—		—		—		15		—		—
Other	37		23		—		2		2		1		6		1
Total current regulatory liabilities	$	223	$	225	$	90	$	91	$	2	$	16	$	6	$	1
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,008	$	996	$	—	$	—	$	309	$	306	$	402	$	399
Power purchase agreement - OVEC	16		19		—		—		11		13		5		6
Net deferred taxes	1,960		1,977		759		763		454		459		517		523
Defined benefit plans	256		252		80		73		20		20		60		59
Terminated interest rate swaps	56		57		—		—		28		29		28		28
Energy efficiency	18		5		—		—		—		—		—		—
Other	37		34		—		—		2		—		4		3
Total noncurrent regulatory liabilities	$	3,351	$	3,340	$	839	$	836	$	824	$	827	$	1,016	$	1,018

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Financing Activities (Tables)

3 Months Ended

Mar. 31, 2024

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The following credit facilities were in place at:

	March 31, 2024									December 31, 2023
	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. 2028	$	1,250	$	—	$	218	$	1,032	$	—	$	390
Bilateral Credit Facility	Feb. 2025	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2025	100		—		13		87		—		13
Total PPL Capital Funding Credit Facilities		$	1,450	$	—	$	231	$	1,219	$	—	$	403
PPL Electric
Syndicated Credit Facility	Dec. 2028	$	650	$	—	$	1	$	649	$	—	$	511
Total PPL Electric Credit Facilities		$	650	$	—	$	1	$	649	$	—	$	511
LG&E
Syndicated Credit Facility	Dec. 2028	$	500	$	—	$	28	$	472	$	—	$	—
Total LG&E Credit Facilities		$	500	$	—	$	28	$	472	$	—	$	—
KU
Syndicated Credit Facility	Dec. 2028	$	400	$	—	$	45	$	355	$	—	$	93
Total KU Credit Facilities		$	400	$	—	$	45	$	355	$	—	$	93

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

(b)The PPL Capital Funding $1.25 billion syndicated credit facility includes a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding at March 31, 2024. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At December 31, 2023, the borrowing sublimit for RIE was $250 million and a $1 billion sublimit for PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million 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, 2024							December 31, 2023
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a) (b)	5.51%	$	1,350	$	218	$	1,132	5.66%	$	365
RIE (b)		400		—		400		5.72%	25
PPL Electric		650		—		650		5.67%	510
LG&E	5.49%	500		28		472			—
KU	5.49%	400		45		355		5.64%	93
Total		$	3,300	$	291	$	3,009		$	993

(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, which has a total capacity of $1.25 billion. At March 31, 2024, the borrowing sublimits were $400 million for RIE and $850 million for PPL Capital Funding. At December 31, 2023, the borrowing sublimits under the facility were $250 million at RIE and $1 billion at 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, 2024

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
	2024		2023
PPL
Service cost	$	9	$	9
Interest cost	46		46
Expected return on plan assets	(75)		(78)
Amortization of:
Prior service cost	1		2
Actuarial loss	2		—
Net periodic defined benefit costs (credits)	$	(17)	$	(21)

	Other Postretirement Benefits
	Three Months
	2024		2023
PPL
Service cost	$	1	$	2
Interest cost	7		7
Expected return on plan assets	(7)		(8)
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, 2024

Commitments and Contingencies Disclosure [Abstract]

Guarantees

The table below details guarantees provided as of March 31, 2024.

	Exposure at March 31, 2024			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	$	121	(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, a PPL indirect U.K. subsidiary, 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. Pursuant to the agreement, 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, pursuant to the agreement, subject to certain adjustments plus the support obligations provided by PPL under sale-leaseback financings.

(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 $86 million at March 31, 2024, consisting of LG&E's share of $60 million and KU's share of $26 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LG&E's and KU's 2023 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, 2024

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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
	2024		2023
PPL Electric from PPL Services	$	56	$	59
LG&E from LKS	29		32
LG&E from PPL Services	11		8
KU from LKS	38		41
KU from PPL Services	11		9

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Other Income (Expense) - net (Tables)

3 Months Ended

Mar. 31, 2024

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
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	8	$	17
Interest income	9		9
AFUDC - equity component	9		6
Charitable contributions	(2)		(1)
Miscellaneous	(2)		(1)
Other Income (Expense) - net	$	22	$	30

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
	2024		2023
Defined benefit plans - non-service credits (Note 9)	$	4	$	5
Interest income	1		4
AFUDC - equity component	5		4
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	9	$	12

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2024

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, 2024								December 31, 2023
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	276	$	276	$	—	$	—	$	331	$	331	$	—	$	—
Restricted cash and cash equivalents (a)	45		45		—		—		51		51		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	321		321		—		—		382		382		—		—
Special use funds (a):
Money market fund	2		2		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	7		—		—		—		9		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		2		—		—		18		1		—		—
Price risk management assets (d):
Gas contracts	1		—		1		—		1		—		1		—
Total assets	$	338	$	323	$	1	$	—	$	401	$	383	$	1	$	—
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Gas contracts	34		—		33		1		60		—		41		19
Total price risk management liabilities	$	39	$	—	$	38	$	1	$	67	$	—	$	48	$	19
PPL Electric
Assets
Cash and cash equivalents	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
Total assets	$	21	$	21	$	—	$	—	$	51	$	51	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	8	$	8	$	—	$	—	$	18	$	18	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		26		26		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	30		30		—		—		44		44		—		—
Total assets	$	30	$	30	$	—	$	—	$	44	$	44	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	7	$	—	$	7	$	—
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	14	$	14	$	—	$	—
Restricted cash and cash equivalents (a)	22		22		—		—		24		24		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	34		34		—		—		38		38		—		—
Total assets	$	34	$	34	$	—	$	—	$	38	$	38	$	—	$	—

(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 asset" 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
2024
Balance at beginning of period	$	19
Settlements	(18)
Balance at end of period	$	1

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, 2024				December 31, 2023
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	15,754	$	15,016	$	14,612	$	14,031
PPL Electric	5,211		5,023		4,567		4,475
LG&E	2,469		2,344		2,469		2,369
KU	3,064		2,832		3,064		2,861

(a)Amounts are net of debt issuance costs.

XML

Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2024

Mar. 31, 2023

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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	$	—	$	1	$	—	$	1
Gas contracts (a)	1		30		1		51
Total current	1		31		1		52
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps (a)	—		4		—		6
Gas contracts (a)	—		4		—		9
Total noncurrent	—		8		—		15
Total derivatives	$	1	$	39	$	1	$	67

(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, 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)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2023.

	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	$	164
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, 2024
Derivatives
PPL	$	1	$	—	$	—	$	1	$	39	$	—	$	—	$	39
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, 2023
Derivatives
PPL	$	1	$	—	$	—	$	1	$	67	$	—	$	—	$	67
LG&E	—		—		—		—		7		—		—		7

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, 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 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, 2023.

	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
Interest rate swaps	Interest expense	$	—
Gas contracts	Energy purchases	(2)
	Other income (expense) - net	1
	Total	$	(1)
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 assets - current	28
	Regulatory assets - noncurrent	(7)
	Total	$	20

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, 2024				December 31, 2023
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	1
Total current	—		1		—		1
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		6
Total noncurrent	—		4		—		6
Total derivatives	$	—	$	5	$	—	$	7

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, 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

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, 2023. 

	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)

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, 2024
Derivatives
PPL	$	1	$	—	$	—	$	1	$	39	$	—	$	—	$	39
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, 2023
Derivatives
PPL	$	1	$	—	$	—	$	1	$	67	$	—	$	—	$	67
LG&E	—		—		—		—		7		—		—		7

XML

Asset Retirement Obligations (Tables)

3 Months Ended

Mar. 31, 2024

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

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, 2023	$	158	$	85	$	66
Accretion	2		1		1
Obligations settled	(5)		(2)		(3)
Other	1		—		—
Balance at March 31, 2024	$	156	$	84	$	64

XML

Accumulated Other Comprehensive Income (Loss) (Tables)

3 Months Ended

Mar. 31, 2024

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, 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)
December 31, 2022	$	3	$	2	$	(5)	$	(124)	$	(124)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		1		—		(1)		1
March 31, 2023	$	4	$	3	$	(5)	$	(125)	$	(123)

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	2024		2023		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, 2024	Dec. 31, 2023
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	276	331
Restricted Cash, Current	45	1
Cash, Cash Equivalents and Restricted Cash	321	332
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	21	51
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	8	18
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	$ 12	$ 14

XML

Segment and Related Information (Details) $ in Millions		3 Months Ended
		Mar. 31, 2024 USD ($) Integer		Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 2,304		$ 2,415
Net income (loss)		307		285
Balance Sheet Data [Abstract]
Assets		39,631			$ 39,236
Segment (Numeric) [Abstract]
Goodwill		$ 2,247			2,247
Number of Reportable Segments | Integer		3
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 984		960
Net income (loss)		190		166
Balance Sheet Data [Abstract]
Assets		17,074			17,029
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		770		891
Net income (loss)		149		138
Balance Sheet Data [Abstract]
Assets		15,116			14,294
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		1		(1)
Net income (loss)		(96)		(73)
Balance Sheet Data [Abstract]
Assets		827			1,398
Rhode Island Regulated
Income Statement Data [Abstract]
Operating Revenues from external customers		549		565
Net income (loss)		64		54
Balance Sheet Data [Abstract]
Assets		6,614			6,515
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		770		891
Net income (loss)	[1]	149		138
Balance Sheet Data [Abstract]
Assets		$ 15,116			14,294
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		2
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 476		474
Net income (loss)		93	[2]	86
Balance Sheet Data [Abstract]
Assets		7,798			7,753
Segment (Numeric) [Abstract]
Goodwill		$ 389			389
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 525		499
Net income (loss)	[3]	108		$ 88
Balance Sheet Data [Abstract]
Assets		9,773			9,714
Segment (Numeric) [Abstract]
Goodwill		$ 607			$ 607
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		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, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	$ 2,304	$ 2,415
Alternative Revenue Programs	7	36
Other Revenue	(8)	(4)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	2,303	2,447
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	42	21
Contract with Customer, Liability	30	46	$ 43	$ 34
Contract with Customer, Liability, Revenue Recognized	25	17
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1,130	1,209
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	451	503
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	177	193
Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	272	287
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	11
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	252	237
Pennsylvania Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	770	891
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	762	890
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	426	537
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	106	128
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	20
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	205	192
Kentucky Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	984	960
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	989	959
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	443	443
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	267	274
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	161	164
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	97	60
Kentucky Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Kentucky Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	11
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	1	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1	(1)
Corporate and Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1	(1)
Corporate and Other [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	549	565
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	551	599
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	261	229
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	78	101
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	4	9
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	161	215
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	47	45
PPL Electric Utilities Corp [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	770	891
Alternative Revenue Programs	(3)	1
Other Revenue	(5)	(2)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	762	890
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	28	10
Contract with Customer, Liability	20	35	29	23
Contract with Customer, Liability, Revenue Recognized	11	6
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	426	537
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	106	128
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	20
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	205	192
Louisville Gas And Electric Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	476	474
Alternative Revenue Programs	2	1
Other Revenue	(1)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	477	474
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	1
Contract with Customer, Liability	5	5	6	5
Contract with Customer, Liability, Revenue Recognized	6	5
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	218	241
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	138	152
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	47	49
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	52	16
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	22	16
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	525	499
Alternative Revenue Programs	5	0
Other Revenue	(1)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	529	498
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	0
Contract with Customer, Liability	5	5	$ 7	$ 6
Contract with Customer, Liability, Revenue Recognized	7	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	225	202
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	129	123
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	114	115
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	46	44
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	9	7
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, 2024	Mar. 31, 2023
Income (Numerator) [Abstract]
Net income (loss)	$ 307	$ 285
Less amounts allocated to participating securities	0	1
Net Income (Loss) Available to Common Stockholders, Basic	307	284
Net income (loss) available to PPL common shareowners - Diluted	$ 307	$ 284
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	737,512	736,829
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	1,308	869
Weighted-average shares - Diluted EPS (in shares)	738,820	737,698
Income (Loss) from Continuing Operations after income taxes, Diluted	$ 0.42	$ 0.39
Income (Loss) from Continuing Operations After Income Taxes, Basic	0.42	0.39
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	0.42	0.39
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.42	$ 0.39
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	534

XML

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 81	$ 76
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	17	22
Depreciation and other items not normalized	(5)	(5)
Amortization of excess deferred income taxes	(13)	(12)
Other	1	(2)
Total increase (decrease)	0	3
Total income tax expense (benefit)	81	79
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	41	38
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	14	14
Depreciation and other items not normalized	(4)	(4)
Amortization of excess deferred income taxes	(2)	(2)
Other	(1)	(1)
Total increase (decrease)	7	7
Total income tax expense (benefit)	48	45
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	25	23
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	4	4
Amortization of excess deferred income taxes	(3)	(3)
Other	(2)	(1)
Total increase (decrease)	(1)	0
Total income tax expense (benefit)	24	23
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	28	23
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	5	4
Amortization of excess deferred income taxes	(5)	(4)
Other	(1)	(1)
Total increase (decrease)	(1)	(1)
Total income tax expense (benefit)	$ 27	$ 22

XML

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Current regulatory assets	$ 330	$ 293
Noncurrent regulatory assets	1,859	1,874
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	36	38
Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	15	5
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	36	43
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	880	887
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	96	97
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	22
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	5	7
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	56	58
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	171	178
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	288	289
Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	33	12
Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	12	4
Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	123	112
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	129	118
Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	29	51
Noncurrent regulatory assets	4	8
Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	15	14
Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	8	0
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	7
Other
Regulatory Assets [Line Items]
Current regulatory assets	35	33
Noncurrent regulatory assets	81	79
Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	97	99
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	84	57
Noncurrent regulatory assets	592	598
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] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	26	31
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	417	417
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	3
PPL Electric Utilities Corp [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
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	171	178
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	33	12
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
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] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent 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] | Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	8	0
PPL Electric Utilities Corp [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	7
PPL Electric Utilities Corp [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	3	1
Noncurrent regulatory assets	1	0
PPL Electric Utilities Corp [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	14	7
Noncurrent regulatory assets	388	395
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	9	10
Louisville Gas And Electric Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Louisville Gas And Electric Co [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
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	212	217
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	15
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	10	10
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	5	7
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	33	34
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	76
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] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	3
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] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent 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] | Universal Service Rider [Member]
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] | Other
Regulatory Assets [Line Items]
Current regulatory assets	4	4
Noncurrent regulatory assets	29	26
Louisville Gas And Electric Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Noncurrent regulatory assets	435	439
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	27	28
Kentucky Utilities Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Smart Meter Rider [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	134	136
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	14
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	7	7
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	23	24
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	212	213
Kentucky Utilities Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	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] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Universal Service Rider [Member]
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] | Other
Regulatory Assets [Line Items]
Current regulatory assets	1	3
Noncurrent regulatory assets	18	17
Kentucky Utilities Co [Member] | Environmental cost 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, 2024

Dec. 31, 2023

Regulatory Liabilities [Line Items]

Current regulatory liabilities

$ 223

$ 225

Noncurrent regulatory liabilities

$ 3,351

3,340

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, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Assets:
Rate adjustment mechanisms	$	129	$	118	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	15		14		—		—		—		—		—		—
Derivative instruments	29		51		—		—		—		—		—		—
Smart meter rider	6		6		6		6		—		—		—		—
Universal service rider	8		—		8		—		—		—		—		—
Storm damage costs	33		12		33		12		—		—		—		—
Gas supply clause	4		—		—		—		4		—		—		—
Fuel adjustment clause	12		4		—		—		6		3		6		—
Transmission service charge	36		43		26		31		—		—		—		—
Transmission formula rate	15		5		—		—		—		—		—		—
Distribution system improvement charge	8		7		8		7		—		—		—		—
Other	35		33		3		1		4		4		1		3
Total current regulatory assets	$	330	$	293	$	84	$	57	$	14	$	7	$	7	$	3
Noncurrent Regulatory Assets:
Defined benefit plans	$	880	$	887	$	417	$	417	$	212	$	217	$	134	$	136
Plant outage costs	36		38		—		—		9		10		27		28
Net metering	123		112		—		—		—		—		—		—
Environmental cost recovery	97		99		—		—		—		—		—		—
Storm costs	96		97		—		—		14		15		14		14
Unamortized loss on debt	22		22		3		3		10		10		7		7
Interest rate swaps	5		7		—		—		5		7		—		—
Terminated interest rate swaps	56		58		—		—		33		34		23		24
Accumulated cost of removal of utility plant	171		178		171		178		—		—		—		—
AROs	288		289		—		—		76		76		212		213
Derivatives instruments	4		8		—		—		—		—		—		—
Other	81		79		1		—		29		26		18		17
Total noncurrent regulatory assets	$	1,859	$	1,874	$	592	$	598	$	388	$	395	$	435	$	439

	PPL				PPL Electric				LG&E				KU
	March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023		March 31, 2024		December 31, 2023
Current Regulatory Liabilities:
Generation supply charge	$	64	$	51	$	64	$	51	$	—	$	—	$	—	$	—
Tax Cuts and Jobs Act customer refund	—		5		—		5		—		—		—		—
Act 129 compliance rider	12		15		12		15		—		—		—		—
Transmission formula rate	17		21		14		18		—		—		—		—
Rate adjustment mechanism	68		72		—		—		—		—		—		—
Energy efficiency	25		23		—		—		—		—		—		—
Gas supply clause	—		15		—		—		—		15		—		—
Other	37		23		—		2		2		1		6		1
Total current regulatory liabilities	$	223	$	225	$	90	$	91	$	2	$	16	$	6	$	1
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,008	$	996	$	—	$	—	$	309	$	306	$	402	$	399
Power purchase agreement - OVEC	16		19		—		—		11		13		5		6
Net deferred taxes	1,960		1,977		759		763		454		459		517		523
Defined benefit plans	256		252		80		73		20		20		60		59
Terminated interest rate swaps	56		57		—		—		28		29		28		28
Energy efficiency	18		5		—		—		—		—		—		—
Other	37		34		—		—		2		—		4		3
Total noncurrent regulatory liabilities	$	3,351	$	3,340	$	839	$	836	$	824	$	827	$	1,016	$	1,018

Regulatory Matters

Rhode Island Activities (PPL)

Rate Case Proceedings

Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC.

The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5.

Advanced Metering Functionality (AMF)

In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory.

On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters.

Grid Modernization

RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023, to discuss the scope of the RIPUC’s review of the GMP and its potential impact future electric ISR plans. RIE cannot predict the outcome of this matter.

Petition for Deferral of Credit Card Fees

On January 31, 2024, RIE filed a petition to request approval to recognize regulatory assets related to the credit card, debit card, and related fees (Electronic Transaction Fees) that RIE has waived and will continue to waive on a going forward basis pursuant to the RIPUC orders in RIPUC Docket No. 5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its next base distribution rate case for the amortization/recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. The Rhode Island Division of Public Utilities and Carriers (the Division) and Intervenor testimony is due two weeks following the filing of RIE's Revised 2022 Earnings Reports, which RIE intends to file in the second quarter of 2024. RIE's rebuttal testimony is due two weeks following the Division's filing of its testimony. No hearings have been scheduled at this time. RIE simultaneously filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges pending in Docket No. 5154. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter.

FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan

At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. The RIPUC has not taken any action to date on this issue, including in its recent action on the FY 2025 Gas ISR Plan.

FY 2024 Gas ISR Plan

At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below.

FY 2025 Gas ISR Plan

On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), plus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

FY 2024 Electric ISR Plan

The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend.

On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below.

FY 2025 Electric ISR Plan

On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024.

Kentucky Activities (PPL, LG&E and KU)

KPSC Investigation Related to Winter Storm Elliott

On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties have been granted intervenor status for the proceeding and a hearing on the matter is scheduled for May 23, 2024. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition.

Pennsylvania Activities (PPL and PPL Electric)

PAPUC investigation into billing issues

On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC’s Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric’s hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E have 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The final approval of the Settlement Agreement is pending the issuance of the PAPUC's order and PPL Electric and I&E's decision on whether to accept the modifications. PPL Electric cannot predict the outcome of this matter.

PPL Electric incurred costs related to the billing issues of $15 million and $3 million for the three-month periods ended March 31, 2024 and March 31, 2023. PPL Electric will not seek regulatory recovery of these costs.

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. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. PPL Electric cannot predict the outcome of this matter.

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 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 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 proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April

24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. 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 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 a PAPUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three months ended March 31, 2024 and 2023, PPL Electric purchased $419 million and $358 million of accounts receivable from alternative suppliers.

(PPL)

In 2021 and 2022, the RIPUC approved various components of a Purchase of Receivables Program (POR) in Rhode Island for effect on April 1, 2022. Municipal aggregators and non-regulated power producers (collectively, Competitive Suppliers) are eligible to participate in accordance with RIE's approved electric tariffs for municipal aggregation and non-regulated power producers. Under the POR program, RIE will purchase the Competitive Suppliers' accounts receivables, including existing receivables, at discounted rates, regardless of whether RIE has collected the owed monies from customers. The program is intended to make RIE whole through the implementation of a discount rate or Standard Complete Bill Percentage (SCBP) paid by Competitive Suppliers. RIE calculates the SCBP for each customer class and files the calculations with the RIPUC for review and approval by February 15 of each year. At an Open Meeting on March 26, 2024, the RIPUC approved the SCBP for effect beginning on April 1, 2024, for a one-year period.

Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

$ 64

51

TCJA customer refund [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

5

Act 129 Compliance Rider [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

12

15

Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

1,008

996

Power Purchase Agreement OVEC [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

16

19

Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

1,960

1,977

Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

256

252

Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

56

57

Energy efficiency charge

Regulatory Liabilities [Line Items]

Current regulatory liabilities

25

23

Noncurrent regulatory liabilities

18

5

Rate adjustment mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

68

72

Transmission Formula Rate [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

17

21

Gas supply clause [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

15

Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

37

23

Noncurrent regulatory liabilities

37

34

PPL Electric Utilities Corp [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

90

91

Noncurrent regulatory liabilities

839

836

PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

64

51

PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

5

PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

12

15

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] | Power Purchase Agreement OVEC [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

759

763

PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

80

73

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] | Transmission Formula Rate [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

14

18

PPL Electric Utilities Corp [Member] | Gas supply clause [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

2

Noncurrent regulatory liabilities

0

0

Louisville Gas And Electric Co [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

2

16

Noncurrent regulatory liabilities

824

827

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] | TCJA customer refund [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Act 129 Compliance Rider [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

309

306

Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

11

13

Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

454

459

Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

20

20

Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

28

29

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] | Transmission Formula Rate [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Gas supply clause [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

15

Louisville Gas And Electric Co [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

2

1

Noncurrent regulatory liabilities

2

0

Kentucky Utilities Co [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

6

1

Noncurrent regulatory liabilities

1,016

1,018

Kentucky Utilities Co [Member] | Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | TCJA customer refund [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Act 129 Compliance Rider [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

402

399

Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

5

6

Kentucky Utilities Co [Member] | Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

517

523

Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

60

59

Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

28

28

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] | Transmission Formula Rate [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Gas supply clause [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

6

1

Noncurrent regulatory liabilities

$ 4

$ 3

XML

Utility Rate Regulation - Regulatory Matters (Details) $ in Millions							1 Months Ended	3 Months Ended
	Mar. 26, 2024 USD ($)	Nov. 06, 2023 MW	Sep. 27, 2023 USD ($)	Mar. 29, 2023 USD ($)	Oct. 16, 2018	Aug. 24, 2018	Dec. 31, 2023 USD ($)	Mar. 31, 2024 USD ($)	Mar. 31, 2023 USD ($)	Mar. 31, 2016	Apr. 26, 2024	Apr. 25, 2024 USD ($)	Nov. 21, 2023 USD ($)
PPL Electric [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Billing Issues, Expenses Incurred								$ 15	$ 3
Distribution System Improvement Charge Cap								5.00%
PPL Electric [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase								$ 419	358
PPL Electric [Member] | Pennsylvania Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
PPL Electric Billing Issue, Civil Penalty to be Paid													$ 1
PPL Electric [Member] | Pennsylvania Public Utility Commission | Subsequent Event [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
PPL Electric Billing Issue, Donation to be Paid												$ 1
Requested Distribution System Improvement Charge Cap											9.00%
LGE [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
KU [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Rhode Island Energy | Rhode Island Public Uitilty Commsion
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity, Percentage						9.275%
RIPUC Approved FY 2024 Gas ISR Plan for capital investment spend				$ 163
Recovery Cap on Capital Investment Related to AMF Program			$ 153
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Vegetation management
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend				14
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Other O&M
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend				1
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend				$ 112
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Common equity percentage related to approved rate
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Percentage of common equity used on allowed ROE						51.00%
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%
Maximum Base ROE reset by FERC										11.74%
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]
FERC Granted ROE								11.74%
Rhode Island Energy | Rhode Island Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Capital Investment Spend on FY 2025 Gas ISR Plan							$ 185
Proposed Capital Investment Spend on FY 2025 Electric ISR Plan							141
Proposed Contingency Plan Spend on FY 2025 Gas ISR Plan							11
Approved Capital Investment Spend on FY 2025 Gas ISR Plan	$ 180
Approved Contingency Plan Spend on FY 2025 Gas ISR Plan	11
Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Approved Capital Investment Spend on FY 2025 Gas ISR Plan	168
Rhode Island Energy | Rhode Island Public Utility Commission | Paving Costs
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Approved Capital Investment Spend on FY 2025 Gas ISR Plan	12
Rhode Island Energy | Rhode Island Public Utility Commission | Vegetation management
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Proposed Capital Investment Spend on FY 2025 Electric ISR Plan							13
Approved Capital Investment Spend on FY 2025 Electric ISR Plan	13
Rhode Island Energy | Rhode Island Public Utility Commission | Other O&M
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Proposed Capital Investment Spend on FY 2025 Electric ISR Plan							$ 1
Approved Capital Investment Spend on FY 2025 Electric ISR Plan	1
Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Approved Capital Investment Spend on FY 2025 Electric ISR Plan	$ 132
PPL Electric Utilities Corp [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Billing Issues, Expenses Incurred								$ 15	3
Distribution System Improvement Charge Cap								5.00%
PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase								$ 419	$ 358
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
PPL Electric Billing Issue, Civil Penalty to be Paid													$ 1
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission | Subsequent Event [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
PPL Electric Billing Issue, Donation to be Paid												$ 1
Requested Distribution System Improvement Charge Cap											9.00%
Louisville Gas And Electric Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
New NGCC LG&E Planned Ownership Percentage		31.00%
Kentucky Utilities Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
New NGCC KU Planned Ownership Percentage		69.00%

XML

Utility Rate Regulation - Other (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 419	$ 358
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 419	$ 358

XML

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	$ 291	$ 993
PPL Capital Funding [Member]
Line of Credit Facility [Line Items]
Capacity	1,450
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	231	403
Unused Capacity	1,219
PPL Capital Funding [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	218	365
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	1,250
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	218	390
Unused Capacity	1,032
Line of Credit Facility, Borrowing Capacity Sublimit	850	1,000
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	218	365
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)	13	13
Unused Capacity	87
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	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
LGE [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	28	0
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
KU [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
KU [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	45	93
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
Rhode Island Energy | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	25
Rhode Island Energy | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit	400	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	25
PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	28	0
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	45	93
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	$ 93
Unused Capacity	$ 355

XML

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Short-term Debt [Line Items]
Capacity	$ 3,300
Commercial Paper Issuances (c)	291	$ 993
Unused Capacity	$ 3,009
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.51%	5.66%
Capacity	$ 1,350
Commercial Paper Issuances (c)	218	$ 365
Unused Capacity	1,132
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%
Capacity	$ 500
Commercial Paper Issuances (c)	28	$ 0
Unused Capacity	$ 472
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%	5.64%
Capacity	$ 400
Commercial Paper Issuances (c)	45	$ 93
Unused Capacity	355
Rhode Island Energy
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.72%
Capacity	400
Commercial Paper Issuances (c)	0	$ 25
Unused Capacity	400
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	$ 650
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%
Capacity	$ 500
Commercial Paper Issuances (c)	28	$ 0
Unused Capacity	$ 472
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%	5.64%
Capacity	$ 400
Commercial Paper Issuances (c)	45	$ 93
Unused Capacity	$ 355

XML

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended
	Mar. 31, 2024	Jan. 31, 2024	Dec. 31, 2023
Long-term Debt (Numeric) [Abstract]
Long-term debt due within one year	$ 1		$ 1
Long-term Debt, Excluding Current Maturities	15,753		14,611
PPL Electric [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	650
Borrowed	0		0
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
PPL Capital Funding [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	1,450
Borrowed	0		0
LGE [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	500
Borrowed	0		0
KU [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	400
Borrowed	0		0
Rhode Island Energy | First Mortgage Bond [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 500
Stated interest rate	5.35%
Proceeds from Issuance of First Mortgage Bond	$ 496
PPL Electric Utilities Corp [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	650
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	5,211		4,567
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
Louisville Gas And Electric Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	500
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	2,469		2,469
Kentucky Utilities Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	400
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	$ 3,064		$ 3,064

XML

Financing Activities - Equity Securities (Details)	1 Months Ended
	Feb. 29, 2024 $ / shares
Securities Financing Transaction [Line Items]
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03

XML

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended
	Feb. 29, 2024	Mar. 31, 2024	Mar. 31, 2023
Distributions (Numeric) [Abstract]
Current quarterly common stock dividend (in dollars per share)	$ 0.2575	$ 0.2575	$ 0.2400
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03

XML

Acquisitions, Development and Divestitures - Development (Details) $ in Millions			3 Months Ended			6 Months Ended
		Nov. 06, 2023 MW	Mar. 31, 2024 USD ($)		Mar. 31, 2023 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2023 USD ($)
Business Acquisition [Line Items]
Transition Service Agreement Cost			$ 48		$ 58
Goodwill			2,247				$ 2,247
Operating Revenues from external customers			2,304		2,415
Net income (loss)			307		285
Indemnification for Safari sale/leaseback			25
Louisville Gas And Electric Co [Member]
Business Acquisition [Line Items]
Goodwill			389				389
Operating Revenues from external customers			476		474
Net income (loss)			93	[1]	86
New NGCC LG&E Planned Ownership Percentage		31.00%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Kentucky Utilities Co [Member]
Business Acquisition [Line Items]
Goodwill			607				$ 607
Operating Revenues from external customers			525		499
Net income (loss)	[2]		108		88
New NGCC KU Planned Ownership Percentage		69.00%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Narragansett Electric
Business Acquisition [Line Items]
Total cash consideration						$ 3,800
Rhode Island Regulated
Business Acquisition [Line Items]
Operating Revenues from external customers			549		565
Net income (loss)			64		54
Corporate and Other [Member]
Business Acquisition [Line Items]
Operating Revenues from external customers			1		(1)
Net income (loss)			(96)		(73)
Rhode Island Energy | Rhode Island Energy TSA
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			81		54
Rhode Island Energy | Accrual for TSA Markup
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			1		$ 2
LGE [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
KU [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
LKE [Member]
Business Acquisition [Line Items]
ExpectedCapitalCostOfExpansionProject			$ 1,000

[1] Net income equals comprehensive income.

[2] Net income equals comprehensive income.

XML

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	$ 5	$ 3
Pension Plan [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	9	9
Interest cost	46	46
Expected return on plan assets	(75)	(78)
Amortization of: [Abstract]
Prior service cost	1	2
Actuarial loss	2	0
Net periodic defined benefit costs (credits)	(17)	(21)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	2
Interest cost	7	7
Expected return on plan assets	(7)	(8)
Amortization of: [Abstract]
Actuarial loss	(1)	(1)
Net periodic defined benefit costs (credits)	0	0
PPL Electric Utilities Corp [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	1	1
Louisville Gas And Electric Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	1	0
Kentucky Utilities Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	$ 1	$ 0

XML

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Claim By Former Affiliate [Abstract]
Period Over Which Distribution Adjustment Charge-related Costs Are amortized	10 years
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	98	$ 99
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, 2024	Mar. 31, 2023	Dec. 31, 2023
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (13)	$ (12)
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	$ 98		$ 99
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	(2)	(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	(3)	(3)
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (5)	$ (4)

XML

Commitments and Contingencies - Guarantees and Other Assurances (Details) - 3 months ended Mar. 31, 2024 £ 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
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | LGE [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			60
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | KU [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			26
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			121
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			86
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			60
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			$ 26
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, 2024	Mar. 31, 2023	Dec. 31, 2023
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from affiliates	$ 554		$ 0
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]	CEP Reserves, Inc		CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 56	$ 59
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	800
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	11	8
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	722
Louisville Gas And Electric Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	29	32
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 37		$ 0
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Affiliated Entity [Member]
Kentucky Utilities Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 11	9
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	568
Kentucky Utilities Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 38	$ 41

XML

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Other Income
Defined benefit plans - non-service credits	$ 8	$ 17
AFUDC - equity component	9	6
Miscellaneous	(2)	(1)
Other Expense
Charitable Contributions	(2)	(1)
Other Income (Expense) - net	22	30
Interest Income (Expense), Nonoperating, Net	9	9
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	4	5
AFUDC - equity component	5	4
Other Expense
Charitable Contributions	(1)	(1)
Other Income (Expense) - net	9	12
Interest Income (Expense), Nonoperating, Net	$ 1	$ 4

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, 2024	Dec. 31, 2023
Assets
Cash and cash equivalents	$ 276	$ 331
Restricted cash and cash equivalents	45	51
Total Cash, Cash Equivalents and Restricted Cash	321	382
Special Use Funds [Abstract]
Money market fund	2	1
Commingled debt fund measured at NAV	7	9
Commingled equity fund measured at NAV	7	8
Total special use funds	16	18
Gas Contracts	1	1
Price risk management assets:
Total Assets	338	401
Price risk management liabilities:
Interest rate swaps	5	7
Gas Contracts	34	60
Total price risk management liabilities	39	67
Level 1 [Member]
Assets
Cash and cash equivalents	276	331
Restricted cash and cash equivalents	45	51
Total Cash, Cash Equivalents and Restricted Cash	321	382
Special Use Funds [Abstract]
Money market fund	2	1
Total special use funds	2	1
Gas Contracts	0	0
Price risk management assets:
Total Assets	323	383
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	1	1
Price risk management assets:
Total Assets	1	1
Price risk management liabilities:
Interest rate swaps	5	7
Gas Contracts	33	41
Total price risk management liabilities	38	48
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	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	1	19
Total price risk management liabilities	1	19
Gas Contracts, Liability, Settlements	(18)
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	21	51
Price risk management assets:
Total Assets	21	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	21	51
Price risk management assets:
Total Assets	21	51
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	8	18
Restricted cash and cash equivalents	22	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
Price risk management liabilities:
Interest rate swaps	5	7
Total price risk management liabilities	5	7
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	8	18
Restricted cash and cash equivalents	22	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
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	7
Total price risk management liabilities	5	7
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	12	14
Restricted cash and cash equivalents	22	24
Total Cash, Cash Equivalents and Restricted Cash	34	38
Price risk management assets:
Total Assets	34	38
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	12	14
Restricted cash and cash equivalents	22	24
Total Cash, Cash Equivalents and Restricted Cash	34	38
Price risk management assets:
Total Assets	34	38
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, 2024	Dec. 31, 2023
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 15,754	$ 14,612
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	15,016	14,031
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,211	4,567
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,023	4,475
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	2,469	2,469
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	2,344	2,369
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	3,064	3,064
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 2,832	$ 2,861

XML

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
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, 2024 USD ($) Bcf	Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	$ 0	$ 0
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	1		1
Liability value	39		67
Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	1		1
Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	31		52
Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	8		15
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		1
Interest Rate Swaps [Member] | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	4		6
Gas Contract | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	1		1
Gas Contract | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Gas Contract | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	30		51
Gas Contract | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	4		9
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	41
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		7
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

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Derivative Instruments and Hedging Activities - Fair Values (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 1	$ 1
Liability value	39	67
Louisville Gas And Electric Co [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	$ 5	$ 7

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Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	$ 179	$ 164
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	22	30
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	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	(16)	(1)
Gain (loss) recognized as regulatory liabilities/assets	28	20
Asset value	1		$ 1
Liability value	39		67
Not Designated As Hedging Instruments [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]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		$ 0
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]		Interest Expense
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	2	$ (1)
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	$ (16)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	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	$ 4
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	22
Not Designated As Hedging Instruments [Member] | Gas Contracts | Other Nonoperating Income (Expense)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		1
Not Designated As Hedging Instruments [Member] | Gas Contracts | Purchased Power And Gas
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		(2)
Not Designated As Hedging Instruments [Member] | Gas Contract | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
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		(7)
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		28
Louisville Gas And Electric Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	26	25
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	2	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		7
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		1
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		6
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		1
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	4		$ 6
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	2	$ (1)
Kentucky Utilities Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	34	33
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	$ 2	$ 2

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Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
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	29
Derivative, Net Liability Position, Aggregate Fair Value	28
Treasury Derivatives [Member]
Assets [Abstract]
Gross	1	1
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	1	1
Liabilities [Abstract]
Gross	39	67
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	39	67
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		7
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 5	$ 7

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Derivative Instruments and Hedging Activities - Commodity Purchases (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Commodity Purchases [Line Items]
Liability value	$ 39	$ 67
Asset value	1	1
Other Current Assets
Commodity Purchases [Line Items]
Asset value	1	1
Other Current Assets | Gas Contract
Commodity Purchases [Line Items]
Asset value	1	1
Other Current Assets | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Current Liabilities
Commodity Purchases [Line Items]
Liability value	31	52
Other Current Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	30	51
Other Current Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value	1	1
Other Noncurrent Assets [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Gas Contract
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Liabilities
Commodity Purchases [Line Items]
Liability value	8	15
Other Noncurrent Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	4	9
Other Noncurrent Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value	$ 4	$ 6

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Asset Retirement Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2024 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 158
Accretion	2
Obligations settled	(5)
Asset Retirement Obligations, Period Change, Miscellaneous	1
Balance at End of Period	156
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	85
Accretion	1
Obligations settled	(2)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	84
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	66
Accretion	1
Obligations settled	(3)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	$ 64

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Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (163)	$ (124)
Amounts arising during the period	1	1
Reclassifications from AOCI	1	0
Net OCI during the period	2	1
Balance at end of period	(161)	(123)
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	6	3
Amounts arising during the period	0	0
Reclassifications from AOCI	1	1
Net OCI during the period	1	1
Balance at end of period	7	4
Equity Investees' OCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	3	2
Amounts arising during the period	1	1
Reclassifications from AOCI	0	0
Net OCI during the period	1	1
Balance at end of period	4	3
Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(168)	(124)
Amounts arising during the period	0	0
Reclassifications from AOCI	0	(1)
Net OCI during the period	0	(1)
Balance at end of period	(168)	(125)
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(4)	(5)
Amounts arising during the period	0	0
Reclassifications from AOCI	0	0
Net OCI during the period	0	0
Balance at end of period	$ (4)	$ (5)

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Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (179)	$ (164)
Other Income (Expense) - net	22	30
Income Tax Expense (Benefit)	(81)	(79)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(1)	0
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	0	1
Income Tax Expense (Benefit)	0	0
Total After-tax	0	1
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	0	1
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)