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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549 |
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| FORM 10-Q |
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| ☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the quarterly period ended June 30, 2023March 31, 2024 |
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the transition period from _________ to ___________ |
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Commission File Number | Registrant; State of Incorporation; Address and Telephone Number | IRS Employer Identification No. |
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| 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 |
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| 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 |
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| 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 |
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| 1-3464 | Kentucky Utilities Company (Exact name of Registrant as specified in its charter) (Kentucky and Virginia)Virginia
One Quality Street Lexington, KY 40507-1462 (502) 627-2000 | 61-0247570 |
Securities registered pursuant to Section 12(b) of the Act:
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| Title of each class | Trading Symbol:Symbol(s): | Name of each exchange on which registered |
| Common Stock of PPL Corporation | PPL | New York Stock Exchange |
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| 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.
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| 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).
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| 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.
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| | 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.
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| 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).
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| 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, 737,088,540737,740,859 shares outstanding at July 31, 2023.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 July 31, 2023.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 July 31, 2023.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 July 31, 2023.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 JUNE 30, 2023MARCH 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.
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| PART I. FINANCIAL INFORMATION | |
| | Item 1. Financial Statements | |
| | | PPL Corporation and Subsidiaries | |
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| | | PPL Electric Utilities Corporation and Subsidiaries | |
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| | | Louisville Gas and Electric Company | |
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| | | Kentucky Utilities Company | |
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| | Combined Notes to Condensed Financial Statements (Unaudited) | |
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| | Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations | |
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| PART II. OTHER INFORMATION | |
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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 will continuecontinues 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 Capital Funding and PPL Energy Holdings, which is the holding company of PPL Electric, PPL Energy Funding Corporation, PPL Capital Funding, LKE, Rhode Island Energy, PPL ServicesRIE and other subsidiaries.
PPL Capital Funding - PPL Capital Funding, Inc., a financing subsidiary of PPL that provides financing for the operations of PPL and certain subsidiaries. Debt issued by PPL Capital Funding is fully and unconditionally guaranteed as to payment by PPL.
PPL Electric - PPL Electric Utilities Corporation, a public utility subsidiary of PPL engaged in the regulated transmission and distribution of electricity in its Pennsylvania service area and that provides electricity supply to its retail customers in this area as a PLR.
PPL Energy Funding - PPL Energy Funding Corporation, a subsidiary of PPL and the parent holding company of PPL Global, LLC and other subsidiaries.
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 andEnergy Holdings formed for the parent holding companypurpose of RIE.acquiring Narragansett Electric to which certain interests of PPL Energy Holdings in the Narragansett Stock Purchase Agreement were assigned.
PPL Services - PPL Services Corporation, a subsidiary of PPL that provides administrative, management and support services to PPL and its subsidiaries.
PPL WPD Limited - a U.K. subsidiary of PPL Global, LLC. Prior to the sale of the U.K. utility business on June 14, 2021, PPL WPD Limited was an indirect parent to PPL WPD Limited Investments. PPL WPD Limited was not included in the sale of the U.K. utility business on June 14, 2021.
RIE - Rhode Island Energy, – the name under which Narragansett Electric will continuecontinues to provide services subsequent tosince its acquisition by PPL and its subsidiary, PPL Rhode Island Holdings LLC on May 25, 2022.
Other terms and abbreviations
£ - British pound sterling.
20222023 Form 10-K - Annual Report to the SEC on Form 10-K for the year ended December 31, 2022.2023.
Act 11 - Act 11 of 2012 that became effective in April 2012. The Pennsylvania legislation authorized the PUCPAPUC 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).
Act 129 Smart Meter program - PPL Electric's system wide meter replacement program that installs wireless digital meters that provide secure communication between PPL Electric and the meter as well as all related infrastructure.
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.
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.
If-Converted MethodIBEW - A method applied to calculate diluted EPS for a company with outstanding convertible debt. This method generally adds back the interest chargesInternational Brotherhood of the debt to net income and the convertible debt is assumed to have been converted to equity at the beginning of the period, and the resulting common shares are treated as outstanding shares for diluted EPS calculations.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.
MWac - megawatt, alternating current. The measure of the power output from a solar installation.
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 USAU.S. affiliate.
NERC - North American Electric Reliability Corporation.
NGCC - Natural gas combined cycle.
NPNS - the normal purchases and normal sales exception as permitted by derivative accounting rules. Derivatives that qualify for this exception may receive accrual accounting treatment.
OCI - other comprehensive income or loss.
OVEC - Ohio Valley Electric Corporation, located in Piketon, Ohio, an entity in which LG&E owns a 5.63% interest and KU owns a 2.50% interest, which are recorded at cost. OVEC owns and operates two coal-fired power plants, the Kyger Creek plant in Ohio and the Clifty Creek plant in Indiana, with combined capacities of 2,120 MW.
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.
PP&E - property, plant and equipment.
PPA(s) - power purchase agreement(s).
PPL EnergyPlus - prior to the June 1, 2015 spinoff, PPL Energy Supply, LLC, PPL EnergyPlus, LLC, a subsidiary of PPL Energy Supply that marketed and traded wholesale and retail electricity and gas and supplied energy and energy services in competitive markets.
PPL Energy Supply - prior to the June 1, 2015 spinoff, PPL Energy Supply, LLC, a subsidiary of PPL Energy Funding and the indirect parent company of PPL Montana, LLC.
PPL Montana - prior to the June 1, 2015 spinoff of PPL Energy Supply, PPL Montana, LLC, an indirect subsidiary of PPL Energy Supply that generated electricity for wholesale sales in Montana and the Pacific Northwest.
RAR – Retired Asset Recovery rider, established by KPSC orders in 2021 to provide for recovery of and return on the remaining investment in certain electric generating units upon their retirement over a ten-year period following retirement.
Registrant(s) - refers to the Registrants named on the cover of this Report (each a "Registrant" and collectively, the "Registrants").
Regulation S-X - SEC regulation governing the form and content of and requirements for financial statements required to be filed pursuant to the federal securities laws.
RIPUC - Rhode Island Public Utilities Commission, a three-member quasi-judicial tribunal with jurisdiction, powers, and duties to implement and enforce the standards of conduct under R.I. Gen. Laws § 39-1-27.6 and to hold investigations and hearings involving the rates, tariffs, tolls, and charges, and the sufficiency and reasonableness of facilities and accommodations of public utilities in the state of Rhode Island.
Riverstone - Riverstone Holdings LLC, a Delaware limited liability company and, as of December 6, 2016, ultimate parent company of the entities that own the competitive power generation business contributed to Talen Energy.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 itsthe 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.
Talen Energy- Talen Energy Corporation, the Delaware corporation formed to be the publicly traded company and owner of the competitive generation assets of PPL Energy Supply and certain affiliates of Riverstone, which as of December 6, 2016, became wholly owned by Riverstone.
Talen EnergyMarketing- Talen Energy Marketing, LLC, the successor name of PPL EnergyPlus after the spinoff of PPL Energy Supply that marketed and traded wholesale and retail electricity and gas, and supplied energy and energy services in competitive markets, after the June 1, 2015 spinoff of PPL Energy Supply.
TCJA - Tax Cuts and Jobs Act. Comprehensive U.S. federal tax legislation enacted on December 22, 2017.
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, Western Power DistributionWPD 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.
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 20222023 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 onin 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 warongoing conflicts in Ukraine;Ukraine and the Middle East;
•changes in political, regulatory or economic conditions in states regions or countriesregions where the Registrants or their subsidiaries conduct business;
•receipt ofthe ability to obtain necessary governmental permits and approvals;
•changes in state or federal tax lawlaws 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 heightened emphasisviews 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;
•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)
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| | | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| Operating Revenues | Operating Revenues | $ | 1,823 | | | $ | 1,696 | | | $ | 4,238 | | | $ | 3,478 | |
| | Operating Expenses | Operating Expenses | | | | |
| Operating Expenses | |
| Operating Expenses | |
| Operation | Operation | | | | |
| Operation | |
| Operation | |
| Fuel | |
| Fuel | |
| Fuel | Fuel | 167 | | | 229 | | | 368 | | | 441 | |
| Energy purchases | Energy purchases | 340 | | | 305 | | | 1,074 | | | 657 | |
| Other operation and maintenance | Other operation and maintenance | 609 | | | 560 | | | 1,168 | | | 993 | |
| Depreciation | Depreciation | 313 | | | 289 | | | 626 | | | 560 | |
| Taxes, other than income | Taxes, other than income | 89 | | | 70 | | | 199 | | | 130 | |
| Total Operating Expenses | Total Operating Expenses | 1,518 | | | 1,453 | | | 3,435 | | | 2,781 | |
| | Operating Income | Operating Income | 305 | | | 243 | | | 803 | | | 697 | |
| Operating Income | |
| Operating Income | |
| | Other Income (Expense) - net (Note 12) | |
| Other Income (Expense) - net (Note 12) | |
| Other Income (Expense) - net (Note 12) | Other Income (Expense) - net (Note 12) | 5 | | | 26 | | | 35 | | | 26 | |
| | Interest Expense | Interest Expense | 165 | | | 118 | | | 329 | | | 225 | |
| Interest Expense | |
| Interest Expense | |
| | Income Before Income Taxes | Income Before Income Taxes | 145 | | | 151 | | | 509 | | | 498 | |
| Income Before Income Taxes | |
| Income Before Income Taxes | |
| | Income Taxes | |
| Income Taxes | |
| Income Taxes | Income Taxes | 33 | | | 32 | | | 112 | | | 106 | |
| | | Net Income | Net Income | $ | 112 | | | $ | 119 | | | $ | 397 | | | $ | 392 | |
| | | Net Income | |
| | Net Income | |
| | Earnings Per Share of Common Stock: | |
| Earnings Per Share of Common Stock: | |
| Earnings Per Share of Common Stock: | Earnings Per Share of Common Stock: | |
| | | Basic and Diluted | Basic and Diluted | |
| | Basic and Diluted | |
| | Basic and Diluted | |
| Net Income Available to PPL Common Shareowners | |
| Net Income Available to PPL Common Shareowners | |
| Net Income Available to PPL Common Shareowners | Net Income Available to PPL Common Shareowners | $ | 0.15 | | | $ | 0.16 | | | $ | 0.54 | | | $ | 0.53 | |
| | Weighted-Average Shares of Common Stock Outstanding (in thousands) | Weighted-Average Shares of Common Stock Outstanding (in thousands) | | | | | | | |
| Weighted-Average Shares of Common Stock Outstanding (in thousands) | |
| Weighted-Average Shares of Common Stock Outstanding (in thousands) | | | | | | | | |
| Basic | Basic | 737,075 | | | 735,977 | | | 736,953 | | | 735,741 | |
| Diluted | Diluted | 738,177 | | | 736,769 | | | 737,938 | | | 736,478 | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
PPL Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars)
| | | |
| | | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| Net income | Net income | $ | 112 | | | $ | 119 | | | $ | 397 | | | $ | 392 | |
| | Other comprehensive income (loss): | Other comprehensive income (loss): | | | | |
| Other comprehensive income (loss): | |
| Other comprehensive income (loss): | |
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | |
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | |
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | Amounts arising during the period - gains (losses), net of tax (expense) benefit: | | | | |
| | Equity investees' other comprehensive income (loss), net of tax of $0, $0, $0, $0 | — | | | 1 | | | 1 | | | 2 | |
| Defined benefit plans: | | |
| Prior service costs, net of tax of $0, $0, $0, $0 | — | | | — | | | — | | | (1) | |
| Net actuarial gain (loss), net of tax of $5, ($7), $5, ($7) | (15) | | | 21 | | | (15) | | | 21 | |
| Equity investees' other comprehensive income (loss), net of tax of $0, $0 | |
| | Equity investees' other comprehensive income (loss), net of tax of $0, $0 | |
| | Equity investees' other comprehensive income (loss), net of tax of $0, $0 | |
| | Reclassifications from AOCI - (gains) losses, net of tax expense (benefit): | Reclassifications from AOCI - (gains) losses, net of tax expense (benefit): | | | | |
| | Qualifying derivatives, net of tax of ($1), ($1), ($1), ($1) | — | | | — | | | 1 | | | 1 | |
| | Reclassifications from AOCI - (gains) losses, net of tax expense (benefit): | |
| | Reclassifications from AOCI - (gains) losses, net of tax expense (benefit): | |
| | Qualifying derivatives, net of tax of $0, $0 | |
| | Qualifying derivatives, net of tax of $0, $0 | |
| | Qualifying derivatives, net of tax of $0, $0 | |
| | Defined benefit plans: | Defined benefit plans: | | | | |
| Prior service costs, net of tax of $0, $0, $0, $0 | 1 | | | — | | | 1 | | | 1 | |
| Net actuarial (gain) loss, net of tax of $1, ($2), $1, ($3) | — | | | 6 | | | (1) | | | 9 | |
| Defined benefit plans: | |
| Defined benefit plans: | |
| | Net actuarial (gain) loss, net of tax of $0, $0 | |
| | Net actuarial (gain) loss, net of tax of $0, $0 | |
| | Net actuarial (gain) loss, net of tax of $0, $0 | |
| | Total other comprehensive income (loss) | Total other comprehensive income (loss) | (14) | | | 28 | | | (13) | | | 33 | |
| | | Total other comprehensive income (loss) | |
| | Total other comprehensive income (loss) | |
| | Comprehensive income | Comprehensive income | $ | 98 | | | $ | 147 | | | $ | 384 | | | $ | 425 | |
| Comprehensive income | |
| Comprehensive income | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
PPL Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars)
| | | | | | | | | | | |
| Six Months Ended June 30, |
| | 2023 | | 2022 |
| Cash Flows from Operating Activities | | | |
| Net income | $ | 397 | | | $ | 392 | |
| | | |
| | | |
| Adjustments to reconcile net income to net cash provided by operating activities | | | |
| Depreciation | 626 | | | 560 | |
| Amortization | 39 | | | 15 | |
| Defined benefit plans - (income) expense | (36) | | | (8) | |
| Deferred income taxes and investment tax credits | 107 | | | 56 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Other | 25 | | | 45 | |
| Change in current assets and current liabilities | | | |
| Accounts receivable | (1) | | | (47) | |
| Accounts payable | (209) | | | 166 | |
| Unbilled revenues | 233 | | | 22 | |
| Fuel, materials and supplies | (30) | | | 23 | |
| Prepayments | (90) | | | (69) | |
| | | |
| Taxes payable | (31) | | | (41) | |
| Regulatory assets and liabilities, net | (57) | | | (211) | |
| Accrued interest | 44 | | | 1 | |
| Other | (50) | | | 97 | |
| Other operating activities | | | |
| Defined benefit plans - funding | (7) | | | (7) | |
| | | |
| Other assets | (97) | | | (74) | |
| Other liabilities | (21) | | | 59 | |
| | | |
| | | |
| Net cash provided by operating activities | 842 | | | 979 | |
| | | |
| Cash Flows from Investing Activities | | | |
| Expenditures for property, plant and equipment | (1,090) | | | (1,009) | |
| | | |
| | | |
| | | |
| Acquisition of Narragansett Electric, net of cash acquired | — | | | (3,674) | |
| | | |
| Other investing activities | (6) | | | — | |
| | | |
| | | |
| Net cash used in investing activities | (1,096) | | | (4,683) | |
| | | |
| Cash Flows from Financing Activities | | | |
| Issuance of long-term debt | 3,127 | | | — | |
| Retirement of long-term debt | (1,763) | | | — | |
| | | |
| | | |
| | | |
| Payment of common stock dividends | (348) | | | (453) | |
| | | |
| | | |
| | | |
| | | |
| Net increase (decrease) in short-term debt | (742) | | | 919 | |
| Other financing activities | (50) | | | 3 | |
| | | |
| | | |
| | | |
| Net cash provided by financing activities | 224 | | | 469 | |
| | | |
| | | |
| | | |
| Net Decrease in Cash, Cash Equivalents and Restricted Cash | (30) | | | (3,235) | |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 357 | | | 3,572 | |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 327 | | | $ | 337 | |
| Supplemental Disclosures of Cash Flow Information | | | |
| Significant non-cash transactions: | | | |
| Accrued expenditures for property, plant and equipment at June 30, | $ | 231 | | | $ | 195 | |
| | | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED BALANCE SHEETS
PPL Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | | | | | | | | |
| | June 30,
2023 | | December 31,
2022 |
| Assets | | | |
| | | |
| Current Assets | | | |
| Cash and cash equivalents | $ | 326 | | | $ | 356 | |
| Accounts receivable (less reserve: 2023, $103; 2022, $87) | | | |
| Customer | 979 | | | 896 | |
| Other | 70 | | | 150 | |
| Unbilled revenues (less reserve: 2023, $3; 2022, $6) | 322 | | | 552 | |
| Fuel, materials and supplies | 474 | | | 443 | |
| Prepayments | 189 | | | 92 | |
| Regulatory assets | 331 | | | 258 | |
| Other current assets | 34 | | | 77 | |
| | | |
| Total Current Assets | 2,725 | | | 2,824 | |
| | | |
| Property, Plant and Equipment | | | |
| Regulated utility plant | 37,743 | | | 36,961 | |
| Less: accumulated depreciation - regulated utility plant | 8,771 | | | 8,352 | |
| Regulated utility plant, net | 28,972 | | | 28,609 | |
| Non-regulated property, plant and equipment | 68 | | | 92 | |
| Less: accumulated depreciation - non-regulated property, plant and equipment | 22 | | | 46 | |
| Non-regulated property, plant and equipment, net | 46 | | | 46 | |
| Construction work in progress | 1,744 | | | 1,583 | |
| Property, Plant and Equipment, net | 30,762 | | | 30,238 | |
| | | |
| Other Noncurrent Assets | | | |
| Regulatory assets | 1,826 | | | 1,819 | |
| Goodwill | 2,247 | | | 2,248 | |
| Other intangibles | 309 | | | 313 | |
| | | |
| Other noncurrent assets (less reserve for accounts receivable: 2023, $1; 2022 $2) | 427 | | | 395 | |
| Total Other Noncurrent Assets | 4,809 | | | 4,775 | |
| | | |
| Total Assets | $ | 38,296 | | | $ | 37,837 | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED BALANCE SHEETS
PPL Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | | | | | | | | |
| | June 30,
2023 | | December 31,
2022 |
| Liabilities and Equity | | | |
| | | |
| Current Liabilities | | | |
| Short-term debt | $ | 243 | | | $ | 985 | |
| Long-term debt due within one year | 91 | | | 354 | |
| Accounts payable | 975 | | | 1,201 | |
| Taxes | 93 | | | 124 | |
| Interest | 141 | | | 97 | |
| Dividends | 173 | | | 166 | |
| Regulatory liabilities | 280 | | | 238 | |
| Other current liabilities | 509 | | | 624 | |
| | | |
| Total Current Liabilities | 2,505 | | | 3,789 | |
| | | |
| Long-term Debt | 14,481 | | | 12,889 | |
| | | |
| Deferred Credits and Other Noncurrent Liabilities | | | |
| Deferred income taxes | 3,138 | | | 3,007 | |
| Investment tax credits | 115 | | | 117 | |
| Accrued pension obligations | 192 | | | 206 | |
| Asset retirement obligations | 128 | | | 138 | |
| Regulatory liabilities | 3,421 | | | 3,412 | |
| Other deferred credits and noncurrent liabilities | 357 | | | 361 | |
| Total Deferred Credits and Other Noncurrent Liabilities | 7,351 | | | 7,241 | |
| | | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | | | |
| | | |
| Equity | | | |
| Common stock - $0.01 par value (a) | 8 | | | 8 | |
| Additional paid-in capital | 12,316 | | | 12,317 | |
| Treasury stock | (949) | | | (967) | |
| Earnings reinvested | 2,721 | | | 2,681 | |
| Accumulated other comprehensive loss | (137) | | | (124) | |
| Total Shareowners' Common Equity | 13,959 | | | 13,915 | |
| Noncontrolling interests | — | | | 3 | |
| Total Equity | 13,959 | | | 13,918 | |
| | | |
| Total Liabilities and Equity | $ | 38,296 | | | $ | 37,837 | |
(a)1,560,000 shares authorized, 770,013 shares issued and 737,086 shares outstanding at June 30, 2023. 1,560,000 shares authorized, 770,013 shares issued and 736,487 shares outstanding at December 31, 2022.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
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 |
| March 31, 2023 | 737,067 | | $ | 8 | | $ | 12,310 | | $ | (950) | | $ | 2,788 | | $ | (123) | | $ | 3 | | $ | 14,036 | |
| | | | | | | | |
| Treasury stock issued | 19 | | | 1 | | 1 | | | | | 2 | |
| Stock-based compensation | | | 5 | | | | | | 5 | |
| Net income | | | | | 112 | | | | 112 | |
| Dividends and dividend equivalents (b) | | | | | (179) | | | | (179) | |
| Preferred stock (Note 7) | | | | | | | (3) | | (3) | |
| Other comprehensive income | | | | | | (14) | | | (14) | |
| | | | | | | | |
| June 30, 2023 | 737,086 | | $ | 8 | | $ | 12,316 | | $ | (949) | | $ | 2,721 | | $ | (137) | | $ | — | | $ | 13,959 | |
| | | | | | | | |
| December 31, 2022 | 736,487 | | $ | 8 | | $ | 12,317 | | $ | (967) | | $ | 2,681 | | $ | (124) | | $ | 3 | | $ | 13,918 | |
| | | | | | | | |
| Treasury stock issued | 599 | | | 3 | | 18 | | | | | 21 | |
| Stock-based compensation | | | (4) | | | | | | (4) | |
| Net income | | | | | 397 | | | | 397 | |
| Dividends and dividend equivalents (b) | | | | | (357) | | | | (357) | |
| Preferred stock (Note 7) | | | | | | | (3) | | (3) | |
| Other comprehensive income | | | | | | (13) | | | (13) | |
| | | | | | | | |
| June 30, 2023 | 737,086 | | $ | 8 | | $ | 12,316 | | $ | (949) | | $ | 2,721 | | $ | (137) | | $ | — | | $ | 13,959 | |
| | | | | | | | |
| March 31, 2022 | 735,765 | | $ | 8 | | $ | 12,299 | | $ | (987) | | $ | 2,697 | | $ | (152) | | $ | — | | $ | 13,865 | |
| Common stock issued | | | 8 | | | | | 8 | |
| Treasury stock issued | 392 | | | | 11 | | | | | 11 | |
| Stock-based compensation | | | 6 | | | | | 6 | |
| Net income | | | | | 119 | | | | 119 | |
| Dividends and dividend equivalents (b) | | | | | (167) | | | | (167) | |
| Preferred stock | | | | | | | 3 | 3 | |
| Other comprehensive income | | | | | | 28 | | | 28 | |
| | | | | | | | |
| June 30, 2022 | 736,157 | | $ | 8 | | $ | 12,313 | | $ | (976) | | $ | 2,649 | | $ | (124) | | $ | 3 | | $ | 13,873 | |
| | | | | | | | |
| December 31, 2021 | 735,112 | | $ | 8 | | $ | 12,303 | | $ | (1,003) | | $ | 2,572 | | $ | (157) | | $ | — | | $ | 13,723 | |
| Common stock issued | 123 | | | 12 | | | | | | 12 | |
| Treasury stock issued | 922 | | | | 27 | | | | | 27 | |
| Stock-based compensation | | | (2) | | | | | | (2) | |
| Net income | | | | | 392 | | | | 392 | |
| Dividends and dividend equivalents (b) | | | | | (315) | | | | (315) | |
| Preferred stock | | | | | | | 3 | 3 | |
| Other comprehensive income | | | | | | 33 | | | 33 | |
| | | | | | | | |
| June 30, 2022 | 736,157 | | $ | 8 | | $ | 12,313 | | $ | (976) | | $ | 2,649 | | $ | (124) | | $ | 3 | | $ | 13,873 | |
| | | | | | | | |
(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 $0.240 and $0.480 for the three and six months ended June 30, 2023 and $0.225 and $0.425 for the three and six months ended June 30, 2022.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
| | |
THIS PAGE INTENTIONALLY LEFT BLANK. |
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
PPL Electric Utilities Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars)
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2023 | | 2022 | | 2023 | | 2022 |
| Operating Revenues | $ | 667 | | | $ | 676 | | | $ | 1,558 | | | $ | 1,451 | |
| | | | | | | |
| Operating Expenses | | | | | | | |
| Operation | | | | | | | |
| Energy purchases | 204 | | | 218 | | | 562 | | | 474 | |
| | | | | | | |
| Other operation and maintenance | 141 | | | 128 | | | 303 | | | 288 | |
| Depreciation | 99 | | | 99 | | | 198 | | | 197 | |
| Taxes, other than income | 30 | | | 32 | | | 74 | | | 69 | |
| Total Operating Expenses | 474 | | | 477 | | | 1,137 | | | 1,028 | |
| | | | | | | |
| Operating Income | 193 | | | 199 | | | 421 | | | 423 | |
| | | | | | | |
| Other Income (Expense) - net (Note 12) | 9 | | | 7 | | | 21 | | | 13 | |
| | | | | | | |
| Interest Income from Affiliate | — | | | 2 | | | — | | | 4 | |
| | | | | | | |
| Interest Expense | 54 | | | 40 | | | 111 | | | 79 | |
| | | | | | | |
| Income Before Income Taxes | 148 | | | 168 | | | 331 | | | 361 | |
| | | | | | | |
| Income Taxes | 38 | | | 44 | | | 83 | | | 94 | |
| | | | | | | |
| Net Income (a) | $ | 110 | | | $ | 124 | | | $ | 248 | | | $ | 267 | |
(a)Net income equals comprehensive income.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
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.
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.
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.
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.
| | |
| THIS PAGE INTENTIONALLY LEFT BLANK. |
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
PPL Electric Utilities Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars)
| | | | | | | | | | | |
| | Six Months Ended June 30, |
| | 2023 | | 2022 |
| Cash Flows from Operating Activities | | | |
| Net income | $ | 248 | | | $ | 267 | |
| Adjustments to reconcile net income to net cash provided by operating activities | | | |
| Depreciation | 198 | | | 197 | |
| Amortization | 18 | | | 5 | |
| Defined benefit plans - expense (income) | (22) | | | (11) | |
| Deferred income taxes and investment tax credits | 54 | | | 67 | |
| Other | (9) | | | (9) | |
| Change in current assets and current liabilities | | | |
| Accounts receivable | (136) | | | (55) | |
| Accounts payable | (69) | | | 18 | |
| Unbilled revenues | 119 | | | 8 | |
| Materials and supplies | (21) | | | (5) | |
| Prepayments | (55) | | | (52) | |
| Regulatory assets and liabilities, net | (39) | | | (73) | |
| Taxes payable | (36) | | | (23) | |
| Counterparty collateral | — | | | 62 | |
| Other | 16 | | | (9) | |
| Other operating activities | | | |
| Defined benefit plans - funding | (1) | | | — | |
| Other assets | (28) | | | (25) | |
| Other liabilities | (1) | | | (7) | |
| Net cash provided by operating activities | 236 | | | 355 | |
| | | |
| Cash Flows from Investing Activities | | | |
| Expenditures for property, plant and equipment | (395) | | | (451) | |
| Expenditures for intangible assets | (3) | | | — | |
| Notes receivable from affiliates | — | | | 333 | |
| Other investing activities | — | | | 1 | |
| Net cash used in investing activities | (398) | | | (117) | |
| | | |
| Cash Flows from Financing Activities | | | |
| Issuance of long-term debt | 1,329 | | | — | |
| Retirement of long-term debt | (1,150) | | | — | |
| Contributions from parent | 200 | | | — | |
| Return of capital to parent | (25) | | | (65) | |
| Payment of common stock dividends to parent | (163) | | | (165) | |
| Net decrease in short-term debt | (15) | | | — | |
| Debt issuance costs | (13) | | | — | |
| | | |
| Net cash provided by (used in) financing activities | 163 | | | (230) | |
| | | |
| Net Increase in Cash, Cash Equivalents and Restricted Cash | 1 | | | 8 | |
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 25 | | | 21 | |
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 26 | | | $ | 29 | |
| | | |
| Supplemental Disclosure of Cash Flow Information | | | |
| Significant non-cash transactions: | | | |
| Accrued expenditures for property, plant and equipment at June 30, | $ | 124 | | | $ | 114 | |
| | | | | | | | | | | | | | | |
| | | | 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.
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.
CONDENSED CONSOLIDATED BALANCE SHEETS
PPL Electric Utilities Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Assets | Assets | | | | Assets | | | |
| | Current Assets | Current Assets | | | |
| Current Assets | |
| Current Assets | | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 26 | | | $ | 25 | |
| Accounts receivable (less reserve: 2023, $40; 2022, $28) | | | |
| Accounts receivable (less reserve: 2024, $57; 2023, $46) | | Accounts receivable (less reserve: 2024, $57; 2023, $46) | | | |
| Customer | Customer | 488 | | | 357 | |
| Other | Other | 10 | | | 12 | |
| Accounts receivable from affiliates | Accounts receivable from affiliates | 10 | | | 3 | |
| | Unbilled revenues (less reserve: 2023, $2; 2022, $2) | 108 | | | 224 | |
| Notes receivable from affiliate | |
| Unbilled revenues (less reserve: 2024, $2; 2023, $2) | |
| Materials and supplies | Materials and supplies | 90 | | | 69 | |
| Prepayments | Prepayments | 96 | | | 34 | |
| Regulatory assets | Regulatory assets | 49 | | | 13 | |
| Other current assets | Other current assets | 20 | | | 22 | |
| Total Current Assets | Total Current Assets | 897 | | | 759 | |
| | Property, Plant and Equipment | |
| Property, Plant and Equipment | |
| Property, Plant and Equipment | Property, Plant and Equipment | | | | | | |
| Regulated utility plant | Regulated utility plant | 15,139 | | | 14,794 | |
| Less: accumulated depreciation - regulated utility plant | Less: accumulated depreciation - regulated utility plant | 3,684 | | | 3,544 | |
| Regulated utility plant, net | Regulated utility plant, net | 11,455 | | | 11,250 | |
| | Construction work in progress | Construction work in progress | 628 | | | 593 | |
| | Construction work in progress | |
| | Construction work in progress | |
| Property, Plant and Equipment, net | Property, Plant and Equipment, net | 12,083 | | | 11,843 | |
| | Other Noncurrent Assets | |
| Other Noncurrent Assets | |
| Other Noncurrent Assets | Other Noncurrent Assets | | | | | | |
| Regulatory assets | Regulatory assets | 552 | | | 568 | |
| Intangibles | Intangibles | 268 | | | 269 | |
| | Other noncurrent assets (less reserve for accounts receivable: 2023, $1; 2022, $2) | 129 | | | 126 | |
| Other noncurrent assets (less reserve for accounts receivable: 2024, $3; 2023, $2) | |
| Other noncurrent assets (less reserve for accounts receivable: 2024, $3; 2023, $2) | |
| Other noncurrent assets (less reserve for accounts receivable: 2024, $3; 2023, $2) | |
| Total Other Noncurrent Assets | Total Other Noncurrent Assets | 949 | | | 963 | |
| | Total Assets | Total Assets | $ | 13,929 | | | $ | 13,565 | |
| Total Assets | |
| Total Assets | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED BALANCE SHEETS
PPL Electric Utilities Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Liabilities and Equity | Liabilities and Equity | | | | Liabilities and Equity | | | |
| | Current Liabilities | Current Liabilities | | | |
| Current Liabilities | |
| Current Liabilities | | | | |
| Short-term debt | Short-term debt | $ | 130 | | | $ | 145 | |
| Long-term debt due within one year | 90 | | | 340 | |
| | Accounts payable | |
| Accounts payable | |
| Accounts payable | Accounts payable | 386 | | | 480 | |
| Accounts payable to affiliates | Accounts payable to affiliates | 32 | | | 16 | |
| Taxes | Taxes | — | | | 36 | |
| Interest | Interest | 57 | | | 35 | |
| Regulatory liabilities | Regulatory liabilities | 82 | | | 85 | |
| | Other current liabilities | Other current liabilities | 88 | | | 86 | |
| Other current liabilities | |
| Other current liabilities | |
| Total Current Liabilities | Total Current Liabilities | 865 | | | 1,223 | |
| | Long-term Debt | Long-term Debt | 4,565 | | | 4,146 | |
| Long-term Debt | |
| Long-term Debt | |
| | Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | | | | | | |
| Deferred income taxes | Deferred income taxes | 1,568 | | | 1,514 | |
| Regulatory liabilities | Regulatory liabilities | 835 | | | 820 | |
| Other deferred credits and noncurrent liabilities | Other deferred credits and noncurrent liabilities | 85 | | | 111 | |
| Total Deferred Credits and Other Noncurrent Liabilities | Total Deferred Credits and Other Noncurrent Liabilities | 2,488 | | | 2,445 | |
| | Commitments and Contingent Liabilities (Notes 6 and 10) | Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | | | | |
| | Equity | |
| Equity | |
| Equity | Equity | | | | | | |
| Common stock - no par value (a) | Common stock - no par value (a) | 364 | | | 364 | |
| Additional paid-in capital | Additional paid-in capital | 4,259 | | | 4,084 | |
| Earnings reinvested | Earnings reinvested | 1,388 | | | 1,303 | |
| Total Equity | Total Equity | 6,011 | | | 5,751 | |
| | Total Liabilities and Equity | Total Liabilities and Equity | $ | 13,929 | | | $ | 13,565 | |
| Total Liabilities and Equity | |
| Total Liabilities and Equity | |
(a)170,000 shares authorized; 66,368 shares issued and outstanding at June 30, 2023March 31, 2024 and December 31, 2022.2023.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY
PPL Electric Utilities Corporation and Subsidiaries
(Unaudited)
(Millions of Dollars)
| | Common
stock
shares
outstanding
(a) | | | Common
stock
shares
outstanding
(a) | | Common
stock | | Additional
paid-in
capital | | Earnings
reinvested | | Total |
| | | Common
stock
shares
outstanding
(a) | | Common
stock | | Additional
paid-in
capital | | Earnings
reinvested | | Total |
| March 31, 2023 | 66,368 | | | $ | 364 | | | $ | 4,284 | | | $ | 1,367 | | | $ | 6,015 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| Net income | Net income | | 110 | | | 110 | |
| Capital contributions from parent | |
| | Return of capital to parent | | (25) | | | (25) | |
| Dividends declared | Dividends declared | | (89) | | | (89) | |
| June 30, 2023 | 66,368 | | | $ | 364 | | | $ | 4,259 | | | $ | 1,388 | | | $ | 6,011 | |
| Dividends declared | |
| Dividends declared | |
| March 31, 2024 | |
| | December 31, 2022 | |
| | December 31, 2022 | |
| | | December 31, 2022 | December 31, 2022 | 66,368 | | | $ | 364 | | | $ | 4,084 | | | $ | 1,303 | | | $ | 5,751 | |
| Net income | Net income | | 248 | | | 248 | |
| Capital contributions from parent | Capital contributions from parent | | 200 | | | 200 | |
| Return of capital to parent | | (25) | | | (25) | |
| | Dividends declared | Dividends declared | | (163) | | | (163) | |
| June 30, 2023 | 66,368 | | | $ | 364 | | | $ | 4,259 | | | $ | 1,388 | | | $ | 6,011 | |
| | March 31, 2022 | 66,368 | | | $ | 364 | | | $ | 4,214 | | | $ | 1,189 | | | $ | 5,767 | |
| Net income | | 124 | | | 124 | |
| | Return of capital to parent | | (25) | | | (25) | |
| Dividends declared | Dividends declared | | (93) | | | (93) | |
| June 30, 2022 | 66,368 | | | $ | 364 | | | $ | 4,189 | | | $ | 1,220 | | | $ | 5,773 | |
| | December 31, 2021 | 66,368 | | | $ | 364 | | | $ | 4,254 | | | $ | 1,118 | | | $ | 5,736 | |
| Net income | | 267 | | | 267 | |
| | Return of capital to parent | | (65) | | | (65) | |
| Dividends declared | Dividends declared | | (165) | | | (165) | |
| June 30, 2022 | 66,368 | | | $ | 364 | | | $ | 4,189 | | | $ | 1,220 | | | $ | 5,773 | |
| March 31, 2023 | |
(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.
| | |
THIS PAGE INTENTIONALLY LEFT BLANK.
|
CONDENSED STATEMENTS OF INCOME
Louisville Gas and Electric Company
(Unaudited)
(Millions of Dollars)
| | | |
| | | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| Operating Revenues | Operating Revenues | | | | | | | |
| Retail and wholesale | Retail and wholesale | $ | 347 | | | $ | 399 | | | $ | 808 | | | $ | 880 | |
| Retail and wholesale | |
| Retail and wholesale | |
| Electric revenue from affiliate | Electric revenue from affiliate | 8 | | | 11 | | | 21 | | | 23 | |
| Total Operating Revenues | Total Operating Revenues | 355 | | | 410 | | | 829 | | | 903 | |
| | Operating Expenses | |
| Operating Expenses | |
| Operating Expenses | Operating Expenses | | | | | | | | | | | | | | |
| Operation | Operation | | | | | | | | Operation | | | | | | | |
| Fuel | Fuel | 68 | | | 90 | | | 147 | | | 171 | |
| Energy purchases | Energy purchases | 22 | | | 43 | | | 106 | | | 134 | |
| Energy purchases from affiliate | Energy purchases from affiliate | 2 | | | 7 | | | 3 | | | 9 | |
| Other operation and maintenance | Other operation and maintenance | 93 | | | 103 | | | 184 | | | 203 | |
| Depreciation | Depreciation | 76 | | | 75 | | | 151 | | | 149 | |
| Taxes, other than income | Taxes, other than income | 12 | | | 12 | | | 24 | | | 24 | |
| Total Operating Expenses | Total Operating Expenses | 273 | | | 330 | | | 615 | | | 690 | |
| | Operating Income | Operating Income | 82 | | | 80 | | | 214 | | | 213 | |
| Operating Income | |
| Operating Income | |
| | Other Income (Expense) - net | Other Income (Expense) - net | — | | | 4 | | | 2 | | | 3 | |
| Other Income (Expense) - net | |
| Other Income (Expense) - net | |
| | Interest Expense | |
| | Interest Expense | |
| | | Interest Expense | Interest Expense | 26 | | | 21 | | | 51 | | | 41 | |
| | Income Before Income Taxes | Income Before Income Taxes | 56 | | | 63 | | | 165 | | | 175 | |
| Income Before Income Taxes | |
| Income Before Income Taxes | |
| | Income Taxes | |
| Income Taxes | |
| Income Taxes | Income Taxes | 11 | | | 9 | | | 34 | | | 28 | |
| | Net Income (a) | Net Income (a) | $ | 45 | | | $ | 54 | | | $ | 131 | | | $ | 147 | |
| Net Income (a) | |
| Net Income (a) | |
(a)Net income equals comprehensive income.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED STATEMENTS OF CASH FLOWS
Louisville Gas and Electric Company
(Unaudited)
(Millions of Dollars)
| | | | Six Months Ended June 30, | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2024 | | 2023 |
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | | | | Cash Flows from Operating Activities | | | |
| Net income | Net income | $ | 131 | | | $ | 147 | |
| Adjustments to reconcile net income to net cash provided by operating activities | Adjustments to reconcile net income to net cash provided by operating activities | | | | Adjustments to reconcile net income to net cash provided by operating activities | | | |
| Depreciation | Depreciation | 151 | | | 149 | |
| Amortization | Amortization | 6 | | | (3) | |
| Defined benefit plans - expense (income) | Defined benefit plans - expense (income) | 1 | | | (1) | |
| Deferred income taxes and investment tax credits | Deferred income taxes and investment tax credits | (5) | | | (9) | |
| Other | (3) | | | 2 | |
| | Change in current assets and current liabilities | |
| Change in current assets and current liabilities | |
| Change in current assets and current liabilities | Change in current assets and current liabilities | | | | | | |
| Accounts receivable | Accounts receivable | 53 | | | 19 | |
| Accounts receivable from affiliates | Accounts receivable from affiliates | 19 | | | 1 | |
| Accounts payable | Accounts payable | (50) | | | 15 | |
| Accounts payable to affiliates | Accounts payable to affiliates | (6) | | | (11) | |
| Unbilled revenues | Unbilled revenues | 42 | | | 8 | |
| Fuel, materials and supplies | Fuel, materials and supplies | 31 | | | 35 | |
| Regulatory assets and liabilities, net | Regulatory assets and liabilities, net | 31 | | | (16) | |
| | Taxes payable | Taxes payable | (16) | | | (7) | |
| Taxes payable | |
| Taxes payable | |
| Accrued interest | Accrued interest | 6 | | | — | |
| Other | Other | (16) | | | 1 | |
| Other operating activities | Other operating activities | | | | Other operating activities | | | |
| Defined benefit plans - funding | Defined benefit plans - funding | — | | | (2) | |
| Expenditures for asset retirement obligations | Expenditures for asset retirement obligations | (6) | | | (8) | |
| | Other assets | |
| Other assets | |
| Other assets | Other assets | (15) | | | (2) | |
| Other liabilities | Other liabilities | 4 | | | (1) | |
| Net cash provided by operating activities | Net cash provided by operating activities | 358 | | | 317 | |
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | | | | Cash Flows from Investing Activities | | | |
| Expenditures for property, plant and equipment | Expenditures for property, plant and equipment | (186) | | | (183) | |
| Net increase in notes receivable with affiliates | Net increase in notes receivable with affiliates | (8) | | | — | |
| | Net cash used in investing activities | Net cash used in investing activities | (194) | | | (183) | |
| Net cash used in investing activities | |
| Net cash used in investing activities | |
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | | | | Cash Flows from Financing Activities | | | |
| Net decrease in notes payable to affiliates | — | | | (324) | |
| | Issuance of long-term debt | |
| Issuance of long-term debt | |
| Issuance of long-term debt | Issuance of long-term debt | 399 | | | — | |
| Retirement of long-term debt | Retirement of long-term debt | (300) | | | — | |
| | Net increase (decrease) in short-term debt | Net increase (decrease) in short-term debt | (158) | | | 325 | |
| | Net increase (decrease) in short-term debt | |
| | Net increase (decrease) in short-term debt | |
| | Payment of common stock dividends to parent | Payment of common stock dividends to parent | (87) | | | (136) | |
| Contributions from parent | 20 | | | 10 | |
| Payment of common stock dividends to parent | |
| Payment of common stock dividends to parent | |
| | Return of capital to parent | |
| Return of capital to parent | |
| Return of capital to parent | Return of capital to parent | (120) | | | — | |
| Other financing activities | Other financing activities | (4) | | | — | |
| Net cash used in financing activities | Net cash used in financing activities | (250) | | | (125) | |
| Net Increase (Decrease) in Cash and Cash Equivalents | (86) | | | 9 | |
| Cash and Cash Equivalents at Beginning of Period | 93 | | | 9 | |
| Cash and Cash Equivalents at End of Period | $ | 7 | | | $ | 18 | |
| Net Decrease in Cash, Cash Equivalents, and Restricted Cash | |
| Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | |
| Cash, Cash Equivalents, and Restricted Cash at End of Period | |
| | Supplemental Disclosure of Cash Flow Information | |
| Supplemental Disclosure of Cash Flow Information | |
| Supplemental Disclosure of Cash Flow Information | Supplemental Disclosure of Cash Flow Information | |
| | Significant non-cash transactions: | Significant non-cash transactions: | |
| Accrued expenditures for property, plant and equipment at June 30, | $ | 39 | | | $ | 33 | |
| | Significant non-cash transactions: | |
| | Significant non-cash transactions: | |
| Accrued expenditures for property, plant and equipment at March 31, | |
| Accrued expenditures for property, plant and equipment at March 31, | |
| Accrued expenditures for property, plant and equipment at March 31, | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED BALANCE SHEETS
Louisville Gas and Electric Company
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Assets | Assets | | | | Assets | | | |
| | Current Assets | Current Assets | | | |
| Current Assets | |
| Current Assets | | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 7 | | | $ | 93 | |
| Accounts receivable (less reserve: 2023, $4; 2022, $4) | | | |
| Accounts receivable (less reserve: 2024, $5; 2023, $6) | | Accounts receivable (less reserve: 2024, $5; 2023, $6) | | | |
| Customer | Customer | 102 | | | 157 | |
| Other | Other | 16 | | | 13 | |
| Unbilled revenues (less reserve: 2023, $0; 2022, $0) | 70 | | | 112 | |
| Unbilled revenues (less reserve: 2024, $0; 2023, $0) | |
| Accounts receivable from affiliates | Accounts receivable from affiliates | 17 | | | 37 | |
| Notes receivable from affiliates | Notes receivable from affiliates | 8 | | | — | |
| Fuel, materials and supplies | Fuel, materials and supplies | 135 | | | 166 | |
| Prepayments | Prepayments | 17 | | | 13 | |
| | Regulatory assets | Regulatory assets | 4 | | | 23 | |
| Regulatory assets | |
| Regulatory assets | |
| Other current assets | Other current assets | 1 | | | 2 | |
| | Total Current Assets | Total Current Assets | 377 | | | 616 | |
| Total Current Assets | |
| Total Current Assets | |
| | Property, Plant and Equipment | |
| Property, Plant and Equipment | |
| Property, Plant and Equipment | Property, Plant and Equipment | | | | | | |
| Regulated utility plant | Regulated utility plant | 7,527 | | | 7,429 | |
| Less: accumulated depreciation - regulated utility plant | Less: accumulated depreciation - regulated utility plant | 1,443 | | | 1,355 | |
| Regulated utility plant, net | Regulated utility plant, net | 6,084 | | | 6,074 | |
| Construction work in progress | Construction work in progress | 294 | | | 268 | |
| Property, Plant and Equipment, net | Property, Plant and Equipment, net | 6,378 | | | 6,342 | |
| | Other Noncurrent Assets | Other Noncurrent Assets | | | |
| Other Noncurrent Assets | |
| Other Noncurrent Assets | | | | |
| Regulatory assets | Regulatory assets | 384 | | | 373 | |
| Goodwill | Goodwill | 389 | | | 389 | |
| Other intangibles | Other intangibles | 21 | | | 24 | |
| Other noncurrent assets | Other noncurrent assets | 70 | | | 66 | |
| Total Other Noncurrent Assets | Total Other Noncurrent Assets | 864 | | | 852 | |
| | Total Assets | Total Assets | $ | 7,619 | | | $ | 7,810 | |
| Total Assets | |
| Total Assets | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED BALANCE SHEETS
Louisville Gas and Electric Company
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Liabilities and Equity | Liabilities and Equity | | | | Liabilities and Equity | | | |
| | Current Liabilities | Current Liabilities | | | |
| Current Liabilities | |
| Current Liabilities | | | | |
| Short-term debt | Short-term debt | $ | 21 | | | $ | 179 | |
| | | Accounts payable | |
| | Accounts payable | |
| | Accounts payable | Accounts payable | 113 | | | 165 | |
| Accounts payable to affiliates | Accounts payable to affiliates | 52 | | | 60 | |
| Customer deposits | Customer deposits | 33 | | | 32 | |
| Taxes | Taxes | 25 | | | 41 | |
| Price risk management liabilities | Price risk management liabilities | 1 | | | 1 | |
| Regulatory liabilities | Regulatory liabilities | 19 | | | 7 | |
| Interest | Interest | 21 | | | 15 | |
| Asset retirement obligations | Asset retirement obligations | 14 | | | 13 | |
| Other current liabilities | Other current liabilities | 36 | | | 46 | |
| Total Current Liabilities | Total Current Liabilities | 335 | | | 559 | |
| | Long-term Debt | Long-term Debt | 2,404 | | | 2,307 | |
| Long-term Debt | |
| Long-term Debt | |
| | Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | | | | | | |
| Deferred income taxes | Deferred income taxes | 774 | | | 771 | |
| Investment tax credits | Investment tax credits | 31 | | | 31 | |
| Price risk management liabilities | Price risk management liabilities | 6 | | | 6 | |
| | Asset retirement obligations | Asset retirement obligations | 64 | | | 73 | |
| Asset retirement obligations | |
| Asset retirement obligations | |
| Regulatory liabilities | Regulatory liabilities | 833 | | | 833 | |
| Other deferred credits and noncurrent liabilities | Other deferred credits and noncurrent liabilities | 61 | | | 64 | |
| Total Deferred Credits and Other Noncurrent Liabilities | Total Deferred Credits and Other Noncurrent Liabilities | 1,769 | | | 1,778 | |
| | Commitments and Contingent Liabilities (Notes 6 and 10) | Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | | | | |
| | Stockholder's Equity | |
| Stockholder's Equity | |
| Stockholder's Equity | Stockholder's Equity | | | | | | |
| Common stock - no par value (a) | Common stock - no par value (a) | 424 | | | 424 | |
| Additional paid-in capital | Additional paid-in capital | 1,987 | | | 2,087 | |
| Earnings reinvested | Earnings reinvested | 700 | | | 655 | |
| Total Equity | Total Equity | 3,111 | | | 3,166 | |
| | Total Liabilities and Equity | Total Liabilities and Equity | $ | 7,619 | | | $ | 7,810 | |
| Total Liabilities and Equity | |
| Total Liabilities and Equity | |
(a)75,000 shares authorized; 21,294 shares issued and outstanding at June 30, 2023March 31, 2024 and December 31, 2022.2023.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
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 | | Common
stock
shares
outstanding
(a) | | Common
stock | | Additional
paid-in
capital | | Earnings
reinvested | | Total |
| March 31, 2023 | 21,294 | | | $ | 424 | | | $ | 1,967 | | | $ | 710 | | | $ | 3,101 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| Net income | Net income | | 45 | | | 45 | |
| Capital contributions from parent | | 20 | | | 20 | |
| | Return of capital to parent | |
| Return of capital to parent | |
| Return of capital to parent | |
| Dividends declared | Dividends declared | | (55) | | | (55) | |
| June 30, 2023 | 21,294 | | | $ | 424 | | | $ | 1,987 | | | $ | 700 | | | $ | 3,111 | |
| March 31, 2024 | |
| | December 31, 2022 | |
| | December 31, 2022 | |
| | | December 31, 2022 | December 31, 2022 | 21,294 | | | $ | 424 | | | $ | 2,087 | | | $ | 655 | | | $ | 3,166 | |
| Net income | Net income | | 131 | | | 131 | |
| Capital contributions from parent | | 20 | | | 20 | |
| | Return of capital to parent | |
| Return of capital to parent | |
| Return of capital to parent | Return of capital to parent | | (120) | | | (120) | |
| Dividends declared | Dividends declared | | (86) | | | (86) | |
| June 30, 2023 | 21,294 | | | $ | 424 | | | $ | 1,987 | | | $ | 700 | | | $ | 3,111 | |
| | March 31, 2022 | 21,294 | | | $ | 424 | | | $ | 1,997 | | | $ | 676 | | | $ | 3,097 | |
| Net income | | 54 | | | 54 | |
| Capital contributions from parent | | 10 | | | 10 | |
| Dividends declared | | (61) | | | (61) | |
| June 30, 2022 | 21,294 | | | $ | 424 | | | $ | 2,007 | | | $ | 669 | | | $ | 3,100 | |
| | December 31, 2021 | 21,294 | | | $ | 424 | | | $ | 1,997 | | | $ | 658 | | | $ | 3,079 | |
| Net income | | 147 | | | 147 | |
| Capital contributions from parent | | 10 | | | 10 | |
| Dividends declared | | (136) | | | (136) | |
| June 30, 2022 | 21,294 | | | $ | 424 | | | $ | 2,007 | | | $ | 669 | | | $ | 3,100 | |
| March 31, 2023 | |
(a)Shares in thousands. All common shares of LG&E stock are owned by LKE.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
| | |
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|
CONDENSED STATEMENTS OF INCOME
Kentucky Utilities Company
(Unaudited)
(Millions of Dollars)
| | | |
| | | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| Operating Revenues | Operating Revenues | | | | | | | |
| Retail and wholesale | Retail and wholesale | $ | 433 | | | $ | 484 | | | $ | 931 | | | $ | 1,007 | |
| Retail and wholesale | |
| Retail and wholesale | |
| Electric revenue from affiliate | Electric revenue from affiliate | 2 | | | 7 | | | 3 | | | 9 | |
| Total Operating Revenues | Total Operating Revenues | 435 | | | 491 | | | 934 | | | 1,016 | |
| | Operating Expenses | |
| Operating Expenses | |
| Operating Expenses | Operating Expenses | | | | | | | | | | | | | | |
| Operation | Operation | | | | | | | | Operation | | | | | | | |
| Fuel | Fuel | 99 | | | 139 | | | 221 | | | 270 | |
| Energy purchases | Energy purchases | 6 | | | 7 | | | 12 | | | 12 | |
| Energy purchases from affiliate | Energy purchases from affiliate | 8 | | | 11 | | | 21 | | | 23 | |
| Other operation and maintenance | Other operation and maintenance | 117 | | | 120 | | | 226 | | | 233 | |
| Depreciation | Depreciation | 98 | | | 98 | | | 196 | | | 193 | |
| Taxes, other than income | Taxes, other than income | 12 | | | 11 | | | 22 | | | 22 | |
| Total Operating Expenses | Total Operating Expenses | 340 | | | 386 | | | 698 | | | 753 | |
| | Operating Income | Operating Income | 95 | | | 105 | | | 236 | | | 263 | |
| Operating Income | |
| Operating Income | |
| | Other Income (Expense) - net | |
| Other Income (Expense) - net | |
| Other Income (Expense) - net | Other Income (Expense) - net | 3 | | | 4 | | | 5 | | | 4 | |
| | Interest Expense | Interest Expense | 33 | | | 28 | | | 66 | | | 55 | |
| Interest Expense | |
| Interest Expense | |
| | Interest Expense with Affiliate | 1 | | | — | | | 1 | | | — | |
| | Income Before Income Taxes | |
| | Income Before Income Taxes | |
| | | Income Before Income Taxes | Income Before Income Taxes | 64 | | | 81 | | | 174 | | | 212 | |
| | Income Taxes | Income Taxes | 13 | | | 15 | | | 35 | | | 39 | |
| Income Taxes | |
| Income Taxes | |
| | Net Income (a) | Net Income (a) | $ | 51 | | | $ | 66 | | | $ | 139 | | | $ | 173 | |
| Net Income (a) | |
| Net Income (a) | |
(a)Net income equals comprehensive income.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED STATEMENTS OF CASH FLOWS
Kentucky Utilities Company
(Unaudited)
(Millions of Dollars)
| | | | Six Months Ended June 30, | | Three Months Ended March 31, |
| | | 2023 | | 2022 | | 2024 | | 2023 |
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | | | | Cash Flows from Operating Activities | | | |
| Net income | Net income | $ | 139 | | | $ | 173 | |
| Adjustments to reconcile net income to net cash provided by operating activities | Adjustments to reconcile net income to net cash provided by operating activities | | | | Adjustments to reconcile net income to net cash provided by operating activities | | | |
| Depreciation | Depreciation | 196 | | | 193 | |
| Amortization | Amortization | 9 | | | 8 | |
| Defined benefit plans - (income) | Defined benefit plans - (income) | (2) | | | (2) | |
| Deferred income taxes and investment tax credits | Deferred income taxes and investment tax credits | (6) | | | (5) | |
| Other | Other | 7 | | | 2 | |
| Change in current assets and current liabilities | Change in current assets and current liabilities | | | | Change in current assets and current liabilities | | | |
| Accounts receivable | Accounts receivable | 24 | | | 1 | |
| | Accounts payable | Accounts payable | (30) | | | 18 | |
| Accounts payable | |
| Accounts payable | |
| Accounts payable to affiliates | Accounts payable to affiliates | (22) | | | (13) | |
| Unbilled revenues | Unbilled revenues | 27 | | | (4) | |
| Fuel, materials and supplies | Fuel, materials and supplies | (25) | | | (5) | |
| Regulatory assets and liabilities, net | Regulatory assets and liabilities, net | 18 | | | (21) | |
| | Taxes payable | |
| Taxes payable | |
| Taxes payable | Taxes payable | (3) | | | 5 | |
| Accrued interest | Accrued interest | 6 | | | — | |
| Other | Other | (7) | | | (4) | |
| Other operating activities | Other operating activities | | | | Other operating activities | | | |
| Defined benefit plans - funding | Defined benefit plans - funding | — | | | (1) | |
| Expenditures for asset retirement obligations | Expenditures for asset retirement obligations | (10) | | | (14) | |
| | Other assets | Other assets | (20) | | | 2 | |
| Other assets | |
| Other assets | |
| Other liabilities | Other liabilities | (3) | | | (1) | |
| Net cash provided by operating activities | Net cash provided by operating activities | 298 | | | 332 | |
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | | | | Cash Flows from Investing Activities | | | |
| Expenditures for property, plant and equipment | Expenditures for property, plant and equipment | (299) | | | (273) | |
| | Net cash used in investing activities | Net cash used in investing activities | (299) | | | (273) | |
| | Net cash used in investing activities | |
| | Net cash used in investing activities | |
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | | | | Cash Flows from Financing Activities | | | |
| Net increase (decrease) in notes payable to affiliates | 8 | | | (294) | |
| Net increase in notes payable to affiliates | |
| Issuance of long-term debt | Issuance of long-term debt | 399 | | | — | |
| Retirement of long-term debt | Retirement of long-term debt | (313) | | | — | |
| Net increase (decrease) in short-term debt | (9) | | | 338 | |
| Net decrease in short-term debt | |
| | Payment of common stock dividends to parent | Payment of common stock dividends to parent | (92) | | | (159) | |
| Contributions from parent | 54 | | | 60 | |
| Payment of common stock dividends to parent | |
| Payment of common stock dividends to parent | |
| | Return of capital to parent | |
| Return of capital to parent | |
| Return of capital to parent | Return of capital to parent | (54) | | | — | |
| Other financing activities | Other financing activities | (4) | | | — | |
| Net cash used in financing activities | Net cash used in financing activities | (11) | | | (55) | |
| Net Increase (Decrease) in Cash and Cash Equivalents | (12) | | | 4 | |
| Cash and Cash Equivalents at Beginning of Period | 21 | | | 13 | |
| Cash and Cash Equivalents at End of Period | $ | 9 | | | $ | 17 | |
| Net Decrease in Cash, Cash Equivalents, and Restricted Cash | |
| Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | |
| Cash, Cash Equivalents, and Restricted Cash at End of Period | |
| | Supplemental Disclosure of Cash Flow Information | |
| Supplemental Disclosure of Cash Flow Information | |
| Supplemental Disclosure of Cash Flow Information | Supplemental Disclosure of Cash Flow Information | |
| | Significant non-cash transactions: | Significant non-cash transactions: | |
| Accrued expenditures for property, plant and equipment at June 30, | $ | 51 | | | $ | 46 | |
| | Significant non-cash transactions: | |
| | Significant non-cash transactions: | |
| Accrued expenditures for property, plant and equipment at March 31, | |
| Accrued expenditures for property, plant and equipment at March 31, | |
| Accrued expenditures for property, plant and equipment at March 31, | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED BALANCE SHEETS
Kentucky Utilities Company
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Assets | Assets | | | | Assets | | | |
| | Current Assets | Current Assets | | | |
| Current Assets | |
| Current Assets | | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 9 | | | $ | 21 | |
| Accounts receivable (less reserve: 2023, $3; 2022, $3) | | | |
| Accounts receivable (less reserve: 2024, $3; 2023, $2) | | Accounts receivable (less reserve: 2024, $3; 2023, $2) | | | |
| Customer | Customer | 133 | | | 158 | |
| Other | Other | 13 | | | 13 | |
| Unbilled revenues (less reserve: 2023, $0; 2022, $0) | 87 | | | 114 | |
| Unbilled revenues (less reserve: 2024, $0; 2023, $0) | |
| | | Fuel, materials and supplies | |
| | Fuel, materials and supplies | |
| | Fuel, materials and supplies | Fuel, materials and supplies | 193 | | | 167 | |
| Prepayments | Prepayments | 16 | | | 14 | |
| | Regulatory assets | Regulatory assets | 10 | | | 32 | |
| Regulatory assets | |
| Regulatory assets | |
| Other current assets | Other current assets | — | | | 1 | |
| | Total Current Assets | Total Current Assets | 461 | | | 520 | |
| Total Current Assets | |
| Total Current Assets | |
| | Property, Plant and Equipment | |
| Property, Plant and Equipment | |
| Property, Plant and Equipment | Property, Plant and Equipment | | | | | | |
| Regulated utility plant | Regulated utility plant | 9,700 | | | 9,515 | |
| Less: accumulated depreciation - regulated utility plant | Less: accumulated depreciation - regulated utility plant | 2,344 | | | 2,201 | |
| Regulated utility plant, net | Regulated utility plant, net | 7,356 | | | 7,314 | |
| Construction work in progress | Construction work in progress | 592 | | | 522 | |
| Property, Plant and Equipment, net | Property, Plant and Equipment, net | 7,948 | | | 7,836 | |
| | Other Noncurrent Assets | Other Noncurrent Assets | | | |
| Other Noncurrent Assets | |
| Other Noncurrent Assets | | | | |
| Regulatory assets | Regulatory assets | 447 | | | 442 | |
| Goodwill | Goodwill | 607 | | | 607 | |
| Other intangibles | Other intangibles | 20 | | | 21 | |
| Other noncurrent assets | Other noncurrent assets | 127 | | | 116 | |
| Total Other Noncurrent Assets | Total Other Noncurrent Assets | 1,201 | | | 1,186 | |
| | Total Assets | Total Assets | $ | 9,610 | | | $ | 9,542 | |
| Total Assets | |
| Total Assets | |
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
CONDENSED BALANCE SHEETS
Kentucky Utilities Company
(Unaudited)
(Millions of Dollars, shares in thousands)
| | | | June 30,
2023 | | December 31,
2022 | | March 31,
2024 | | December 31,
2023 |
| Liabilities and Equity | Liabilities and Equity | | | | Liabilities and Equity | | | |
| | Current Liabilities | Current Liabilities | | | |
| Current Liabilities | |
| Current Liabilities | | | | |
| Short-term debt | Short-term debt | $ | 92 | | | $ | 101 | |
| Long-term debt due within one year | — | | | 13 | |
| | Notes payable to affiliates | |
| Notes payable to affiliates | |
| Notes payable to affiliates | Notes payable to affiliates | 8 | | | — | |
| Accounts payable | Accounts payable | 86 | | | 123 | |
| Accounts payable to affiliates | Accounts payable to affiliates | 75 | | | 101 | |
| Customer deposits | Customer deposits | 34 | | | 33 | |
| Taxes | Taxes | 23 | | | 26 | |
| Regulatory liabilities | Regulatory liabilities | 2 | | | 6 | |
| Interest | Interest | 25 | | | 19 | |
| Asset retirement obligations | Asset retirement obligations | 19 | | | 26 | |
| Other current liabilities | Other current liabilities | 49 | | | 51 | |
| Total Current Liabilities | Total Current Liabilities | 413 | | | 499 | |
| | Long-term Debt | Long-term Debt | 3,003 | | | 2,907 | |
| Long-term Debt | |
| Long-term Debt | |
| | Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | |
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | | | | | | |
| Deferred income taxes | Deferred income taxes | 903 | | | 896 | |
| Investment tax credits | Investment tax credits | 84 | | | 85 | |
| | Asset retirement obligations | |
| Asset retirement obligations | |
| Asset retirement obligations | Asset retirement obligations | 56 | | | 56 | |
| Regulatory liabilities | Regulatory liabilities | 1,032 | | | 1,029 | |
| Other deferred credits and noncurrent liabilities | Other deferred credits and noncurrent liabilities | 34 | | | 32 | |
| Total Deferred Credits and Other Noncurrent Liabilities | Total Deferred Credits and Other Noncurrent Liabilities | 2,109 | | | 2,098 | |
| | Commitments and Contingent Liabilities (Notes 6 and 10) | Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | |
| Commitments and Contingent Liabilities (Notes 6 and 10) | | | | |
| | Stockholder's Equity | |
| Stockholder's Equity | |
| Stockholder's Equity | Stockholder's Equity | | | | | | |
| Common stock - no par value (a) | Common stock - no par value (a) | 308 | | | 308 | |
| Additional paid-in capital | Additional paid-in capital | 3,041 | | | 3,041 | |
| | Earnings reinvested | Earnings reinvested | 736 | | | 689 | |
| Earnings reinvested | |
| Earnings reinvested | |
| Total Equity | Total Equity | 4,085 | | | 4,038 | |
| | Total Liabilities and Equity | Total Liabilities and Equity | $ | 9,610 | | | $ | 9,542 | |
| Total Liabilities and Equity | |
| Total Liabilities and Equity | |
(a)80,000 shares authorized; 37,818 shares issued and outstanding at June 30, 2023March 31, 2024 and December 31, 2022.2023.
The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.
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 |
| March 31, 2023 | 37,818 | | | $ | 308 | | | $ | 2,987 | | | $ | 742 | | | | $ | 4,037 | |
| | |
| | | Common
stock
shares
outstanding
(a) | | Common
stock | | Additional
paid-in
capital | | Earnings
reinvested | | | | Total |
| | December 31, 2023 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| Net income | Net income | | 51 | | | | 51 | |
| Capital contributions from parent | | 54 | | | | 54 | |
| | Return of capital to parent | |
| Dividends declared | Dividends declared | | (57) | | | | (57) | |
| | June 30, 2023 | 37,818 | | | $ | 308 | | | $ | 3,041 | | | $ | 736 | | | | $ | 4,085 | |
| March 31, 2024 | |
| March 31, 2024 | |
| March 31, 2024 | |
| | December 31, 2022 | |
| | December 31, 2022 | |
| | | December 31, 2022 | December 31, 2022 | 37,818 | | | $ | 308 | | | $ | 3,041 | | | $ | 689 | | | | $ | 4,038 | |
| Net income | Net income | | 139 | | | | 139 | |
| Capital contributions from parent | | 54 | | | | 54 | |
| | Return of capital to parent | |
| Return of capital to parent | |
| Return of capital to parent | Return of capital to parent | | (54) | | | | (54) | |
| Dividends declared | Dividends declared | | (92) | | | | (92) | |
| | June 30, 2023 | 37,818 | | | $ | 308 | | | $ | 3,041 | | | $ | 736 | | | | $ | 4,085 | |
| | March 31, 2022 | 37,818 | | | $ | 308 | | | $ | 2,957 | | | $ | 680 | | | | $ | 3,945 | |
| Net income | | 66 | | | | 66 | |
| Capital contributions from parent | | 60 | | | | 60 | |
| Dividends declared | | (69) | | | | (69) | |
| | June 30, 2022 | 37,818 | | | $ | 308 | | | $ | 3,017 | | | $ | 677 | | | | $ | 4,002 | |
| | December 31, 2021 | 37,818 | | | $ | 308 | | | $ | 2,957 | | | $ | 663 | | | | $ | 3,928 | |
| Net income | | 173 | | | | 173 | |
| Capital contributions from parent | | 60 | | | | 60 | |
| Dividends declared | | (159) | | | | (159) | |
| | June 30, 2022 | 37,818 | | | $ | 308 | | | $ | 3,017 | | | $ | 677 | | | | $ | 4,002 | |
| March 31, 2023 | |
| March 31, 2023 | |
| March 31, 2023 | |
(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.
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, 20222023 is derived from that Registrant's 20222023 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 20222023 Form 10-K. The results of operations for the three and six months ended June 30, 2023March 31, 2024 are not necessarily indicative of the results to be expected for the full year ending December 31, 20232024 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.
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). The results of Narragansett Electric are included in the consolidated results of PPL from the date of the Acquisition. Following the closing of the Acquisition,
Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). See Note 8 for additional 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.
Beginning on January 1, 2023, theThe Kentucky Regulated segment consists primarily ofincludes 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. Prior to January 1, 2023, the Kentucky Regulated segment also included the financing activities of LKE. The financing activity of LKE is presented in "Corporate and Other" beginning on January 1, 2023. Prior periods have been adjusted to reflect this change. As a result, PPL’s segments consist of its regulated operations in Kentucky, Pennsylvania and Rhode Island and exclude any incremental financing activities of holding companies, which Management believes is a more meaningful presentation as it provides information on the core regulated operations of PPL.
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, which were acquired on May 25, 2022.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 and the financial results of Safari Energy, prior to its sale on November 1, 2022.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 June 30March 31 are as follows:
| | | | Three Months | | Six Months |
| | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | Three Months |
| | | | | | | | 2024 | | 2023 |
| | Operating Revenues from external customers | |
| Operating Revenues from external customers | |
| Operating Revenues from external customers | Operating Revenues from external customers | | | | | | | | | | | | | | |
| Kentucky Regulated | Kentucky Regulated | $ | 778 | | | $ | 883 | | | $ | 1,738 | | | $ | 1,887 | |
| Pennsylvania Regulated | Pennsylvania Regulated | 667 | | | 676 | | | 1,558 | | | 1,451 | |
| Rhode Island Regulated | Rhode Island Regulated | 377 | | | 128 | | | 942 | | | 128 | |
| Corporate and Other | Corporate and Other | 1 | | | 9 | | | — | | | 12 | |
| Total | Total | $ | 1,823 | | | $ | 1,696 | | | $ | 4,238 | | | $ | 3,478 | |
| | Net Income (Loss) | Net Income (Loss) | | | | | | | |
| Net Income (Loss) | |
| Net Income (Loss) | | | | | | | | |
| | Kentucky Regulated | |
| Kentucky Regulated | |
| Kentucky Regulated | Kentucky Regulated | $ | 91 | | | $ | 112 | | | $ | 257 | | | $ | 301 | |
| Pennsylvania Regulated | Pennsylvania Regulated | 110 | | | 124 | | | 248 | | | 267 | |
| Rhode Island Regulated | Rhode Island Regulated | 10 | | | (29) | | | 64 | | | (29) | |
| Corporate and Other | Corporate and Other | (99) | | | (88) | | | (172) | | | (147) | |
| Total | Total | $ | 112 | | | $ | 119 | | | $ | 397 | | | $ | 392 | |
The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of:
| | June 30,
2023 | | December 31,
2022 |
| March 31,
2024 | | | March 31,
2024 | | December 31,
2023 |
| Assets | Assets | | | | Assets | | | |
| Kentucky Regulated | Kentucky Regulated | $ | 16,794 | | | $ | 16,904 | |
| Pennsylvania Regulated | Pennsylvania Regulated | 13,929 | | | 13,565 | |
| Rhode Island Regulated | Rhode Island Regulated | 6,217 | | | 6,081 | |
| Corporate and Other (a) | Corporate and Other (a) | 1,356 | | | 1,287 | |
| Total | Total | $ | 38,296 | | | $ | 37,837 | |
(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 isoperate as a single operating and reportable segment.
3. Revenue from Contracts with Customers
(All Registrants)
See Note 3 in the Registrants' 20222023 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 June 30.March 31.
| | | 2023 Three Months |
| | PPL | | PPL Electric | | LG&E | | KU |
| | 2024 Three Months | |
| | 2024 Three Months | |
| | 2024 Three Months | |
| PPL | | | PPL | | PPL Electric | | LG&E | | KU |
| Operating Revenues (a) | Operating Revenues (a) | $ | 1,823 | | | $ | 667 | | | $ | 355 | | | $ | 435 | |
| Revenues derived from: | Revenues derived from: | |
| Alternative revenue programs (b) | |
| Alternative revenue programs (b) | |
| Alternative revenue programs (b) | Alternative revenue programs (b) | 5 | | | 6 | | | — | | | (3) | |
| Other (c) | Other (c) | (7) | | | (5) | | | (1) | | | (1) | |
| Revenues from Contracts with Customers | Revenues from Contracts with Customers | $ | 1,821 | | | $ | 668 | | | $ | 354 | | | $ | 431 | |
| | 2022 Three Months |
| PPL | | PPL Electric | | LG&E | | KU |
| 2023 Three Months | |
| 2023 Three Months | |
| 2023 Three Months | |
| PPL | | | PPL | | PPL Electric | | LG&E | | KU |
| Operating Revenues (a) | Operating Revenues (a) | $ | 1,696 | | | $ | 676 | | | $ | 410 | | | $ | 491 | |
| Revenues derived from: | Revenues derived from: | |
| Alternative revenue programs (b) | Alternative revenue programs (b) | (40) | | | (23) | | | 3 | | | 1 | |
| Other (c) | (6) | | | (3) | | | (2) | | | (2) | |
| Revenues from Contracts with Customers | $ | 1,650 | | | $ | 650 | | | $ | 411 | | | $ | 490 | |
| | 2023 Six Months |
| PPL | | PPL Electric | | LG&E | | KU |
| Operating Revenues (a) | $ | 4,238 | | | $ | 1,558 | | | $ | 829 | | | $ | 934 | |
| Revenues derived from: | |
| Alternative revenue programs (b) | |
| Alternative revenue programs (b) | Alternative revenue programs (b) | 42 | | | 7 | | | 1 | | | (3) | |
| Other (c) | Other (c) | (11) | | | (7) | | | (2) | | | (2) | |
| Revenues from Contracts with Customers | Revenues from Contracts with Customers | $ | 4,269 | | | $ | 1,558 | | | $ | 828 | | | $ | 929 | |
| | 2022 Six Months |
| PPL | | PPL Electric | | LG&E | | KU |
| Operating Revenues (a) | $ | 3,478 | | | $ | 1,451 | | | $ | 903 | | | $ | 1,016 | |
| Revenues derived from: | |
| Alternative revenue programs (b) | (67) | | | (59) | | | 9 | | | 4 | |
| Other (c) | (13) | | | (7) | | | (4) | | | (3) | |
| Revenues from Contracts with Customers | $ | 3,398 | | | $ | 1,385 | | | $ | 908 | | | $ | 1,017 | |
(a)PPL includes $377 million and $942$549 million for the three and six months ended June 30, 2023March 31, 2024 and $128$565 million for the three and six months ended June 30, 2022March 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. For PPL Electric, the three and six months ended June 30, 2022, included $30 million and $74 million related to the amortization of the regulatory liability recorded in 2021 for a reduction in the transmission formula rate return on equity that was reflected in rates in 2022.
(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 June 30.March 31.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months |
| Residential | | Commercial | | Industrial | | Other (a) | | Wholesale - municipality | | Wholesale - other (b) | | Transmission | | Revenues from Contracts with Customers |
| | | | | | | | | | | | | | | |
| PPL | | | | | | | | | | | | | | | |
| 2023 | | | | | | | | | | | | | | | |
| PA Regulated | $ | 340 | | | $ | 105 | | | $ | 11 | | | $ | 13 | | | $ | — | | | $ | — | | | $ | 199 | | | $ | 668 | |
| KY Regulated | 298 | | | 237 | | | 160 | | | 66 | | | 4 | | | 9 | | | | | 774 | |
| RI Regulated | 141 | | | 49 | | | 4 | | | 149 | | | — | | | — | | | 36 | | | 379 | |
| Corp and Other | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total PPL | $ | 779 | | | $ | 391 | | | $ | 175 | | | $ | 228 | | | $ | 4 | | | $ | 9 | | | $ | 235 | | | $ | 1,821 | |
| | | | | | | | | | | | | | | |
| 2022 | | | | | | | | | | | | | | | |
| PA Regulated | $ | 329 | | | $ | 117 | | | $ | 30 | | | $ | 14 | | | $ | — | | | $ | — | | | $ | 160 | | | $ | 650 | |
| KY Regulated | 339 | | | 251 | | | 167 | | | 93 | | | 8 | | | 26 | | | — | | | 884 | |
| RI Regulated | 31 | | | 12 | | | 1 | | | 47 | | | — | | | — | | | 16 | | | 107 | |
| Corp and Other | — | | | — | | | — | | | 9 | | | — | | | — | | | — | | | 9 | |
| Total PPL | $ | 699 | | | $ | 380 | | | $ | 198 | | | $ | 163 | | | $ | 8 | | | $ | 26 | | | $ | 176 | | | $ | 1,650 | |
| | | | | | | | | | | | | | | |
| PPL Electric | | | | | | | | | | | | | | | |
| 2023 | $ | 340 | | | $ | 105 | | | $ | 11 | | | $ | 13 | | | $ | — | | | $ | — | | | $ | 199 | | | $ | 668 | |
| 2022 | $ | 329 | | | $ | 117 | | | $ | 30 | | | $ | 14 | | | $ | — | | | $ | — | | | $ | 160 | | | $ | 650 | |
| | | | | | | | | | | | | | | |
| LG&E | | | | | | | | | | | | | | | |
| 2023 | $ | 151 | | | $ | 119 | | | $ | 47 | | | $ | 26 | | | $ | — | | | $ | 11 | | | $ | — | | | $ | 354 | |
| 2022 | $ | 169 | | | $ | 124 | | | $ | 49 | | | $ | 47 | | | $ | — | | | $ | 22 | | | $ | — | | | $ | 411 | |
| | | | | | | | | | | | | | | |
| KU | | | | | | | | | | | | | | | |
| 2023 | $ | 147 | | | $ | 117 | | | $ | 113 | | | $ | 40 | | | $ | 4 | | | $ | 10 | | | $ | — | | | $ | 431 | |
| 2022 | $ | 170 | | | $ | 127 | | | $ | 118 | | | $ | 45 | | | $ | 8 | | | $ | 22 | | | $ | — | | | $ | 490 | |
| | Three Months | | | Three Months |
| Residential | | | Residential | | Commercial | | Industrial | | Other (a) | | Wholesale - municipality | | Wholesale - other (b) | | Transmission | | Revenues from Contracts with Customers |
| | | | Six Months |
| | Residential | | Commercial | | Industrial | | Other (a) | | Wholesale - municipality | | Wholesale - other (b) | | Transmission | | Revenues from Contracts with Customers |
| | PPL | PPL | | | | | | | | | | | | | | | |
| 2023 | |
| | PPL | |
| | PPL | |
| 2024 | |
| 2024 | |
| 2024 | |
| PA Regulated | |
| PA Regulated | |
| PA Regulated | PA Regulated | $ | 968 | | | $ | 253 | | | $ | 34 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 277 | | | $ | 1,558 | |
| KY Regulated | KY Regulated | 741 | | | 511 | | | 324 | | | 126 | | | 11 | | | 20 | | | — | | | 1,733 | |
| RI Regulated | RI Regulated | 370 | | | 150 | | | 13 | | | 364 | | | — | | | — | | | 81 | | | 978 | |
| Corp and Other | Corp and Other | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total PPL | Total PPL | $ | 2,079 | | | $ | 914 | | | $ | 371 | | | $ | 516 | | | $ | 11 | | | $ | 20 | | | $ | 358 | | | $ | 4,269 | |
| | 2022 | |
| 2023 | |
| 2023 | |
| 2023 | |
| PA Regulated | |
| PA Regulated | |
| PA Regulated | PA Regulated | $ | 782 | | | $ | 225 | | | $ | 45 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 307 | | | $ | 1,385 | |
| KY Regulated | KY Regulated | 817 | | | 521 | | | 321 | | | 176 | | | 14 | | | 45 | | | — | | | 1,894 | |
| RI Regulated | RI Regulated | 31 | | | 12 | | | 1 | | | 47 | | | — | | | — | | | 16 | | | 107 | |
| Corp and Other | Corp and Other | — | | | — | | | — | | | 12 | | | — | | | — | | | — | | | 12 | |
| Total PPL | Total PPL | $ | 1,630 | | | $ | 758 | | | $ | 367 | | | $ | 261 | | | $ | 14 | | | $ | 45 | | | $ | 323 | | | $ | 3,398 | |
|
| | Six Months |
| Residential | | Commercial | | Industrial | | Other (a) | | Wholesale - municipality | | Wholesale - other (b) | | Transmission | | Revenues from Contracts with Customers |
| | Three Months | | | Three Months |
| Residential | | | Residential | | Commercial | | Industrial | | Other (a) | | Wholesale - municipality | | Wholesale - other (b) | | Transmission | | Revenues from Contracts with Customers |
| PPL Electric | PPL Electric | |
| 2024 | |
| 2024 | |
| 2024 | |
| 2023 | 2023 | $ | 968 | | | $ | 253 | | | $ | 34 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 277 | | | $ | 1,558 | |
| 2022 | $ | 782 | | | $ | 225 | | | $ | 45 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 307 | | | $ | 1,385 | |
| | LG&E | LG&E | |
| LG&E | |
| LG&E | |
| 2024 | |
| 2024 | |
| 2024 | |
| 2023 | 2023 | $ | 392 | | | $ | 271 | | | $ | 96 | | | $ | 42 | | | $ | — | | | $ | 27 | | | $ | — | | | $ | 828 | |
| 2022 | $ | 415 | | | $ | 270 | | | $ | 94 | | | $ | 86 | | | $ | — | | | $ | 43 | | | $ | — | | | $ | 908 | |
| | KU | KU | |
| KU | |
| KU | |
| 2024 | |
| 2024 | |
| 2024 | |
| 2023 | 2023 | $ | 349 | | | $ | 240 | | | $ | 228 | | | $ | 84 | | | $ | 11 | | | $ | 17 | | | $ | — | | | $ | 929 | |
| 2022 | $ | 402 | | | $ | 251 | | | $ | 227 | | | $ | 89 | | | $ | 14 | | | $ | 34 | | | $ | — | | | $ | 1,017 | |
(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 June 30.March 31.
| | Three Months | | Six Months |
| 2023 | | 2022 | | 2023 | | 2022 |
| PPL | $ | 6 | | | $ | 25 | | | $ | 26 | | | $ | 33 | |
| PPL Electric | 7 | | | — | | | 17 | | | 5 | |
| | | Three Months | |
| | | Three Months | |
| | | Three Months | |
| | | | | 2024 | | | | | | | 2024 | | 2023 |
| PPL (a) | |
| PPL Electric (a) | |
| LG&E | LG&E | — | | | 1 | | | 1 | | | 2 | |
| KU | KU | 1 | | | 1 | | | 1 | | | 2 | |
(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, 2022 | $ | 34 | | | $ | 23 | | | $ | 5 | | | $ | 6 | |
| Contract liabilities at June 30, 2023 | 48 | | | 35 | | | 6 | | | 7 | |
| Revenue recognized during the six months ended June 30, 2023 that was included in the contract liability balance at December 31, 2022 | 18 | | | 7 | | | 5 | | | 6 | |
| | | | | | | |
| Contract liabilities at December 31, 2021 | $ | 42 | | | $ | 25 | | | $ | 6 | | | $ | 6 | |
| Contract liabilities at June 30, 2022 | 33 | | | 16 | | | 6 | | | 5 | |
| Revenue recognized during the six months ended June 30, 2022 that was included in the contract liability balance at December 31, 2021 | 24 | | | 12 | | | 6 | | | 6 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| 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.
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. The If-Converted Method will be applied toIncremental non-participating securities that have a dilutive impact are detailed in the Exchangeable Senior Notes due 2028 issued in February 2023. See Note 7 for additional information.table below.
Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended June 30March 31 used in the EPS calculation are:
| | | |
| | | | Three Months | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| Income (Numerator) | Income (Numerator) | | | | | | | | Income (Numerator) | | | | | | | |
| | Net income attributable to PPL | Net income attributable to PPL | $ | 112 | | | $ | 119 | | | $ | 397 | | | $ | 392 | |
| | Net income attributable to PPL | |
| | Net income attributable to PPL | |
| Less amounts allocated to participating securities | Less amounts allocated to participating securities | — | | | — | | | 1 | | | — | |
| Net income available to PPL common shareowners - Basic and Diluted | Net income available to PPL common shareowners - Basic and Diluted | $ | 112 | | | $ | 119 | | | $ | 396 | | | $ | 392 | |
| | Shares of Common Stock (Denominator) | Shares of Common Stock (Denominator) | | | | | | | |
| Shares of Common Stock (Denominator) | |
| Shares of Common Stock (Denominator) | | | | | | | | |
| Weighted-average shares - Basic EPS | Weighted-average shares - Basic EPS | 737,075 | | | 735,977 | | | 736,953 | | | 735,741 | |
| | Add: Dilutive share-based payment awards | 1,102 | | | 792 | | | 985 | | | 737 | |
| Add: Dilutive share-based payment awards (a) | |
| Add: Dilutive share-based payment awards (a) | |
| Add: Dilutive share-based payment awards (a) | |
| | Weighted-average shares - Diluted EPS | |
| Weighted-average shares - Diluted EPS | |
| Weighted-average shares - Diluted EPS | Weighted-average shares - Diluted EPS | 738,177 | | | 736,769 | | | 737,938 | | | 736,478 | |
| | Basic and Diluted EPS | Basic and Diluted EPS | | | | | | | |
| Basic and Diluted EPS | |
| Basic and Diluted EPS | | | | | | | | |
| | | Net Income available to PPL common shareowners | |
| | Net Income available to PPL common shareowners | |
| | Net Income available to PPL common shareowners | Net Income available to PPL common shareowners | $ | 0.15 | | | $ | 0.16 | | | $ | 0.54 | | | $ | 0.53 | |
|
(a) The Treasury Stock Method was applied to non-participating share-based payment awards.
For the periods ended June 30, PPL issued shares of common stock related to stock-based compensation plans as follows (in thousands):
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | 2023 | | 2022 |
| Stock-based compensation plans | — | | | — | | | — | | | 124 | |
For the periods ended June 30,March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months | | Six Months |
| 2023 | | 2022 | | 2023 | | 2022 |
| Stock-based compensation awards | 258 | | | 66 | | | 396 | | | 110 | |
| | | | | | | | | | | | | | | |
| | | | Three Months |
| | | | | 2024 | | 2023 |
| Stock-based compensation awards | | | | | — | | | 534 | |
5. Income Taxes
Reconciliations of income tax expense (benefit) for the periods ended June 30March 31 are as follows.
| | (PPL) | | | Three Months | | Six Months |
| (PPL) | |
| | 2023 | | 2022 | | 2023 | | 2022 |
| (PPL) | |
| | | Three Months | | | | | Three Months |
| | | | | 2024 | | | | | | | 2024 | | 2023 |
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 30 | | | $ | 32 | | | $ | 107 | | | $ | 104 | |
| Increase (decrease) due to: | Increase (decrease) due to: | | | | | | | | Increase (decrease) due to: | | | | | | | |
| State income taxes, net of federal income tax benefit | State income taxes, net of federal income tax benefit | 11 | | | 27 | | | 33 | | | 48 | |
| | Valuation allowance adjustments | 5 | | | 7 | | | 7 | | | 10 | |
| | Amortization of investment tax credit including deferred taxes on basis adjustment | — | | | (4) | | | (1) | | | (7) | |
| Depreciation and other items not normalized | (2) | | | (5) | | | (7) | | | (8) | |
| | Utility rate-making tax adjustments (a) | |
| | Utility rate-making tax adjustments (a) | |
| | Utility rate-making tax adjustments (a) | |
| Amortization of excess deferred federal and state income taxes | Amortization of excess deferred federal and state income taxes | (8) | | | (22) | | | (20) | | | (40) | |
| | Other | Other | (3) | | | (3) | | | (7) | | | (1) | |
| | Other | |
| | Other | |
| Total increase (decrease) | Total increase (decrease) | 3 | | | — | | | 5 | | | 2 | |
| Total income tax expense (benefit) | Total income tax expense (benefit) | $ | 33 | | | $ | 32 | | | $ | 112 | | | $ | 106 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| (PPL Electric) | | | | | | | |
| Three Months | | Six Months |
| 2023 | | 2022 | | 2023 | | 2022 |
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 31 | | | $ | 35 | | | $ | 70 | | | $ | 76 | |
| Increase (decrease) due to: | | | | | | | |
| State income taxes, net of federal income tax benefit | 11 | | | 13 | | | 24 | | | 28 | |
| | | | | | | |
| Depreciation and other items not normalized | (3) | | | (3) | | | (7) | | | (6) | |
| Amortization of excess deferred federal and state income taxes | (2) | | | (2) | | | (4) | | | (5) | |
| | | | | | | |
| | | | | | | |
| Other | 1 | | | 1 | | | — | | | 1 | |
| Total increase (decrease) | 7 | | | 9 | | | 13 | | | 18 | |
| Total income tax expense (benefit) | $ | 38 | | | $ | 44 | | | $ | 83 | | | $ | 94 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| (LG&E) | | | | | | | |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | 2023 | | 2022 |
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 12 | | | $ | 13 | | | $ | 35 | | | $ | 37 | |
| Increase (decrease) due to: | | | | | | | |
| State income taxes, net of federal income tax benefit | 2 | | | 2 | | | 6 | | | 7 | |
| | | | | | | |
| Amortization of excess deferred federal and state income taxes | (3) | | | (7) | | | (6) | | | (14) | |
| | | | | | | |
| | | | | | | |
| Other | — | | | 1 | | | (1) | | | (2) | |
| Total increase (decrease) | (1) | | | (4) | | | (1) | | | (9) | |
| Total income tax expense (benefit) | $ | 11 | | | $ | 9 | | | $ | 34 | | | $ | 28 | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | (KU) | | | | |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | 2023 | | 2022 |
| (PPL Electric) | |
| (PPL Electric) | |
| (PPL Electric) | | | | | | | | |
| | | Three Months | | | | | Three Months |
| | | | | 2024 | | | | | | | 2024 | | 2023 |
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 13 | | | $ | 17 | | | $ | 36 | | | $ | 45 | |
| Increase (decrease) due to: | Increase (decrease) due to: | | | | | | | | Increase (decrease) due to: | | | | | | | |
| State income taxes, net of federal income tax benefit | State income taxes, net of federal income tax benefit | 3 | | | 3 | | | 7 | | | 8 | |
| | Utility rate-making tax adjustments (a) | |
| Utility rate-making tax adjustments (a) | |
| Utility rate-making tax adjustments (a) | |
| Amortization of excess deferred federal and state income taxes | Amortization of excess deferred federal and state income taxes | (4) | | | (6) | | | (8) | | | (12) | |
| | Other | Other | 1 | | | 1 | | | — | | | (2) | |
| | Other | |
| | Other | |
| Total increase (decrease) | Total increase (decrease) | — | | | (2) | | | (1) | | | (6) | |
| Total income tax expense (benefit) | Total income tax expense (benefit) | $ | 13 | | | $ | 15 | | | $ | 35 | | | $ | 39 | |
(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
Narragansett Electric Acquisition (PPL)
The acquisition of Narragansett Electric on May 25, 2022 was deemed an asset acquisition for federal and state income tax purposes, as a result of PPL and National Grid making a tax election under Internal Revenue Code (IRC) §338(h)(10). Accordingly, the tax bases of substantially all of the assets acquired were increased to fair market value, which equaled net book value, thereby eliminating the related deferred tax assets and liabilities. This election resulted in tax goodwill that will be amortized for tax purposes over 15 years.
Pennsylvania State Tax Reform (PPL and PPL Electric)
On July 8, 2022, the Governor of Pennsylvania signed into law Pennsylvania House Bill 1342 (H.B. 1342). Among other changes to the state tax code, the bill reduces the corporate net income tax rate from 9.99% to 8.99% beginning January 1, 2023, and further reduces the rate annually by half a percentage point until the rate reaches 4.99% in 2031.
Inflation Reduction Act (All Registrants)
On August 16, 2022, the Inflation Reduction Act (IRA) was signed into law. Among other things, the IRA enacted a new 15% corporate "book minimum tax," which is based on adjusted GAAP pre-tax income and is only applicable to corporations whose pre-tax income exceeds a certain threshold. PPL does not expect to be subject to the book minimum tax in 2023. The Registrants will continue to assess the impacts of the IRA on their financial statements and will monitor guidance issued by the U.S. Treasury in the future. In addition, the IRA enacted numerous new tax credits, largely associated with renewable energy.
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 newly issued 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.
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 |
| June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 |
| Current Regulatory Assets: | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Gas supply clause | $ | — | | | $ | 41 | | | $ | — | | | $ | — | | | $ | — | | | $ | 13 | | | $ | — | | | $ | — | |
| Rate adjustment mechanisms | 214 | | | 96 | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| Renewable energy certificates | 13 | | 14 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Derivative instruments | 15 | | 41 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Smart meter rider | 5 | | | 5 | | | 5 | | | 5 | | | — | | | — | | | — | | | — | |
| Universal service rider | 21 | | | 3 | | | 21 | | | 3 | | | — | | | — | | | — | | | — | |
| Fuel adjustment clause | 9 | | | 38 | | | — | | | — | | | 2 | | | 9 | | | 7 | | | 29 | |
| Transmission service charge | 12 | | | — | | | 12 | | | — | | | — | | | — | | | — | | | — | |
| Other | 42 | | | 20 | | | 11 | | | 5 | | | 2 | | | 1 | | | 3 | | | 3 | |
| Total current regulatory assets | $ | 331 | | | $ | 258 | | | $ | 49 | | | $ | 13 | | | $ | 4 | | | $ | 23 | | | $ | 10 | | | $ | 32 | |
| | | | | | | | | | | | | | | |
| Noncurrent Regulatory Assets: | | | | | | | | | | | | | | | |
| Defined benefit plans | $ | 783 | | | $ | 778 | | | $ | 353 | | | $ | 353 | | | $ | 208 | | | $ | 209 | | | $ | 139 | | | $ | 140 | |
| Plant outage costs | 42 | | | 46 | | | — | | | — | | | 11 | | | 12 | | | 31 | | | 34 | |
| Net metering | 89 | | | 61 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Environmental cost recovery | 101 | | | 102 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Taxes recoverable through future rates | 38 | | | 47 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Storm costs | 111 | | | 118 | | | — | | | — | | | 15 | | | 7 | | | 14 | | | 3 | |
| Unamortized loss on debt | 24 | | | 21 | | | 4 | | | 3 | | | 11 | | | 11 | | | 7 | | | 7 | |
| Interest rate swaps | 6 | | | 7 | | | — | | | — | | | 6 | | | 7 | | | — | | | — | |
| Terminated interest rate swaps | 61 | | | 63 | | | — | | | — | | | 36 | | | 37 | | | 25 | | | 26 | |
| Accumulated cost of removal of utility plant | 195 | | | 212 | | | 195 | | | 212 | | | — | | | — | | | — | | | — | |
| AROs | 292 | | | 295 | | | — | | | — | | | 76 | | | 76 | | | 216 | | | 219 | |
| | | | | | | | | | | | | | | |
| Derivatives instruments | 7 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Other | 77 | | | 69 | | | — | | | — | | | 21 | | | 14 | | | 15 | | | 13 | |
| Total noncurrent regulatory assets | $ | 1,826 | | | $ | 1,819 | | | $ | 552 | | | $ | 568 | | | $ | 384 | | | $ | 373 | | | $ | 447 | | | $ | 442 | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| PPL | | PPL Electric | | LG&E | | KU |
| June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 |
| Current Regulatory Liabilities: | | | | | | | | | | | | | | | |
| Generation supply charge | $ | 41 | | | $ | 37 | | | $ | 41 | | | $ | 37 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
| Transmission service charge | — | | | 14 | | | — | | | 7 | | | — | | | — | | | — | | | — | |
| TCJA customer refund | 6 | | | 15 | | | 6 | | | 15 | | | — | | | — | | | — | | | — | |
| Act 129 compliance rider | 15 | | | 14 | | | 15 | | | 14 | | | — | | | — | | | — | | | — | |
| Transmission formula rate | 23 | | | 12 | | | 20 | | | 12 | | | — | | | — | | | — | | | — | |
| Rate adjustment mechanism | 133 | | | 96 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Energy efficiency | 23 | | | 23 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Gas supply clause | 16 | | | — | | | — | | | — | | | 16 | | | — | | | — | | | — | |
| Other | 23 | | | 27 | | | — | | | — | | | 3 | | | 7 | | | 2 | | | 6 | |
| Total current regulatory liabilities | $ | 280 | | | $ | 238 | | | $ | 82 | | | $ | 85 | | | $ | 19 | | | $ | 7 | | | $ | 2 | | | $ | 6 | |
| | | | | | | | | | | | | | | |
| | PPL | | PPL Electric | | LG&E | | KU |
| PPL | | | PPL | | PPL Electric | | LG&E | | KU |
| March 31, 2024 | | | 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 | |
| Generation supply charge | |
| Generation supply charge | |
| Tax Cuts and Jobs Act customer refund | |
| Act 129 compliance rider | |
| Transmission formula rate | |
| Rate adjustment mechanism | |
| Energy efficiency | |
| Gas supply clause | |
| Other | |
| Total current regulatory liabilities | |
| | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 | | June
30, 2023 | | December 31,
2022 |
| Noncurrent Regulatory Liabilities: | Noncurrent Regulatory Liabilities: | | | | | | | | |
| Noncurrent Regulatory Liabilities: | |
| Noncurrent Regulatory Liabilities: | |
| Accumulated cost of removal of utility plant | |
| Accumulated cost of removal of utility plant | |
| Accumulated cost of removal of utility plant | Accumulated cost of removal of utility plant | $ | 978 | | | $ | 950 | | | $ | — | | | $ | — | | | $ | 296 | | | $ | 287 | | | $ | 396 | | | $ | 389 | |
| Power purchase agreement - OVEC | Power purchase agreement - OVEC | 22 | | | 26 | | | — | | | — | | | 15 | | | 18 | | | 7 | | | 8 | |
| Net deferred taxes | Net deferred taxes | 2,054 | | | 2,094 | | | 776 | | | 775 | | | 469 | | | 477 | | | 535 | | | 546 | |
| Defined benefit plans | Defined benefit plans | 225 | | | 187 | | | 59 | | | 45 | | | 21 | | | 21 | | | 57 | | | 56 | |
| Terminated interest rate swaps | Terminated interest rate swaps | 58 | | | 60 | | | — | | | — | | | 29 | | | 30 | | | 29 | | | 30 | |
| Energy efficiency | Energy efficiency | 39 | | | 32 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Other | Other | 45 | | | 63 | | | — | | | — | | | 3 | | | — | | | 8 | | | — | |
| Total noncurrent regulatory liabilities | Total noncurrent regulatory liabilities | $ | 3,421 | | | $ | 3,412 | | | $ | 835 | | | $ | 820 | | | $ | 833 | | | $ | 833 | | | $ | 1,032 | | | $ | 1,029 | |
Regulatory Matters
Rhode Island Activities (PPL)
Rate Case proceedingsProceedings
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 fivesix 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 May 25,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 on track for timely completion,online and fully connected, (iii) an incentive-onlya performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is now 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 has paused the ET programs in Rate Year 5. As of June 30, 2023, the RIPUC had not made any rulings regarding the timing of crediting customers the deferral balance pursuant to the ASA. RIE cannot predict the outcome of this matter.
Advanced Metering Functionality and Grid Modernization(AMF)
In 2021, RIE filed its Updated Advanced Metering Functionality (AMF)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. In 2021, the RIPUC stayed the AMF and GMP proceedings pending further consideration following the issuance of a final Order by the Rhode Island Division of Public Utilities and Carriers onAfter PPL completed the acquisition of RIE. RIE, filed notice of withdrawal of the original Updated AMF Business Case and GMP with the RIPUC, and in November 2022RIE filed a new AMF Business Case with the RIPUC.The new AMF Business Case filing consistsRIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory. The proposal will enable significant customer and grid benefits in line with the state’s climate mandates. In its filing, RIE estimated that the proposed program would cost $188 million on a net present value (NPV) basis and provide benefits of $729 million NPV over the 20-year project life, yielding a benefit-cost ratio of 3.9%. RIE believes AMF is a foundational technology that is a necessary first step to transforming Rhode Island’s electric distribution system.
In its filing, RIE requested a RIPUC decision by June 2023; the RIPUC issued a revised procedural schedule for the AMF Business Case filing that provides for hearings in July 2023.Evidentiary hearings commenced on July 20, 2023 and continued on July 25, 2023 through July 27, 2023. In addition, the RIPUC held a public comment hearing on April 4, 2023, and technical
sessionsOn 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 Februaryrecovery 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 May 10, 2023 and June 13, 2023. Thefor RIPUC also held a separate evidentiary hearing on April 14, 2023, regarding certain Motions for Confidential Treatment by RIE.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 issueissues an order affirming RIE’sRIE'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.
COVID-19Petition for Deferral Filingof Credit Card Fees
On April 30, 2021,January 31, 2024, RIE filed a petition forto request approval to recognize regulatory assets related to COVID-19 impacts (RIPUCthe 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. 5154). In5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its petition,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 soughtintends to file in the RIPUC's authorizationsecond 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 and consideration of future cost recovery for the following COVID-19 costs: (1) the increased cost of customer accounts receivable that RIE will be unable to collect as a result of the COVID-19 pandemic,related bad debt expense and the executive orders and RIPUC orders restricting RIE's collection activities as a result of the pandemic, which will result in increased net charge-offs; (2) lost revenue from unassessed late payment charges; and (3) charges to RIE for other fees that RIE has waived pursuant to the RIPUC's orders in RIPUC Docket No. 5022. RIE is evaluating its request to create a regulatory asset for COVID-19-related bad debt expense to consider the impact, if any, of the proposed arrearage forgiveness sought in RIE’s Petition to Forgive Certain Arrearage Balances for Low-Income and Protected Customerspending in Docket No. 22-08-GE, which5154. RIE filed withis continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the RIPUC to fulfill its obligations under PPL's settlement with the Rhode Island Attorney General.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’sRIE'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’sRIE's Wampanoag and Tiverton take stations. TheIn response to RIPUC held an Open Meeting on September 13, 2022, and issued its Order on November 18, 2022 regarding the Proactive Main Replacement Program and made the following rulings: (1) commencingdirection, RIE filed testimony with the Gas ISR plan to be filed in this calendar yearRIPUC on May 16, 2022 (prospectively), new main constructed to replace leak prone pipe will not be considered used and useful, and therefore not eligible for rate base treatment, until the related old main is abandoned; and (2) approved the proactive main replacement revenue requirement set forth in the FY2023 Gas ISR plan. Also, the RIPUC directed RIE to submit prefiled testimony on the issue ofregarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and to address three issues, specifically: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. RIE filed this testimony with the RIPUC on May 16, 2022, theThe RIPUC has not taken any action to date on this issue. RIE cannot predictissue, including in its recent action on the outcome of this matter.FY 2025 Gas ISR Plan.
FY 2024 Gas ISR Plan
On December 23, 2022, RIE filed its FY 2024 Gas ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget that was filed with the RIPUC on January 27, 2023 includes $187 million of capital investment spend. The supplemental rate schedules were filed on February 3, 2023. RIE and the Rhode Island Division of Public Utilities and Carriers reached an agreement on an approximately $171 million capital investment spending plan, and RIE filed a second supplemental budget on March 13, 2023. The RIPUC held a hearing on the plan on March 14, 2023. At an Open Meeting on March 29, 2023, the RIPUC approved the planRIE'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. The RIPUC continues to considerCertain open issues regarding the appropriate rate recovery treatmentGas 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 projects not covered by anthe FY 2025 Gas ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan process. RIE cannot predict the outcome of this matter.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
On December 23, 2022, RIE filed its FY 2024 Electric ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget filed with the RIPUC on January 27, 2023 includes $176 million of capital investment spend, $14 million of vegetation operations and management (O&M) spend and $3 million of Other O&M spend. The supplemental rate schedules were filed on February 3, 2023. RIE filed second supplemental budget schedules on March 21, 2023, which includes $166 million of capital investment spend, $14 million of vegetation management O&M spend and $1 million of Other O&M spend. The RIPUC held hearings in March 2023, and on March 29, 2023, approved the planRIE'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 March 30, 2023 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 continues to considerheld hearings in March 2024, and on March 26, 2024, approved the appropriate rate recovery treatment of projects not covered by an ISR plan, forincluding the applicable fiscal year,proposed budgetary and additional definitions and procedures that may be implemented relatedreconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR plan process. RIE cannot predictPlan 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 outcome of this matter.RIPUC approved RIE's compliance filing for rates effective April 1, 2024.
Kentucky Activities (PPL, LG&E and KU)
CPCN and SB 4 ApplicationKPSC Investigation Related to Winter Storm Elliott
On December 15, 2022,22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU filed an application withregarding the KPSC forprovision of electric service from December 23, 2022 through December 25, 2022, during a CPCN forperiod of extreme temperatures during Winter Storm Elliott. The investigation is the constructionresult of two 621 MW net summer rating NGCC combustion turbine facilities, one at LG&E's Mill Creek Generating Stationand 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 Jefferson County, KentuckyFebruary 2023 and reports completed by the NERC and the other atFERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's E.W. Brown Generating Station in Mercer County, Kentucky, including on-site natural gasactions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and electric transmission construction associated with those facilities and site compatibility certificates.power system stress. LG&E and KU also applied for a CPCN to construct a 120 MWac solar photovoltaic electric generating facility in Mercer County, Kentucky,believe actions taken during the period under question were necessary and for a CPCN to acquire a 120 MWac solar facility to be built by a third-party solar developer in Marion County, Kentucky. LG&E and KU further applied for a CPCN to construct a 125 MW, 4-hour battery energy storage system facility at KU's E.W. Brown Generating Station and for approval of their proposed 2024-2030 DSM programs. The plan includes adding 14 new, adjusted or expanded energy efficiency programs, which would reduce LG&E's and KU's overall need by approximately 100 MW each. Finally, LG&E and KU requested a declaratory order to confirm that their entry into non-firm energy-only power-purchase agreementsappropriate. Several parties have been granted intervenor status for the output of four solar photovoltaic facilities withproceeding and a combined capacity of 637 MW does not require KPSC approval and that LG&E and KU may recover the costs of the solar PPAs through their fuel adjustment clause mechanisms as previously approved for a prior solar PPA. LG&E and KU plan to accrue AFUDChearing on the constructed NGCC facilities, the solar facility in Mercer County, Kentucky and the battery energy storage system facility and have requested regulatory asset treatment to recover the financing costs of these projects.
The new NGCC facilities would be jointly owned by LG&E (31%) and KU (69%) and the solar units would be jointly owned by LG&E (37%) and KU (63%), the battery storage unit would be owned by LG&E, and the proposed PPA transactions and DSM programs would be entered into or conducted jointly by LG&E and KU, consistent with LG&E and KU's shared dispatch, cost allocation, tariff or other frameworks.
The filing also notes planned retirement datesmatter is scheduled for certain existing coal-fired generation units, including Mill Creek 1 (300 MW) in 2024 and E.W. Brown 3 (412 MW) in 2028, and updates and advances the planned retirement dates for Mill Creek 2 (297 MW) to 2027 and Ghent 2 (486 MW) to 2028. LG&E and KU anticipate the recovery of associated retirement costs, including the remaining net book value, for these coal-fired generating units through the RAR or other rate mechanisms.
The KPSC accepted the CPCN filing as of January 6, 2023. On March 24, 2023, Kentucky Senate Bill 4 (SB 4) went into effect, which requires KPSC approval of fossil fuel-fired electric generating unit retirements in the state. On May 10, 2023, LG&E and KU filed an application with the KPSC seeking approval of the retirement of seven fossil fuel-fired generating units as required by the recently enacted SB 4. On May 16, 2023, the KPSC entered an Order consolidating the SB 4 filing proceeding into the CPCN case. The KPSC has indicated its intention to issue an order on all issues by November 6, 2023. PPL,23, 2024. LG&E and KU cannot predict the outcome of these matters.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.
Kentucky March 2023 Storm
On March 3, 2023, LG&E and KU experienced significant windstorm activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total costs incurred through June 30, 2023 of $75 million ($33 million at
LG&E and $42 million at KU). On March 17, 2023, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the windstorm. On April 5, 2023, the KPSC issued an order approving the request for accounting purposes, noting that approval for recovery would be determined in LG&E’s and KU’s next base rate cases. As of June 30, 2023, LG&E and KU recorded regulatory assets related to the storm of $8 million and $11 million.
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 25,9, 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 has submitted its responses to the information request and is cooperatingcooperated 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. On June 9, 2023, the FERC granted LG&E’s and KU’s motion for an extension of time to process refunds until November 2023. LG&E and KU filed a request for rehearing of the May 18, 2023 order, which was denied by operation of law on July 17, 2023. LG&E and KU filed 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 July 28,December 1, 2023. In the second quarter ofThe FERC issued an order on LG&E and KU's compliance filing on November 16, 2023, and LG&E and KU recorded regulatory liabilitiesfiled a petition for review of $3 millionthis 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 $8 million relatedKU'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 potential refunds resulting fromlift the FERC’sabeyance on April
24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May 18, 2023 order.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 provided primarily through base rates withincreases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be primarily subject to base rate recovery in 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'sGrid 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 are currently on appeal beforehave 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 and six months ended June 30,March 31, 2024 and 2023, PPL Electric purchased $374$419 million and $732$358 million of accounts receivable from alternative suppliers. During the three and six months ended June 30, 2022, PPL Electric purchased $273 million and $622 million of receivables.
(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 29, 2023,26, 2024, the RIPUC approved the SCBP for effect beginning on April 1, 2023,2024, for a one-year period.
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 except for borrowings under PPL Electric's term loan agreement due March 2024 and borrowings under LG&E's and KU's term loan agreements due July 2024, which are reflected in "Long-term debt" at December 31, 2022.Sheets. The following credit facilities were in place at:
| | | | June 30, 2023 | | December 31, 2022 | | March 31, 2024 | | December 31, 2023 |
| | | Expiration
Date | | Capacity | | Borrowed | | Letters of
Credit
and
Commercial
Paper
Issued (d) | | Unused
Capacity | | Borrowed | | Letters of
Credit
and
Commercial
Paper
Issued (d) | | 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 | | | | | | | | | | | | | | PPL | | | |
| PPL Capital Funding (a) | PPL Capital Funding (a) | | | | | | | | | | | | | | PPL Capital Funding (a) | | | |
| Syndicated Credit Facility (b) | Syndicated Credit Facility (b) | Dec. 2027 | | $ | 1,250 | | | $ | — | | | $ | — | | | $ | 1,250 | | | $ | — | | | $ | 561 | |
| | Bilateral Credit Facility | Bilateral Credit Facility | Mar. 2024 | | 100 | | | — | | | — | | | 100 | | | — | | | — | |
| Bilateral Credit Facility (c) | Mar. 2024 | | 100 | | | — | | | 58 | | | 42 | | | — | | | 58 | |
| Bilateral Credit Facility | |
| Bilateral Credit Facility | |
| Bilateral Credit Facility | |
| Total PPL Capital Funding Credit Facilities | Total PPL Capital Funding Credit Facilities | | $ | 1,450 | | | $ | — | | | $ | 58 | | | $ | 1,392 | | | $ | — | | | $ | 619 | |
| | | PPL Electric | PPL Electric | | | | | | | | | | | | | |
| | PPL Electric | |
| | PPL Electric | | | | |
| Syndicated Credit Facility | Syndicated Credit Facility | Dec. 2027 | | $ | 650 | | | $ | — | | | $ | 131 | | | $ | 519 | | | $ | — | | | $ | 146 | |
| Term Loan Credit Facility | Mar. 2024 | | — | | | — | | | — | | | — | | | 250 | | | — | |
| | Total PPL Electric Credit Facilities | |
| Total PPL Electric Credit Facilities | |
| Total PPL Electric Credit Facilities | Total PPL Electric Credit Facilities | | $ | 650 | | | $ | — | | | $ | 131 | | | $ | 519 | | | $ | 250 | | | $ | 146 | |
| | | LG&E | LG&E | | | | | | | | | | | | |
| | LG&E | |
| | LG&E | |
| Syndicated Credit Facility | Syndicated Credit Facility | Dec. 2027 | | $ | 500 | | | $ | — | | | $ | 21 | | | $ | 479 | | | $ | — | | | $ | 180 | |
| Term Loan Credit Facility | Jul. 2024 | | — | | | — | | | — | | | — | | | 300 | | | — | |
| Syndicated Credit Facility | |
| Syndicated Credit Facility | |
| | Total LG&E Credit Facilities | |
| Total LG&E Credit Facilities | |
| Total LG&E Credit Facilities | Total LG&E Credit Facilities | | $ | 500 | | | $ | — | | | $ | 21 | | | $ | 479 | | | $ | 300 | | | $ | 180 | |
| | KU | KU | | | | | | | | | | | | | |
| KU | |
| KU | | | | |
| Syndicated Credit Facility | Syndicated Credit Facility | Dec. 2027 | | $ | 400 | | | $ | — | | | $ | 92 | | | $ | 308 | | | $ | — | | | $ | 101 | |
| Term Loan Credit Facility | Jul. 2024 | | — | | | — | | | — | | | — | | | 300 | | | — | |
| | Total KU Credit Facilities | Total KU Credit Facilities | | | $ | 400 | | | $ | — | | | $ | 92 | | | $ | 308 | | | $ | 300 | | | $ | 101 | |
| Total KU Credit Facilities | |
| Total KU Credit Facilities | |
(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.
(b)IncludesThe PPL Capital Funding $1.25 billion syndicated credit facility includes a $250$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)Includes a $45 million letter of credit on behalf of RIE.
(d)Commercial paper issued reflects the undiscounted face value of the issuance.
(PPL)
In March 2023, RIE was added as an authorized borrower under the PPL Capital Funding syndicated credit facility. At June 30, 2023, RIE’s borrowing limit under the facility was set at $250 million and PPL Capital Funding's borrowing limit was set at $1 billion. At June 30, 2023, neither PPL Capital Funding nor RIE had any borrowings outstanding under the facility.
(PPL and PPL Electric)
In March 2023, PPL Electric repaid its $250 million term loan expiring in March 2024 and terminated the facility.
(PPL and LG&E)
In March 2023, LG&E repaid its $300 million term loan expiring in July 2024 and terminated the facility.
(PPL and KU)
In March 2023, KU repaid its $300 million term loan expiring in July 2024 and terminated the facility.
(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:
| | | | June 30, 2023 | | December 31, 2022 | | 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) |
| Weighted -
Average
Interest Rate | | | Weighted -
Average
Interest Rate | | Capacity | | Commercial
Paper
Issuances (c) | | Unused
Capacity | | Weighted -
Average
Interest Rate | | Commercial
Paper
Issuances (c) |
| PPL Capital Funding (a) (b) | PPL Capital Funding (a) (b) | | | $ | 1,350 | | | $ | — | | | $ | 1,350 | | | 4.84% | | $ | 561 | |
| RIE (b) | RIE (b) | | 400 | | | — | | | 400 | | | — | |
PPL Electric | PPL Electric | 5.31% | | 650 | | | 130 | | | 520 | | | 4.74% | | 145 | |
| LG&E | LG&E | 5.30% | | 500 | | | 21 | | | 479 | | | 4.94% | | 180 | |
| KU | KU | 5.34% | | 400 | | | 92 | | | 308 | | | 4.90% | | 101 | |
| Total | Total | | | $ | 3,300 | | | $ | 243 | | | $ | 3,057 | | | | | $ | 987 | |
(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 and under which they are both borrowers.at PPL Capital Funding. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. The PPL Capital Funding syndicated credit facility includes a borrowing sublimit for RIE, which is currently set at $250 million with the remaining $1 billion allocated to PPL Capital Funding. The sublimits of each borrower may be decreased or increased at the borrowers’ option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.25 billion.
(c)Commercial paper issued reflects the undiscounted face value of the issuance.
(PPL)
In June 2023, RIE established a commercial paper program with a capacity of $400 million. This program is supported by PPL Capital Funding's syndicated credit facility, under which RIE is a co-borrower.
(PPL Electric, LG&E, and KU)
See Note 11 for discussion of intercompany borrowings.
Long-term Debt
(PPL)
In February 2023, PPL Capital FundingMarch 2024, RIE issued $1.0 billion$500 million of 2.875% Exchangeable5.35% Senior Notes due 2028 (the Notes). PPL Capital Funding2034. RIE received proceeds of $980$496 million, net of discounts and underwriting fees, which werewill be used to repay short-term debt and for other general corporate purposes. The Notes are senior unsecured notes, fully guaranteed by PPL. The Notes are scheduled to mature on March 15, 2028, unless earlier exchanged, redeemed or repurchased.
The Notes are exchangeable at an initial exchange rate of 29.3432 shares of PPL's common stock per $1,000 principal amount (equivalent to an initial exchange price of approximately $34.08 per share of common stock). The initial exchange rate is subject to adjustment, as provided in the indenture for anti-dilutive events and fundamental change and redemption provisions. Upon exchange of the Notes, PPL Capital Funding will redeem the aggregate principal amount of the Notes in cash. PPL Capital Funding will pay cash, deliver shares of common stock or a combination of cash and shares of common stock, at PPL Capital Funding's election, in respect of the remainder, if any, of its exchange obligation in excess of the aggregate principal amount of the Notes being exchanged. Prior to December 15, 2027, the Notes will be exchangeable at the option of the noteholders only upon the satisfaction of specified conditions and during certain periods described in the indenture pursuant to which the Notes were issued. On or after December 15, 2027 until the maturity date, the Notes will be exchangeable at the option of the noteholders at any time regardless of these conditions or periods.
PPL Capital Funding may redeem all or any portion of the Notes, at its option, on or after March 20, 2026, if the last reported sale price of the common stock has been at least 130% of the exchange price then in effect for at least 20 trading days (whether or not consecutive), during any 30 consecutive trading day period, at a redemption price equal to 100% of the principal amount of the Notes to be redeemed, plus any accrued and unpaid interest. No sinking fund is provided for the Notes.
Subject to certain conditions, holders of the Notes will have the right to require PPL Capital Funding to repurchase all or a portion of their Notes upon the occurrence of a fundamental change, as defined in the indenture pursuant to which the Notes were issued at a repurchase price of 100% of their principal amount plus any accrued and unpaid interest. In connection with certain corporate events or if PPL Capital Funding calls any Notes for redemption, PPL Capital Funding will, under certain circumstances, increase the exchange rate for noteholders who elect to exchange their Notes in connection with any such corporate event or exchange their Notes called for redemption.
(PPL and PPL Electric)
In March 2023,January 2024, PPL Electric issued $600$650 million of 5.00%4.85% First Mortgage Bonds due 2033 and $750 million of 5.25% First Mortgage Bonds due 2053.2034. PPL Electric received proceeds of $1.32 billion,$644 million, net of discounts and underwriting fees, which werewill be used to repay short-term debt including PPL Electric's $250 million term loan, and for other general corporate purposes.
In March 2023, PPL Electric redeemed all of the outstanding $650 million aggregate principal amount of its First Mortgage Bonds, Floating Rate Series due 2024.
In March 2023, PPL Electric redeemed all of the outstanding $250 million aggregate principal amount of its First Mortgage Bonds, Floating Rate Series due 2023.
(PPL and LG&E)
In March 2023, LG&E issued $400 million of 5.45% First Mortgage Bonds due 2033. LG&E received proceeds of $396 million, net of discounts and underwriting fees, which were used to repay LG&E's $300 million term loan and for other general corporate purposes.
(PPL and KU)
In March 2023, KU issued $400 million of 5.45% First Mortgage Bonds due 2033. KU received proceeds of $396 million, net of discounts and underwriting fees, which were used to repay KU's $300 million term loan and for general corporate purposes.
(PPL)
Equity Securities
In June 2023, RIE redeemed all 49,089 shares of its outstanding preferred stock at a redemption price equal to the par value of $50 per share, plus a premium of $5 per share, plus a prorated dividend of $0.1875 per share. The total payment was $3 million.
Dividends
In May 2023,February 2024, PPL declared a quarterly cash dividend on its common stock, payable July 3, 2023,April 1, 2024, of 24.025.75 cents per share (equivalent to 96.0 cents$1.03 per annum).
8. Acquisitions, DevelopmentDevelopments and Divestitures
Acquisitions (PPL)
Acquisitions
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 hasentities 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 is subjectcertain aspects have been extended to extension as necessary to complete the successful transition.third quarter of 2024. TSA costs of $63$48 million and $120$58 million were incurred during the three and six months ended June 30,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 20222023 Form 10-K for a complete listing of those commitments. PPL incurred the following expenses related to some of the remaining commitments for the three and six months ended June 30, 2023: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 $70$81 million and $124$54 million for the three and six months ended June 30,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 $2$1 million and $4$2 million for the three and six months ended June 30,March 31, 2024 and 2023.
Purchase Price AllocationDevelopments (PPL, LG&E and KU)
The operations of Narragansett Electric are subject to the accounting for certain types of regulation as prescribed by GAAP. The carrying value of Narragansett Electric’s assets and liabilities subject to rate-setting and cost recovery provisions provide revenues derived from costs, including a return on investment of net assets and liabilities included in rate base. Therefore, the fair values of these assets and liabilities equal their carrying values. Accordingly, neither the assets acquired nor liabilities assumed reflect any adjustments related to these amounts.Mill Creek Unit 5 Construction
DuringIn December 2022, LG&E and KU filed a Certificate of Public Convenience and Necessity (CPCN) with the three months ended June 30,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 allocationKPSC 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 purchase pricefacility is anticipated to the assets acquired and liabilities assumed recorded in PPL's Consolidated Balance Sheet was adjusted, resulting in a net decrease to goodwill of $1 million. The one-year measurement period and the allocation of the purchase price were completed during the quarter ended June 30, 2023. Total goodwill resulting from the acquisition as of June 30, 2023 was $1,585 million. PPL has elected to not reflect the effects of purchase accounting in the separate financial statements of RIE or PPL's Rhode Island Regulated segment. Accordingly, the Rhode Island Regulated segment includes $725 million of acquired legacy goodwill. The remaining excess purchase price of $860 million is included in PPL's Corporate and Other category for segment reporting purposes.begin mid-2027.
See Note 97 in the PPL's 20222023 Form 10-K for additional information regardingon the purchase price allocation of Narragansett Electric.CPCN filing.
Divestitures
Sale of Safari Holdings
On September 29, 2022, PPL signed a definitive agreement to sell all of Safari Holdings membership interests to Aspen Power Services, LLC (Aspen Power). On November 1, 2022, PPL completed the sale of Safari Holdings (the Transaction).
The accounting for the closing of the Transaction was substantially completed in the fourth quarter of 2022. Final closing adjustments were completed in the first quarter of 2023, resulting in an increase to the loss on sale of $6 million ($4 million net of tax), which was recorded in "Other operation and maintenance" on the Statements of Income for the six months ended June 30, 2023.
In connection with the closing of the Transaction, PPL provided certain guarantees and other assurances. See Note 10 for additional information.
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 June 30:March 31:
| | Pension Benefits |
| | | | | Pension Benefits | |
| | | | | Pension Benefits | |
| | | | | Pension Benefits | |
| | | Three Months | | Six Months | | | | Three Months |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
| PPL | PPL | | | | | | | |
| Service cost | |
| Service cost | |
| Service cost | Service cost | $ | 8 | | | $ | 13 | | | $ | 17 | | | $ | 25 | |
| Interest cost | Interest cost | 48 | | | 30 | | | 94 | | | 62 | |
| Expected return on plan assets | Expected return on plan assets | (77) | | | (63) | | | (155) | | | (127) | |
| Amortization of: | Amortization of: | |
| Prior service cost | Prior service cost | 1 | | | 2 | | | 3 | | | 4 | |
| Prior service cost | |
| Prior service cost | |
| Actuarial loss | Actuarial loss | 1 | | | 17 | | | 1 | | | 29 | |
| Net periodic defined benefit costs (credits) before settlements | (19) | | | (1) | | | (40) | | | (7) | |
| Settlements (a) | — | | | 12 | | | — | | | 12 | |
| | | Net periodic defined benefit costs (credits) | Net periodic defined benefit costs (credits) | $ | (19) | | | $ | 11 | | | $ | (40) | | | $ | 5 | |
| | Net periodic defined benefit costs (credits) | |
| | Net periodic defined benefit costs (credits) | |
(a)Due to the amount of lump sum payment distributions from the LKE qualified pension plan, settlement charges were incurred during the three and six months ended, June 30, 2022. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized over 15 years.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Other Postretirement Benefits |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | 2023 | | 2022 |
| PPL | | | | | | | |
| Service cost | $ | 1 | | | $ | 2 | | | $ | 3 | | | $ | 3 | |
| Interest cost | 8 | | | 4 | | | 15 | | | 8 | |
| Expected return on plan assets | (7) | | | (6) | | | (15) | | | (12) | |
| Amortization of: | | | | | | | |
| Prior service cost | 1 | | | 1 | | | 1 | | | 1 | |
| Actuarial loss | (2) | | | (2) | | | (3) | | | (2) | |
| Net periodic defined benefit costs (credits) | $ | 1 | | | $ | (1) | | | $ | 1 | | | $ | (2) | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | 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
Long-term Contracts for Renewable Energy (PPL)
In July 2022, Rhode Island passed an amendment to the Affordable Clean Energy Security Act (ACES) that required RIE to issue a request for proposals (RFP) for at least 600 MW but no greater than 1,000 MW of newly developed offshore wind capacity no later than October 15, 2022. The RFP was issued on October 14, 2022, following a public comment period, and subsequently revised on November 7, 2022. On March 17, 2023, RIE announced that it will evaluate a joint proposal from Orsted and Eversource to develop 884 MW of offshore wind, which was the sole response to RIE’s RFP. On July 18, 2023, RIE announced it would not be proceeding with conditional selection of the bid because it did not meet the terms of the ACES statute. RIE intends to file supporting documentation with the RIPUC in approximately 60 days.
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.
Talen Litigation
Background (PPL)
In September 2013, one of PPL's former subsidiaries, PPL Montana entered into an agreement to sell its hydroelectric generating facilities. In June 2014, PPL and PPL Energy Supply, the parent company of PPL Montana, entered into various definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and ultimately combine it with Riverstone's competitive power generation businesses to form a stand-alone company named Talen Energy. In November 2014, after executing the spinoff agreements but prior to the closing of the spinoff transaction, PPL Montana closed the sale of its hydroelectric generating facilities. Subsequently, on June 1, 2015, the spinoff of PPL Energy Supply was completed. Following the spinoff transaction, PPL had no continuing ownership interest in or control of PPL Energy Supply. In connection with the spinoff transaction, PPL Montana became Talen Montana, LLC (Talen Montana), a subsidiary of Talen Energy and Talen Energy Marketing, LLC also became a subsidiary of Talen Energy. Talen Energy has owned and operated both Talen Montana and Talen Energy Marketing, LLC since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. Riverstone subsequently acquired the remaining interests in Talen Energy in a take private transaction in December 2016.
In October 2018, Talen Montana Retirement Plan and Talen Energy Marketing, LLC filed a putative class action complaint on behalf of current and contingent creditors of Talen Montana (the Montana Action) who allegedly suffered harm or allegedly will suffer reasonably foreseeable harm as a result of, among other things, the November 2014 allegedly fraudulent transfer of proceeds from the sale of then-PPL Montana's hydroelectric generating facilities.
In November 2018, PPL, certain PPL affiliates, and certain current and former officers and directors (PPL plaintiffs) filed a complaint in the Court of Chancery of the State of Delaware seeking various forms of relief against Riverstone, Talen Energy and certain of their affiliates (the Delaware Action), in response to the Montana Action and as part of the defense strategy.
Talen Energy Supply, LLC et al. andTalen Montana LLC v. PPL Corp., PPL Capital Funding, Inc., PPL Electric Utilities Corp., and PPL Energy Funding (PPL and PPL Electric)
On May 9, 2022, Talen Energy Supply, LLC and 71 affiliates, including Talen Montana, LLC, filed petitions for protection under Chapter 11 of the Bankruptcy Code in the U.S. Bankruptcy Court for the Southern District of Texas (Texas Bankruptcy Court).
On May 10, 2022, Talen Montana, LLC, as debtor-in-possession, filed a complaint initiating an adversary proceeding (Adversary Proceeding) in the Texas Bankruptcy Court against PPL Corporation, PPL Capital Funding, Inc., PPL Electric Utilities Corporation, and PPL Energy Funding Corporation. Similar to the litigation in Montana, the Adversary Proceeding seeks the recovery of an allegedly fraudulent transfer relating to PPL Montana’s November 2014 sale of hydroelectric assets to Northwestern and subsequent distribution of certain proceeds of that sale of approximately $900 million, reiterating claims that the parties had already been litigating in Montana and Delaware.
Both the Montana Action and the Delaware Action have now been transferred to and consolidated in the Texas Bankruptcy Court. PPL has filed its Answer and asserted a Counterclaim against the Talen and Riverstone entities, similar to the claims previously asserted in the Delaware Action, and has filed a motion for partial summary judgment that was heard on October 31, 2022. Mediation occurred on February 22, 2023 before Judge David R. Jones of the Texas Bankruptcy Court. The parties did not settle the case, and mediation was discontinued. On June 14, 2023, the Texas Bankruptcy Court entered an Order denying the defendants’ motion for partial summary judgment. The defendants anticipate trial will occur in the first quarter of 2024.Riverstone has filed a motion for summary judgement, which is set to be heard on August 15, 2023.
PPL believes that the 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent at all relevant times. Additionally, the agreements entered into in connection with the spinoff, which PPL and affiliates of Talen Energy and Riverstone negotiated and executed prior to the 2014 distribution, directly address the treatment of the proceeds from the sale of PPL Montana's hydroelectric generating facilities; in those agreements, Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds.
PPL believes that it has meritorious defenses to the claims made in the Adversary Proceeding and intends to vigorously defend against this action. At this time, PPL cannot predict the outcome of the Adversary Proceeding or estimate the range of possible losses, if any, that PPL might incur as a result of the claims, although they could be material.
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 itsemployees of National Grid employeesUSA 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, pursuant to Rhode Island General Laws Section 39-4-13.RIE. If the Division finds sufficient grounds, the Division may proceed to a formal hearing regarding the matters under investigation pursuant to Rhode Island General Laws Sections 39-4-14 and 39-4-15.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 RIPUC Docket No. 22-05-EE.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 Docket No. 22-05-EEdisallow 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
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 RIPUC Docket No. 22-05-EEthis 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). In March 2023,On April 25, 2024, the EPA released a proposedpre-publication version of a final rule that would modifymodifying the 2020 ELG revisions. The proposed rule would increaseincreases the stringency of previous control technology and zero discharge requirements, reviserevises certain exemptions for generating units planned for retirement, and requirerequires case-by-case limitations for legacy wastewaters based on the best professional judgment of the state regulators. Compliance with the Reconsideration Rule is required during the pendency of the rulemaking process. The proposedfinal 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. LG&E and KU are currently implementing responsive compliance strategies and schedules. Certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. 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. The EPA is conducting ongoing rulemaking actions regarding various other amendments to the rule including potentially making the rule applicable to certain inactive impoundments and landfills not currently subject to the rule. Certain ongoing legal challenges to various provisions of the CCR Rule have been held in abeyance pending review by the EPA pursuant to the President's executive order. 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
taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. On May 18, 2023,April 25, 2024, the EPA publishedreleased a proposedpre-publication version of a final rule establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities.facilities (legacy impoundments). The EPA proposes to establishrule 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 proposed rule if finalized, would requirealso 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 within three months of the proposed rule’s effective date.impoundments. Additionally, the proposed 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 existingapplicable regulations.
In January 2017, Kentucky issued a new state rule relating to CCR management, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. As a result of a subsequent legal challenge, in January 2018, the Franklin County,
Kentucky Circuit Court issued an opinion invalidating certain procedural elements of the rule. LG&E and KU presently operate their facilities under continuing permits authorized under the former program and do not currently anticipate material impacts as a result of the judicial ruling. Associated costs are expected to be subject to rate recovery.
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 including the Columbia Gas Plant site and the Brodhead site.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 June 30, 2023March 31, 2024 and December 31, 2022,2023, PPL Electric had a recorded liability of $11$8 million, representing its best estimate of the probable loss incurred to remediate the sites identified above.these sites.
(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 June 30, 2023March 31, 2024 and December 31, 2022,2023, PPL had a recorded liability of $100$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
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 June 30, 2023.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 June 30, 2023 | | Expiration
Date | |
| Exposure at March 31, 2024 | |
| Exposure at March 31, 2024 | |
| Exposure at March 31, 2024 | |
| PPL | |
| PPL | |
| PPL | PPL | | | | | |
| Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business | Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business | £ | 50 | | (a) | | 2028 | |
| Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business | |
| Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business | |
| PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings | PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings | $ | 137 | | (b) | | 2028 | |
| PPL guarantee of Safari payment obligations under certain PPAs related to the sale of Safari Holdings | 55 | | (c) | | |
| PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings | |
| PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings | |
| Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings | |
| Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings | |
| Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings | 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 | | (d) | | 2028 | |
| LG&E and KU | LG&E and KU | | | | |
| LG&E and KU | |
| LG&E and KU | |
| LG&E and KU obligation of shortfall related to OVEC | LG&E and KU obligation of shortfall related to OVEC | | (e) | | | |
| LG&E and KU obligation of shortfall related to OVEC | |
| LG&E and KU obligation of shortfall related to OVEC | |
(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)PPL guaranteed the payment obligations of Safari under certain PPAs executed by Safari. Aspen Power is expected to replace these guarantees and retain liability for any payments made by PPL or claims against PPL under any guarantee that is not replaced.
(d)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 and PPAs that will be replaced by Aspen Power.financings.
(e)(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 $89$86 million at June 30, 2023,March 31, 2024, consisting of LG&E's share of $62$60 million and KU's share of $27$26 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 1413 in PPL's, LG&E's and KU's 20222023 Form 10-K for additional information on the OVEC power purchase contract.
The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is generally remote.
PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225$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 June 30,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 | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | 2023 | | 2022 | | | | | | 2024 | | 2023 |
PPL Electric from PPL Services | PPL Electric from PPL Services | $ | 55 | | | $ | 60 | | | $ | 114 | | | $ | 121 | |
| LG&E from LKS | LG&E from LKS | 28 | | | 41 | | | 60 | | | 80 | |
| LG&E from PPL Services | LG&E from PPL Services | 12 | | | — | | | 20 | | | — | |
| KU from LKS | KU from LKS | 34 | | | 42 | | | 75 | | | 86 | |
| KU from PPL Services | KU from PPL Services | 13 | | | — | | | 23 | | | — | |
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.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 $500$800 million revolving line of credit with a PPL Electric subsidiary. At June 30, 2023 and DecemberMarch 31, 2022,2024, 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 June 30, 2023,March 31, 2024, LG&E's money pool unused capacity was $729$722 million. At June 30,March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE were not significant. At December 31, 2022,LKE. These balances would be reflected in "Notes payable to affiliates" on the LG&E had no borrowings outstanding from KU and/or LKE.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 June 30, 2023,March 31, 2024, KU's money pool unused capacity was $550$568 million. At June 30, 2023,March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $837 million. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. At December 31, 2022,2023, KU had no borrowings outstanding from LG&E and/or LKE.
VEBA Funds Receivable (PPL Electric)
In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active
bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. There was no intercompany receivable balance associated with these funds as of June 30, 2023, which would be reflected in "Accounts receivable from affiliates" on the PPL Electric Balance Sheets. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022.
12. Other Income (Expense) - net
(PPL)
The details of "Other Income (Expense) - net" for the periods ended June 30,March 31, were:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months | | Six Months | | | | |
| 2023 | | 2022 | | 2023 | | 2022 | | | | | | | | |
| | | | | | | | | | | | | | | |
| Defined benefit plans - non-service credits (Note 9) | $ | (1) | | | $ | 9 | | | $ | 16 | | | $ | 20 | | | | | | | | | |
| Interest income (expense) | 8 | | | (1) | | | 17 | | | (2) | | | | | | | | | |
| AFUDC - equity component | 8 | | | 6 | | | 14 | | | 10 | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Charitable contributions | — | | | (1) | | | (2) | | | (2) | | | | | | | | | |
| Miscellaneous (a) | (10) | | | 13 | | | (10) | | | — | | | | | | | | | |
| Other Income (Expense) - net | $ | 5 | | | $ | 26 | | | $ | 35 | | | $ | 26 | | | | | | | | | |
(a)Includes legal expenses incurred and insurance reimbursements received related to litigation with a former affiliate, Talen Montana. See Note 10 for additional information. | | | | | | | | | | | | | | | | | | | | | | | |
| | | | 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 June 30,March 31, were:
| | | | Three Months | | Six Months | |
| | 2023 | | 2022 | | 2023 | | 2022 | |
| | | | | | 2024 | |
| | | | | 2024 | |
| | | | | 2024 | |
| | Defined benefit plans - non-service credits (Note 9) | Defined benefit plans - non-service credits (Note 9) | $ | 5 | | | $ | 4 | | | $ | 10 | | | $ | 8 | | |
| Interest income (expense) | 1 | | | — | | | 5 | | | 1 | | |
| | Defined benefit plans - non-service credits (Note 9) | |
| | Defined benefit plans - non-service credits (Note 9) | |
| Interest income | |
| Interest income | |
| Interest income | |
| AFUDC - equity component | |
| AFUDC - equity component | |
| AFUDC - equity component | AFUDC - equity component | 4 | | | 4 | | | 8 | | | 8 | | |
| | Charitable contributions | Charitable contributions | — | | | — | | | (2) | | | (2) | | |
| Miscellaneous | (1) | | | (1) | | | — | | | (2) | | |
| | Charitable contributions | |
| | Charitable contributions | |
| | Other Income (Expense) - net | Other Income (Expense) - net | $ | 9 | | | $ | 7 | | | $ | 21 | | | $ | 13 | | |
| | Other Income (Expense) - net | |
| | Other Income (Expense) - net | |
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 20222023 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:
| | June 30, 2023 | | December 31, 2022 |
| March 31, 2024 | | | March 31, 2024 | | December 31, 2023 |
| | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 |
| PPL | PPL | | | | | | | | | | | | | | | | PPL | | | |
| Assets | Assets | | | | | | | | | | | | | | | | Assets | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 326 | | | $ | 326 | | | $ | — | | | $ | — | | | $ | 356 | | | $ | 356 | | | $ | — | | | $ | — | |
| Restricted cash and cash equivalents (a) | Restricted cash and cash equivalents (a) | 1 | | | 1 | | | — | | | — | | | 1 | | | 1 | | | — | | | — | |
| Total Cash, Cash Equivalents and Restricted Cash (b) | Total Cash, Cash Equivalents and Restricted Cash (b) | 327 | | | 327 | | | — | | | — | | | 357 | | | 357 | | | — | | | — | |
| Special use funds (a): | Special use funds (a): | | | | | | | | | | | | | | | |
| Money market fund | Money market fund | 1 | | | 1 | | | — | | | — | | | 1 | | | 1 | | | — | | | — | |
| Money market fund | |
| Money market fund | |
| Commingled debt fund measured at NAV (c) | Commingled debt fund measured at NAV (c) | 11 | | | — | | | — | | | — | | | 13 | | | — | | | — | | | — | |
| Commingled equity fund measured at NAV (c) | Commingled equity fund measured at NAV (c) | 10 | | | — | | | — | | | — | | | 11 | | | — | | | — | | | — | |
| Total special use funds | Total special use funds | 22 | | | 1 | | | — | | | — | | | 25 | | | 1 | | | — | | | — | |
| Price risk management assets (d): | Price risk management assets (d): | | | | | | | | | | | | | | | |
| Gas contracts | Gas contracts | 1 | | | — | | | 1 | | | — | | | 25 | | | — | | | 25 | | | — | |
| Gas contracts | |
| Gas contracts | |
| Total assets | Total assets | $ | 350 | | | $ | 328 | | | $ | 1 | | | $ | — | | | $ | 407 | | | $ | 358 | | | $ | 25 | | | $ | — | |
| | Liabilities | |
| Liabilities | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | |
| Price risk management liabilities (d): | Price risk management liabilities (d): | | | | | | | | | | | | | | | | Price risk management liabilities (d): | | | |
| Interest rate swaps | Interest rate swaps | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | |
| Gas contracts | Gas contracts | (23) | | | — | | | (23) | | | — | | | 66 | | | — | | | 10 | | | 56 | |
| Total price risk management liabilities | Total price risk management liabilities | $ | (16) | | | $ | — | | | $ | (16) | | | $ | — | | | $ | 73 | | | $ | — | | | $ | 17 | | | $ | 56 | |
| | PPL Electric | PPL Electric | | | | | | | | | | | | | | | |
| PPL Electric | |
| PPL Electric | | | | |
| Assets | Assets | | | | | | | | | | | | | | | | Assets | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 26 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 25 | | | $ | 25 | | | $ | — | | | $ | — | |
| | Total assets | Total assets | $ | 26 | | | $ | 26 | | | $ | — | | | $ | — | | | $ | 25 | | | $ | 25 | | | $ | — | | | $ | — | |
| Total assets | |
| Total assets | |
| | LG&E | LG&E | | | | | | | | | | | | |
| LG&E | |
| LG&E | |
| Assets | |
| Assets | |
| Assets | Assets | | | | | | | | | | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 7 | | | $ | 7 | | | $ | — | | | $ | — | | | $ | 93 | | | $ | 93 | | | $ | — | | | $ | — | |
| Cash and cash equivalents | |
| Cash and cash equivalents | |
| Restricted cash and cash equivalents (a) | |
| Total Cash, Cash Equivalents and Restricted Cash (b) | |
| | Total assets | |
| Total assets | |
| Total assets | Total assets | $ | 7 | | | $ | 7 | | | $ | — | | | $ | — | | | $ | 93 | | | $ | 93 | | | $ | — | | | $ | — | |
| | Liabilities | Liabilities | | | | | | | | | | | | |
| Liabilities | |
| Liabilities | |
| Price risk management liabilities: | Price risk management liabilities: | | | | | | | | | | | | |
| Price risk management liabilities: | |
| Price risk management liabilities: | |
| Interest rate swaps | |
| Interest rate swaps | |
| Interest rate swaps | Interest rate swaps | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | |
| Total price risk management liabilities | Total price risk management liabilities | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | | | $ | 7 | | | $ | — | |
| | KU | KU | | | | | | | | | | | | | | | |
| KU | |
| KU | | | | |
| Assets | Assets | | | | | | | | | | | | | | | | Assets | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 9 | | | $ | 9 | | | $ | — | | | $ | — | | | $ | 21 | | | $ | 21 | | | $ | — | | | $ | — | |
| Restricted cash and cash equivalents (a) | |
| Total Cash, Cash Equivalents and Restricted Cash (b) | |
| Total assets | Total assets | $ | 9 | | | $ | 9 | | | $ | — | | | $ | — | | | $ | 21 | | | $ | 21 | | | $ | — | | | $ | — | |
(a)IncludedCurrent 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 assets and liabilities classified as Level 3 for the sixthree months ended June 30March 31 is as follows:
| | | | | |
| Gas Contracts |
20232024 | |
| Balance at beginning of period | $ | 5619 | |
| |
| |
| |
| |
| Settlements | (56)(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.
| | | | June 30, 2023 | | December 31, 2022 | | March 31, 2024 | | December 31, 2023 |
| Carrying
Amount (a) | | Fair Value | | Carrying
Amount (a) | | Fair Value |
| Carrying
Amount (a) | | | Carrying
Amount (a) | | Fair Value | | Carrying
Amount (a) | | Fair Value |
| PPL | PPL | $ | 14,572 | | | $ | 13,613 | | | $ | 13,243 | | | $ | 12,239 | |
| PPL Electric | PPL Electric | 4,655 | | | 4,432 | | | 4,486 | | | 4,259 | |
| LG&E | LG&E | 2,404 | | | 2,236 | | | 2,307 | | | 2,128 | |
| KU | KU | 3,003 | | | 2,722 | | | 2,920 | | | 2,616 | |
(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 Senior Director-Risk Management,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, in the event that the counterparties'if a counterparty's credit ratings fall below investment grade, their tangible net worth falls below specified percentages or theirits 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, had no obligation to return or post cash collateral under master netting arrangements at June 30, 2023 and December 31, 2022.
LG&E and KU had no obligation to return or post cash collateral under master netting arrangements at June 30, 2023March 31, 2024 and December 31, 2022.2023.
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 June 30, 2023.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 and six months ended June 30,March 31, 2024 and 2023, and 2022, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.
At June 30, 2023,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 June 30, 2023,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 June 30, 2023,March 31, 2024, RIE held contracts with notional volumes of 4541 Bcf that range in maturity from 2024 through 2025.2029.
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 June 30, 2023March 31, 2024 and December 31, 2022.2023.
See Note 1 in each Registrant's 20222023 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.
| | | June 30, 2023 | | | December 31, 2022 |
| | | | | March 31, 2024 | |
| | | | | March 31, 2024 | |
| | | | | March 31, 2024 | | | | | | | December 31, 2023 |
| | | | Assets | | Liabilities | | | Assets | | Liabilities | | | | | | Assets | | Liabilities | | | | | | Assets | | Liabilities |
| Current: | Current: | | | | | | | | | | Current: | | | | | | | | | | | | | | | |
| Price Risk Management Assets/Liabilities: | Price Risk Management Assets/Liabilities: | | | | | | | | | | Price Risk Management Assets/Liabilities: | | | | | | | | | | | | | | | |
| Interest rate swaps (a) | Interest rate swaps (a) | | $ | — | | | $ | 1 | | | | $ | — | | | $ | 1 | |
| Gas contracts (a) | Gas contracts (a) | | 1 | | | 16 | | | | 20 | | | 62 | |
| | Total current | Total current | | 1 | | | 17 | | | | 20 | | | 63 | |
| | Total current | |
| | Total current | |
| Noncurrent: | Noncurrent: | | | | | | | | | | Noncurrent: | | | | | | | | | | | | | | | |
| Price Risk Management Assets/Liabilities: | Price Risk Management Assets/Liabilities: | | | | | | | | | | Price Risk Management Assets/Liabilities: | | | | | | | | | | | | | | | |
| Interest rate swaps (a) | Interest rate swaps (a) | | — | | | 6 | | | | — | | | 6 | |
| Gas contracts (a) | Gas contracts (a) | | — | | | 7 | | | | 5 | | | 4 | |
| | Total noncurrent | Total noncurrent | | — | | | 13 | | | | 5 | | | 10 | |
| Total noncurrent | |
| Total noncurrent | |
| Total derivatives | Total derivatives | | $ | 1 | | | $ | 30 | | | | $ | 25 | | | $ | 73 | |
(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 June 30, 2023.March 31, 2024.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Three Months | | Six Months | | | | Three Months | | Six Months |
Derivative
Relationships | | Derivative Gain
(Loss) Recognized in
OCI | | Derivative Gain
(Loss) Recognized in
OCI | | Location of
Gain (Loss)
Recognized
in Income
on Derivative | | Gain (Loss)
Reclassified
from AOCI
into Income | | Gain (Loss)
Reclassified
from AOCI
into
Income |
| Cash Flow Hedges: | | | | | | | | | | |
| Interest rate swaps | | $ | — | | | $ | — | | | Interest expense | | $ | (1) | | | $ | (2) | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | |
| | | | 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 | | Six Months |
| Gas contracts | | Energy purchases | | $ | (4) | | | $ | (6) | |
| | Other income(expense) -net | | (1) | | | — | |
| | Total | | $ | (5) | | | $ | (6) | |
| | | | | | |
| | | | | | |
Derivatives Not Designated as
Hedging Instruments | | Location of Gain (Loss) Recognized as
Regulatory Liabilities/Assets | | Three Months | | Six Months |
| Interest rate swaps | | Regulatory assets - noncurrent | | $ | 2 | | | $ | 1 | |
| Gas contracts | | Regulatory assets - current | | 2 | | | (26) | |
| | Regulatory assets - noncurrent | | — | | | 7 | |
| | Total | | $ | 4 | | | $ | (18) | |
| | | | | | | | | | | | | | | | |
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 June 30, 2022.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) | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Three Months | | Six Months | | | | Three Months | | Six Months |
Derivative
Relationships | | Derivative Gain
(Loss) Recognized in
OCI | | Derivative Gain
(Loss) Recognized in
OCI | | Location of
Gain (Loss)
Recognized
in Income
on Derivative | | Gain (Loss)
Reclassified
from AOCI
into Income | | Gain (Loss)
Reclassified
from AOCI
into Income |
| Cash Flow Hedges: | | | | | | | | | | |
| Interest rate swaps | | $ | — | | | $ | — | | | Interest expense | | $ | (1) | | | $ | (2) | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | |
Derivatives Not Designated as
Hedging Instruments | | Location of Gain (Loss) Recognized in
Income on Derivative | | Three Months | | Six Months |
| Interest rate swaps | | Interest expense | | $ | — | | | $ | 1 | |
| Gas contracts | | Energy purchases | | 9 | | | 9 | |
| | Total | | $ | 9 | | | $ | 10 | |
Derivatives Not Designated as
Hedging Instruments | | Location of Gain (Loss) Recognized as
Regulatory Liabilities/Assets | | Three Months | | Six Months |
| Interest rate swaps | | Regulatory assets - noncurrent | | $ | 4 | | | $ | 8 | |
| | | | | | |
| | | | | | |
| | | | | | |
| | | | | | | | | | | | | | | | |
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 June 30, 2023.March 31, 2024.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships | |
| Three Months | | Six Months | |
| Interest Expense | | Other Income (Expense) - net | | Interest Expense | | | | Other Income (Expense) - net | |
| Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded | $ | 165 | | | $ | 5 | | | $ | 329 | | | | | $ | 35 | | |
| 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) | | | — | | | (2) | | | | | — | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | 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 June 30, 2022.March 31, 2023.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships | |
| Three Months | | Six Months | |
| Interest Expense | | Other Income (Expense) - net | | Interest Expense | | | | Other Income (Expense) - net | |
| Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded | $ | 118 | | | $ | 26 | | | $ | 225 | | | | | $ | 26 | | |
| 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) | | | — | | | (2) | | | | | — | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | 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.
| | | | June 30, 2023 | | December 31, 2022 | | March 31, 2024 | | December 31, 2023 |
| | | Assets | | Liabilities | | Assets | | Liabilities | | Assets | | Liabilities | | Assets | | Liabilities |
| Current: | Current: | | | | | | | | Current: | | | | | | | |
| Price Risk Management Assets/Liabilities: | Price Risk Management Assets/Liabilities: | | | | | | | | Price Risk Management Assets/Liabilities: | | | | | | | |
| Interest rate swaps | Interest rate swaps | $ | — | | | $ | 1 | | | $ | — | | | $ | 1 | |
| | Total current | Total current | — | | | 1 | | | — | | | 1 | |
| | Total current | |
| | Total current | |
| Noncurrent: | Noncurrent: | | | | | | | | Noncurrent: | | | | | | | |
| Price Risk Management Assets/Liabilities: | Price Risk Management Assets/Liabilities: | | | | | | | | Price Risk Management Assets/Liabilities: | | | | | | | |
| Interest rate swaps | Interest rate swaps | — | | | 6 | | | — | | | 6 | |
| Total noncurrent | Total noncurrent | — | | | 6 | | | — | | | 6 | |
| Total derivatives | Total derivatives | $ | — | | | $ | 7 | | | $ | — | | | $ | 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 June 30, 2023.March 31, 2024.
| | | | | | | | | | | | | | | | | | | | |
| | | Location of Gain (Loss) Recognized in | | | | |
| Derivative Instruments | | Income on Derivatives | | Three Months | | Six Months |
| Interest rate swaps | | Interest expense | | $ | — | | | $ | — | |
| | | Location of Gain (Loss) Recognized in | | | | |
| Derivative Instruments | | Regulatory Assets | | Three Months | | Six Months |
| Interest rate swaps | | Regulatory assets - noncurrent | | $ | 2 | | | $ | 1 | |
| | | | | | | | | | | | | | | | |
| | 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 June 30, 2022.March 31, 2023.
| | | | | | | | | | | | | | | | | | | | |
| | | Location of Gain (Loss) Recognized in | | | | |
| Derivative Instruments | | Income on Derivatives | | Three Months | | Six Months |
| Interest rate swaps | | Interest expense | | $ | — | | | $ | 1 | |
| | | Location of Gain (Loss) Recognized in | | | | |
| Derivative Instruments | | Regulatory Assets | | Three Months | | Six Months |
| Interest rate swaps | | Regulatory assets - noncurrent | | $ | 4 | | | $ | 8 | |
| | | | | | | | | | | | | | | | |
| | 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 | | Assets | | Liabilities |
| | | | | Eligible for Offset | | | | | | Eligible for Offset | | | | | | Eligible for Offset | | | | | | Eligible for Offset | | |
| Gross | | Derivative
Instruments | | Cash
Collateral
Received | | Net | | Gross | | Derivative
Instruments | | Cash
Collateral
Pledged | | Net |
| June 30, 2023 | | | | | | | | | | | | | | | |
| Gross | | | Gross | | Derivative
Instruments | | Cash
Collateral
Received | | Net | | Gross | | Derivative
Instruments | | Cash
Collateral
Pledged | | Net |
| March 31, 2024 | | March 31, 2024 | | | |
| Derivatives | Derivatives | | | | | | | | | | | | | | | | Derivatives | | | |
PPL | PPL | $ | 1 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 30 | | | $ | 1 | | | $ | — | | | $ | 29 | |
| LG&E | LG&E | — | | | — | | | — | | | — | | | 7 | | | — | | | — | | | 7 | |
| | | | Assets | | Liabilities | | Assets | | Liabilities |
| | | | | Eligible for Offset | | | | | | Eligible for Offset | | | | | | Eligible for Offset | | | | | | Eligible for Offset | | |
| Gross | | Derivative
Instruments | | Cash
Collateral
Received | | Net | | Gross | | Derivative
Instruments | | Cash
Collateral
Pledged | | Net |
| December 31, 2022 | | | | | | | | | | | | | | | |
| Gross | | | Gross | | Derivative
Instruments | | Cash
Collateral
Received | | Net | | Gross | | Derivative
Instruments | | Cash
Collateral
Pledged | | Net |
| December 31, 2023 | | December 31, 2023 | | | | | | | | | |
| Derivatives | Derivatives | | | | | | | | | | | | | | Derivatives | | | | | | | | | |
| PPL | PPL | $ | 25 | | | $ | 20 | | | $ | — | | | $ | 5 | | | $ | 73 | | | $ | 62 | | | $ | — | | | $ | 11 | |
| LG&E | 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 June 30, 2023,March 31, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features collateral posted on those positions andwas $28 million. At March 31, 2024, the related effect of a decrease in credit ratings below investment grade was $22 million. The aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $22$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 hashave 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 KU,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, 2022 | $ | 177 | | | $ | 86 | | | $ | 82 | |
| Accretion | 4 | | | 2 | | | 2 | |
| New obligations incurred | 2 | | | 1 | | | 1 | |
| Changes in estimated cash flow or settlement date | (1) | | | 1 | | | — | |
| Obligations settled | (16) | | | (6) | | | (10) | |
| Other | (5) | | | (6) | | | — | |
| Balance at June 30, 2023 | $ | 161 | | | $ | 78 | | | $ | 75 | |
| | | | | | | | | | | | | | | | | |
| | 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 | |
16. Accumulated Other Comprehensive Income (Loss)
(PPL)
The after-tax changes in AOCI by component for the periods ended June 30March 31 were as follows.
| | | | | Unrealized gains (losses)
on qualifying
derivatives | | | | Defined benefit plans | | |
| | | | Equity
investees'
AOCI | | Prior
service
costs | | Actuarial
gain
(loss) | | Total |
| | | | | | | | | Unrealized gains (losses)
on qualifying
derivatives | | | | Defined benefit plans | | |
| | | | | | Equity
investees'
AOCI | | | | | | | | Equity
investees'
AOCI | | Prior
service
costs | | Actuarial
gain
(loss) | | Total |
| PPL | PPL | | | | | | | | | | |
| March 31, 2023 | | $ | 4 | | | $ | 3 | | | $ | (5) | | | $ | (125) | | | $ | (123) | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| | December 31, 2023 | |
| Amounts arising during the period | Amounts arising during the period | | — | | | — | | | — | | | (15) | | | (15) | |
| Reclassifications from AOCI | Reclassifications from AOCI | | — | | | — | | | 1 | | | — | | | 1 | |
| Net OCI during the period | Net OCI during the period | | — | | | — | | | 1 | | | (15) | | | (14) | |
| June 30, 2023 | | $ | 4 | | | $ | 3 | | | $ | (4) | | | $ | (140) | | | $ | (137) | |
| March 31, 2024 | |
| | December 31, 2022 | |
| | December 31, 2022 | |
| | | December 31, 2022 | December 31, 2022 | | $ | 3 | | | $ | 2 | | | $ | (5) | | | $ | (124) | | | $ | (124) | |
| Amounts arising during the period | Amounts arising during the period | | — | | | 1 | | | — | | | (15) | | | (14) | |
| Reclassifications from AOCI | Reclassifications from AOCI | | 1 | | | — | | | 1 | | | (1) | | | 1 | |
| Net OCI during the period | | 1 | | | 1 | | | 1 | | | (16) | | | (13) | |
| June 30, 2023 | | $ | 4 | | | $ | 3 | | | $ | (4) | | | $ | (140) | | | $ | (137) | |
| | March 31, 2022 | | $ | 2 | | | $ | 1 | | | $ | (6) | | | $ | (149) | | | $ | (152) | |
| Amounts arising during the period | | — | | | 1 | | | — | | | 21 | | | 22 | |
| Reclassifications from AOCI | | — | | | — | | | — | | | 6 | | | 6 | |
| | Net OCI during the period | Net OCI during the period | | — | | | 1 | | | — | | | 27 | | | 28 | |
| June 30, 2022 | | $ | 2 | | | $ | 2 | | | $ | (6) | | | $ | (122) | | | $ | (124) | |
| | December 31, 2021 | | $ | 1 | | | $ | — | | | $ | (6) | | | $ | (152) | | | $ | (157) | |
| Amounts arising during the period | | — | | | 2 | | | (1) | | | 21 | | | 22 | |
| Reclassifications from AOCI | | 1 | | | — | | | 1 | | | 9 | | | 11 | |
| | Net OCI during the period | Net OCI during the period | | 1 | | | 2 | | | — | | | 30 | | | 33 | |
| June 30, 2022 | | $ | 2 | | | $ | 2 | | | $ | (6) | | | $ | (122) | | | $ | (124) | |
| Net OCI during the period | |
| March 31, 2023 | |
The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30.March 31.
| | Three Months | | Six Months | | Affected Line Item on the |
| | | | Three Months | |
| | | | Three Months | |
| | | | Three Months | | | Affected Line Item on the |
| Details about AOCI | Details about AOCI | | 2023 | | 2022 | | 2023 | | 2022 | | Statements of Income | Details about AOCI | | | | | | 2024 | | 2023 | | Statements of Income |
| Qualifying derivatives | Qualifying derivatives | | | | | | | | | | | Qualifying derivatives | | | | | | | | |
| Interest rate swaps | Interest rate swaps | | $ | (1) | | | $ | (1) | | | $ | (2) | | | $ | (2) | | | Interest Expense | Interest rate swaps | | | | | | $ | (1) | | | $ | | $ | (1) | | | Interest Expense | | Interest Expense |
| | Total Pre-tax | Total Pre-tax | | (1) | | | (1) | | | (2) | | | (2) | | |
| | Total Pre-tax | |
| | Total Pre-tax | |
| Income Taxes | |
| Income Taxes | |
| Income Taxes | Income Taxes | | 1 | | | 1 | | | 1 | | | 1 | | | | | | | | | — | | | — | | — | | | | | |
| Total After-tax | Total After-tax | | — | | | — | | | (1) | | | (1) | | | | Total After-tax | | | | | | (1) | | | (1) | | (1) | | | | | |
| | | Defined benefit plans | Defined benefit plans | | | | | | | | | |
| Prior service costs (a) | | (1) | | | — | | | (1) | | | (1) | | |
| | Defined benefit plans | |
| | Defined benefit plans | |
| | Net actuarial loss (a) | |
| | Net actuarial loss (a) | |
| | Net actuarial loss (a) | Net actuarial loss (a) | | 1 | | | (8) | | | 2 | | | (12) | | |
| Total Pre-tax | Total Pre-tax | | — | | | (8) | | | 1 | | | (13) | | |
| Total Pre-tax | |
| Total Pre-tax | |
| Income Taxes | Income Taxes | | (1) | | | 2 | | | (1) | | | 3 | | |
| Income Taxes | |
| Income Taxes | |
| Total After-tax | |
| Total After-tax | |
| Total After-tax | Total After-tax | | (1) | | | (6) | | | — | | | (10) | | |
| | | Total reclassifications during the period | Total reclassifications during the period | | $ | (1) | | | $ | (6) | | | $ | (1) | | | $ | (11) | | |
| | Total reclassifications during the period | |
| | Total reclassifications during the period | |
(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
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.
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' 20222023 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 and six months ended June 30, 2023March 31, 2024 with the same periodsperiod in 2022.2023. The PPL "Results of Operations" also includes "Segment Earnings"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).
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | 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)
Beginning on January 1, 2023,PPL is organized into three reportable segments as depicted in the chart above: Kentucky Regulated, segment consistswhich primarily ofrepresents the regulated electricity generation, transmission and distribution operations conducted byresults of LG&E and KU, as well as LG&E's regulated distributionPennsylvania Regulated, which primarily represents the results of PPL Electric, and saleRhode Island Regulated, which primarily represents the results of natural gas. Prior to January 1, 2023, the Kentucky Regulated segment also included the financing activities of LKE. The financing activity of LKE is presented inRIE. "Corporate and Other" beginning on January 1, 2023. Prior periods have been adjusted to reflect this change. As a result, PPL’s segments consist of its regulated operations in Kentucky, Pennsylvania and Rhodeprimarily includes corporate level financing
Islandcosts, certain unallocated costs, and exclude any incremental financing activitiescertain non-recoverable costs incurred in conjunction with the acquisition of holding companies, which Management believes is a more meaningful presentation as it provides information on the core regulated operations of PPL.Narragansett Electric.
Business Strategy
(All Registrants)
PPL operates four fully regulated utilities located in Pennsylvania, Kentucky and Rhode Island, which are constructive regulatoryIsland. Each of these jurisdictions withhas 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
IRS Revenue Procedure 2023-15Transfer of Certain Credits under the Inflation Reduction Act (PPL and LG&E)(PPL)
On April 14, 2023,25, 2024, the IRS issuedreleased the final Internal Revenue Procedure 2023-15, which provides a safe harbor methodCode Section 6418 regulations related to the transfer of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmissioncertain credits under the Inflation Reduction Act. The regulations were published in the Federal Register on April 30, 2024, and distribution property mustwill be capitalized for tax purposes.effective on July 1, 2024. PPL and LG&E areis currently reviewing the revenue procedurefinal regulations to determine what impact the newly issued 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 anticipates retiringhas sought and obtained approval to retire two older coal-fired units at the Mill Creek Plant and KU anticipates retiring one coal-fired unit at each of the E.W. Brown and Ghent plants.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. E.W. Brown Unit 3, with 412 MW of capacity, and Ghent Unit 2, with 486 MW of capacity, are expected2027, subject to becertain conditions. See Note 6 to the Financial Statements for additional information.
retired in 2028. On May 10, 2023, LG&E and KU submitted an application with the KPSC requesting approval of the relevant proposed retirements. LG&E and KU expect to recover the associated retirement costs, including the remaining net book value, for these coal-fired generating units through the RAR or other rate mechanisms in the future.
CPCN and SB 4 Application
On December 15, 2022, LG&E and KU filed an application with the KPSC for a CPCN for the construction of two 621 MW net summer rating NGCC combustion turbine facilities, one at LG&E's Mill Creek Generating Station in Jefferson County, Kentucky and the other at KU's E.W. Brown Generating Station in Mercer County, Kentucky, including on-site natural gas and electric transmission construction associated with those facilities and site compatibility certificates. LG&E and KU also applied for a CPCN to construct a 120 MWac solar photovoltaic electric generating facility in Mercer County, Kentucky, and for a CPCN to acquire a 120 MWac solar facility to be built by a third-party solar developer in Marion County, Kentucky. LG&E and KU further applied for a CPCN to construct a 125 MW, 4-hour battery energy storage system facility at KU's E.W. Brown Generating Station and for approval of their proposed 2024-2030 DSM programs. The plan includes adding 14 new, adjusted or expanded energy efficiency programs, which would reduce LG&E's and KU's overall need by approximately 100 MW each. Finally, LG&E and KU requested a declaratory order to confirm that their entry into non-firm energy-only power-purchase agreements for the output of four solar photovoltaic facilities with a combined capacity of 637 MW does not require KPSC approval and that LG&E and KU may recover the costs of the solar PPAs through their fuel adjustment clause mechanisms as previously approved for a prior solar PPA. LG&E and KU plan to accrue AFUDC on the constructed NGCC facilities, the solar facility in Mercer County, Kentucky and the battery energy storage system facility and have requested regulatory asset treatment to recover the financing costs of these projects.
The plan is consistent with PPL's goal to achieve net-zero carbon emissions by 2050. PPL has estimated that the replacement strategy contemplated by the plan would reduce the carbon intensity of LG&E and KU's generation fleet and result in greenhouse gas emissions reductions that support achievement of 2035 and 2040 interim targets of 70% and 80%, respectively.
The KPSC accepted the CPCN filing as of January 6, 2023. On March 24, 2023, Kentucky Senate Bill 4 (SB 4) went into effect, which requires KPSC approval of fossil fuel-fired electric generating unit retirements in the state. On May 10, 2023, LG&E and KU filed an application with the KPSC seeking approval of the retirement of seven fossil fuel-fired generating units as required by the recently enacted SB 4. On May 16, 2023, the KPSC entered an Order consolidating the SB 4 filing proceeding into the CPCN case. The KPSC has indicated its intention to issue an order on all issues by November 6, 2023. PPL, LG&E and KU cannot predict the outcome of these matters.
Kentucky March 2023 Storm
On March 3, 2023, LG&E and KU experienced significant windstorm activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total costs incurred through June 30, 2023 of $75 million ($33 million at LG&E and $42 million at KU). On March 17, 2023, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the windstorm. On April 5, 2023, the KPSC issued an order approving the request for accounting purposes, noting that approval for recovery would be determined in LG&E’s and KU’s next base rate cases. As of June 30, 2023, LG&E and KU recorded regulatory assets related to the storm of $8 million and $11 million.
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. On June 9, 2023, the FERC granted LG&E’s and KU’s motion for an extension of time to process refunds until November 2023. LG&E and KU filed a request for rehearing of the May 18, 2023 order, which was denied by operation of law on July 17, 2023. LG&E and KU filed 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 July 28,December 1, 2023. In the second quarter ofThe FERC issued an order on LG&E and KU's compliance filing on November 16, 2023, and LG&E and KU recorded regulatory liabilitiesfiled a petition for review of $3 millionthis 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 $8 million relatedKU'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 potential refunds resulting fromlift the FERC’sabeyance on April 24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May 18, 2023 order.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 provided primarily through base rates withincreases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be primarily subject to base rate recovery in future rate proceedings.
(PPL)
FY 20242025 Gas Infrastructure, Safety and Reliability (ISR)ISR Plan
On December 23, 2022,22, 2023, RIE filed its FY 20242025 Gas ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplementalwith a budget that was filed with the RIPUC on January 27, 2023 includes $187$185 million of capital investment spend. The supplemental rate schedules werespend, 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 on February 3, 2023. RIEits proposed gas ISR plan budgetary and the Rhode Island Division of Public Utilities and Carriers reached an agreement on an approximately $171 million capital investment spending plan, and RIE filed a second supplemental budget on March 13, 2023.reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held a hearing on the plan hearings in March 2024, and on March 14, 2023. At an Open Meeting on March 29, 2023, the RIPUC26, 2024, approved the plan, with an adjustment toincluding the budget for the Proactive Main Replacement Program category resulting inproposed budgetary and reconciliation framework, with a total approved FY 20242025 Gas ISR Plan of $163$180 million of which $168 million is for capital investment spend.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 31, 2023,28, 2024, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan process. RIE cannot predict the outcome of this matter.2024.
FY 20242025 Electric ISR Plan
On December 23, 2022,21, 2023, RIE filed its FY 20242025 Electric ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplementalwith a budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget filed with the RIPUC on January 27, 2023that includes $176$141 million of capital investment spend, $14$13 million of vegetation operations and management (O&M) spend and $3 million of Other O&M spend. The supplemental rate schedules were filed on February 3, 2023. RIE filed second supplemental budget schedules on March 21, 2023, which includes $166 million of capital investment spend, $14 million of vegetation management 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 2023,2024, and on March 29, 2023,26, 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 20242025 Electric ISR Plan of $112$132 million for capital investment spend, $14$13 million for vegetation management O&M spend, and $1 million for Other O&M spend.On March 31, 2023,28, 2024, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. The2024.
Advanced Metering Functionality (AMF)
In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC continuesin accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to considerdeploy smart meters throughout the appropriate rate recovery treatmentservice territory. After PPL completed the acquisition of projects not covered byRIE, 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 ISR planAMF-based metering system for the applicable fiscal year,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 additional definitions and procedures that may be implemented relatedlimitations with respect to the ISR plan process.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 and six months ended June 30, 2023March 31, 2024 with the same periodsperiod in 2022.2023. 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.
(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 and six months ended June 30, 2023March 31, 2024 with the same periodsperiod in 2022.2023.
(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 June 30March 31 includes the following results:
| | | |
| | | | Three Months | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change | | | | | | | | 2024 | | 2023 | | $ Change |
| Operating Revenues | Operating Revenues | $ | 1,823 | | | $ | 1,696 | | | $ | 127 | | | $ | 4,238 | | | $ | 3,478 | | | $ | 760 | |
| | Operating Expenses | Operating Expenses | |
| Operating Expenses | |
| Operating Expenses | |
| Operation | Operation | |
| Operation | |
| Operation | |
| Fuel | |
| Fuel | |
| Fuel | Fuel | 167 | | | 229 | | | (62) | | | 368 | | | 441 | | | (73) | |
| Energy purchases | Energy purchases | 340 | | | 305 | | | 35 | | | 1,074 | | | 657 | | | 417 | |
| Other operation and maintenance | Other operation and maintenance | 609 | | | 560 | | | 49 | | | 1,168 | | | 993 | | | 175 | |
| Depreciation | Depreciation | 313 | | | 289 | | | 24 | | | 626 | | | 560 | | | 66 | |
| Taxes, other than income | Taxes, other than income | 89 | | | 70 | | | 19 | | | 199 | | | 130 | | | 69 | |
| Total Operating Expenses | Total Operating Expenses | 1,518 | | | 1,453 | | | 65 | | | 3,435 | | | 2,781 | | | 654 | |
| Operating Income | |
| Other Income (Expense) - net | Other Income (Expense) - net | 5 | | | 26 | | | (21) | | | 35 | | | 26 | | | 9 | |
| Interest Expense | Interest Expense | 165 | | | 118 | | | 47 | | | 329 | | | 225 | | | 104 | |
| Income Before Income Taxes | Income Before Income Taxes | 145 | | | 151 | | | (6) | | | 509 | | | 498 | | | 11 | |
| Income Taxes | Income Taxes | 33 | | | 32 | | | 1 | | | 112 | | | 106 | | | 6 | |
| | Net Income | Net Income | $ | 112 | | | $ | 119 | | | $ | (7) | | | $ | 397 | | | $ | 392 | | | $ | 5 | |
| | Net Income | |
| | Net Income | |
Operating Revenues
The increase (decrease) in operating revenues was due to:
| | | | | | | | | | | |
| Three Months | | Six Months |
| PPL Electric distribution price (a) | $ | 13 | | | $ | 40 | |
| PPL Electric distribution volume (b) | (18) | | | (47) | |
| PPL Electric PLR (c) | (15) | | | 98 | |
| PPL Electric transmission formula rate (d) | 9 | | | 17 | |
| | | |
| | | |
| | | |
| LG&E volumes (b) | (29) | | | (72) | |
| LG&E fuel and other energy prices (e) | (33) | | | (22) | |
| | | |
| LG&E economic relief billing credit, net of amortization of $0 | 6 | | | 12 | |
| | | |
| KU volumes (b) | (34) | | | (79) | |
| KU fuel and other energy prices (e) | (25) | | | (16) | |
| | | |
| | | |
| | | |
| | | |
| | | |
| KU economic relief billing credit, net of amortization of $0 | 3 | | | 5 | |
| Acquisition of RIE | 249 | | | 814 | |
| Other | 1 | | | 10 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Total | $ | 127 | | | $ | 760 | |
| | | | | | | |
| | | 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 increases wereincrease was primarily due to reconcilable cost recovery mechanisms approved by the PAPUC.
(b)The decreasesincreases were primarily due to lower volumes due to weather.weather, along with other higher usage in 2024 at PPL Electric.
(c)The increase for the six month perioddecrease was primarily the result of higherfewer PLR customers, and lower energy prices, and more PLR customers, partially offset by lowerhigher customer volumes due to weather.weather and other higher usage.
(d)The increases wereincrease 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 and returns on additional transmission capital investments, partially offset by a lower PPL zonal peak load billing factor in 2023.variance.
(e)The decreases weredecrease 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 lowerhigher commodity costs.costs and volumes.
Fuel
Fuel decreased $62 million for the three months ended June 30, 2023 compared with 2022,The decrease was primarily due to a decrease in commodity costslower recoveries of $13 million at LG&Eenergy purchases and $27 million at KU and a decrease in volumes due to weathergross earnings tax, partially offset by higher recoveries of $9 million at LG&E and $14 million at KU.
Fuel decreased $73 million for the six months ended June 30, 2023 compared with 2022, primarily due to a decrease in volumes due to weather of $14 million at LG&E and $29 million at KU and a decrease in commodity costs of $11 million at LG&E and $20 million at KU.
Energy Purchases
Energy purchases increased $35decreased $214 million for the three months ended June 30, 2023March 31, 2024 compared with 2022, primarily2023, primarily due to higherlower PLR prices of $39$108 million at PPL Electric and an additional $70 million due to the operations of RIE, partially offset by lower PLR volumes of $52 million at PPL Electric and a decrease in commodity costs at LG&E of $20 million.
Energy purchases increased $417 million for the six months ended June 30, 2023 compared with 2022, primarily due to higher PLR prices of $161 million at PPL Electric and an additional $356 million due to the operations of RIE, partially offset by lower PLR volumes of $77$33 million at PPL Electric, a decrease in volumes due to weathercommodity costs of $21 million at LG&E of $20 million 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 of $8 million.&E.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| | | | | | | | | | | |
| Three Months | | Six Months |
| PPL Electric storm costs | $ | — | | | $ | (3) | |
| PPL Electric vegetation management expenses | (3) | | | (4) | |
| PPL Electric support costs | (5) | | | (8) | |
| PPL Electric bad debts | 7 | | | 11 | |
| PPL Electric operation costs | 8 | | | 8 | |
| PPL Electric IT cloud amortization costs | 7 | | | 13 | |
| | | |
| LG&E plant operations and maintenance expenses | (9) | | | (12) | |
| LG&E transmission credits | 3 | | | 3 | |
| LG&E generation outage expenses | (1) | | | (2) | |
| LG&E vegetation management expenses | (2) | | | (4) | |
| | | |
| | | |
| KU generation outage expenses | (4) | | | (6) | |
| KU transmission credits | 7 | | | 7 | |
| | | |
| | | |
| KU vegetation management expenses | (2) | | | (5) | |
| Acquisition of RIE (a) | 61 | | | 204 | |
| | | |
| | | |
| | | |
| Other | (18) | | | (27) | |
| Total | $ | 49 | | | $ | 175 | |
(a)Includes activity associated with the operations of RIE, along with integration and related costs. See Note 8 to the Financial Statements for additional information.
Depreciation
The increase (decrease) in depreciation was due to:
| | | | | | | | | | | |
| | Three Months | | Six Months |
| Additions to PP&E, net | $ | 3 | | | $ | 7 | |
| VA rate case adjustment | (2) | | | (2) | |
| | | |
| Acquisition of RIE | 25 | | | 64 | |
| Other | (2) | | | (3) | |
| Total | $ | 24 | | | $ | 66 | |
| | | | | | | |
| | | 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 | | Six Months |
| State gross receipts tax (a) | $ | 7 | | | $ | 35 | |
| Domestic property tax expense (a) | 13 | | | 34 | |
| Other | (1) | | | — | |
| Total | $ | 19 | | | $ | 69 | |
| | | | | | | |
| | | Three Months |
| State gross earnings and gross receipts tax (a) | | | $ | (30) | |
| Property tax expense | | | 8 | |
| | | |
| Total | | | $ | (22) | |
(a)The increases weredecrease was primarily duerelated to the acquisition of RIE.
Other Income (Expense) - net
The increase (decrease) in other income (expense) - net was due to:
| | | | | | | | | | | |
| | Three Months | | Six Months |
| Defined benefit plans - non-service credits (Note 9) | $ | (10) | | | $ | (4) | |
| Interest income | 9 | | | 19 | |
| Other (a) | (20) | | | (6) | |
| Total | $ | (21) | | | $ | 9 | |
(a)See Note 12 for additional information.RIE Gross Earnings Tax Holiday Credit.
Interest Expense
The increase (decrease) in interest expense was due to:
| | | | | | | | | | | |
| | Three Months | | Six Months |
| | | |
| Long-term debt (a) | $ | 37 | | | $ | 71 | |
| Acquisition of RIE | 10 | | | 27 | |
| Short-term debt | — | | | 5 | |
| Other | — | | | 1 | |
| Total | $ | 47 | | | $ | 104 | |
| | | | | | | |
| | | Three Months |
| | | |
| Long-term debt (a) | | | $ | 16 | |
| | | |
| | | |
| Other | | | (1) | |
| Total | | | $ | 15 | |
(a) The increases wereincrease was primarily due to increased borrowings at LG&E, KU, PPL Electric and PPL Capital Funding, along with higher rates at PPL Capital Funding.borrowings. See Note 7 to the Financial Statements for additional information.
Income Taxes
Segment Earnings
The increase (decrease) in income taxesPPL's Net Income (Loss) by reportable segment for the periods ended March 31 was due to:
| | | | | | | | | | | |
| | Three Months | | Six Months |
| Change in pre-tax income | $ | (18) | | | $ | (13) | |
| Valuation allowance adjustments | (2) | | | (3) | |
| | | |
| Amortization of investment tax credit including deferred taxes on basis difference | 4 | | | 6 | |
| | | |
| Amortization of excess deferred income taxes | 14 | | | 20 | |
| Other | 3 | | | (4) | |
| Total | $ | 1 | | | $ | 6 | |
Segment Earnings
PPL's Net Income by reportable segment for the periods ended June 30 was as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change |
| | | | | | | | | | | |
| Kentucky Regulated (a) | $ | 91 | | | $ | 112 | | | $ | (21) | | | $ | 257 | | | $ | 301 | | | $ | (44) | |
| Pennsylvania Regulated | 110 | | | 124 | | | (14) | | | 248 | | | 267 | | | (19) | |
| Rhode Island Regulated | 10 | | | (29) | | | 39 | | | 64 | | | (29) | | | 93 | |
| Corporate and Other (a) (b) | (99) | | | (88) | | | (11) | | | (172) | | | (147) | | | (25) | |
| | | | | | | | | | | |
| Net Income | $ | 112 | | | $ | 119 | | | $ | (7) | | | $ | 397 | | | $ | 392 | | | $ | 5 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| | | | 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)The financing activity of LKE is presented in Corporate and Other beginning on January 1, 2023. Prior periods have been adjusted to reflect this change.
(b)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 June 30March 31 were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months | | Six Months |
| | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change |
| Kentucky Regulated (a) | $ | 96 | | | $ | 114 | | | $ | (18) | | | $ | 263 | | | $ | 307 | | | $ | (44) | |
| Pennsylvania Regulated | 117 | | | 124 | | | (7) | | | 254 | | | 267 | | | (13) | |
| Rhode Island Regulated | 23 | | | 9 | | | 14 | | | 94 | | | 9 | | | 85 | |
| Corporate and Other (a) | (21) | | | (25) | | | 4 | | | (44) | | | (56) | | | 12 | |
| Earnings from Ongoing Operations | $ | 215 | | | $ | 222 | | | $ | (7) | | | $ | 567 | | | $ | 527 | | | $ | 40 | |
(a)The financing activity of LKE is presented in Corporate and Other beginning on January 1, 2023. Prior periods have been adjusted to reflect this change. | | | | | | | | | | | | | | | | | | | | | | | |
| | | | 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 theLG&E's and KU's 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.
Net Income and Earnings from Ongoing Operations for the periods ended June 30March 31 include the following results.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months | | Six Months |
| 2023 | | 2022 (a) | | $ Change | | 2023 | | 2022 (a) | | $ Change |
| Operating revenues | $ | 778 | | | $ | 883 | | | $ | (105) | | | $ | 1,738 | | | $ | 1,887 | | | $ | (149) | |
| Fuel | 167 | | | 229 | | | (62) | | | 368 | | | 441 | | | (73) | |
| Energy purchases | 28 | | | 50 | | | (22) | | | 118 | | | 146 | | | (28) | |
| Other operation and maintenance | 217 | | | 234 | | | (17) | | | 426 | | | 459 | | | (33) | |
| Depreciation | 174 | | | 173 | | | 1 | | | 347 | | | 342 | | | 5 | |
| Taxes, other than income | 23 | | | 23 | | | — | | | 46 | | | 46 | | | — | |
| Total operating expenses | 609 | | | 709 | | | (100) | | | 1,305 | | | 1,434 | | | (129) | |
| Other Income (Expense) - net | 3 | | | 8 | | | (5) | | | 6 | | | 6 | | | — | |
| | | | | | | | | | | |
| Interest Expense | 59 | | | 49 | | | 10 | | | 117 | | | 96 | | | 21 |
| | | | | | | | | | | |
| Income Taxes | 22 | | | 21 | | | 1 | | | 65 | | | 62 | | | 3 | |
| Net Income | 91 | | | 112 | | | (21) | | | 257 | | | 301 | | | (44) | |
| Less: Special Items | (5) | | | (2) | | | (3) | | | (6) | | | (6) | | | — | |
| Earnings from Ongoing Operations | $ | 96 | | | $ | 114 | | | $ | (18) | | | $ | 263 | | | $ | 307 | | | $ | (44) | |
(a)The financing activity of LKE is presented in Corporate and Other beginning on January 1, 2023. Prior periods have been adjusted to reflect this change. | | | | | | | | | | | | | | | | | | | | | | | |
| | | 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 June 30.March 31.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Income Statement Line Item | | Three Months | | Six Months |
| | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| | | | | | | | | |
| Strategic corporate initiatives, net of tax of $1, $0, $2 (a) | Other operation and maintenance | | $ | — | | | $ | (2) | | | $ | (1) | | | $ | (6) | |
| FERC transmission credit refund, net of tax of $2, $2 (b) | Other operation and maintenance | | (5) | | | — | | | (5) | | | — | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Total Special Items | | | $ | (5) | | | $ | (2) | | | $ | (6) | | | $ | (6) | |
| | | | | | | | | | | | | | | | | | | |
| 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.
(b)Prior period impact related to a FERC refund order. See Note 6 to the Financial Statements for additional information.
The changes in the components of the Kentucky Regulated segment's results between thesethe three month periods wereare 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 | |
| | | |
| | | |
•Lower operating revenues for the three month period primarily due to a $63 million decrease in sales volumes primarily due to weather and a $58 million decrease in recoveries of fuel and energy purchases due to lower commodity costs, partially offset by a $9 million increase due to the expiration of the economic relief billing credit from June 2022 and other items that were not individually significant.
•LowerHigher operating revenues for the six month period primarily due to a $151 million decreasean increase in sales volumes primarily due to weather and a $38 million decrease in recoveries of fuel and energy purchases due to lower commodity costs, partially offset by a $17 million increase due to the expiration of the economic relief billing credit from June 2022 and other items that were not individually significant.
•Lower fuel expense for the three month period primarily due to a $40 million decrease in commodity costs and a $23 million decrease in volumes duerelated to weather.
•LowerHigher fuel expense for the six month period primarily due to a $43$13 million decreaseincrease in generation volumes primarily due to weather, andpartially offset by a $31$5 million decrease in commodity costs.
•Lower energy purchases for the three month period primarily due to a $20$21 million decrease in commodity costs.costs, partially offset by an $8 million increase in volumes primarily due to weather.
•Lower energy purchases for the six month period primarily due to a $20 million decrease in volumes due to weather and a $8 million decrease in commodity costs.
•Lower other operation and maintenance expense for the three month period primarilydue to a $5 million decrease in generation outage expenses, a $4 million decrease in vegetation management expenses and other items that were not individually significant.
•Lower operation and maintenance expense for the six month period primarily due to a $9 million decrease in vegetation management expenses, an $8 million decrease in generation outage expenses and other items that were not individually significant.
•Higher interest expense for the three and six month periods primarily due to increased borrowings.
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 June 30March 31 include the following results.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months | | Six Months |
| 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change |
| Operating revenues | $ | 667 | | | $ | 676 | | | $ | (9) | | | $ | 1,558 | | | $ | 1,451 | | | $ | 107 | |
| | | | | | | | | | | |
| Energy purchases | 204 | | | 218 | | | (14) | | | 562 | | | 474 | | | 88 | |
| Other operation and maintenance | 141 | | | 128 | | | 13 | | | 303 | | | 288 | | | 15 | |
| Depreciation | 99 | | | 99 | | | — | | | 198 | | | 197 | | | 1 | |
| Taxes, other than income | 30 | | | 32 | | | (2) | | | 74 | | | 69 | | | 5 | |
| Total operating expenses | 474 | | | 477 | | | (3) | | | 1,137 | | | 1,028 | | | 109 | |
| Other Income (Expense) - net | 9 | | | 9 | | | — | | | 21 | | | 17 | | | 4 | |
| Interest Expense | 54 | | | 40 | | | 14 | | | 111 | | | 79 | | | 32 | |
| | | | | | | | | | | |
| | | | | | | | | | | |
| Income Taxes | 38 | | | 44 | | | (6) | | | 83 | | | 94 | | | (11) | |
| Net Income | 110 | | | 124 | | | (14) | | | 248 | | | 267 | | | (19) | |
| Less: Special Items | (7) | | | — | | | (7) | | | (6) | | | — | | | (6) | |
| Earnings from Ongoing Operations | $ | 117 | | | $ | 124 | | | $ | (7) | | | $ | 254 | | | $ | 267 | | | $ | (13) | |
| | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| | | 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 June 30.March 31.
| | Income Statement Line Item | | Three Months | | Six Months |
| 2023 | | 2022 | | 2023 | | 2022 |
| Income Statement Line Item | |
| Income Statement Line Item | |
| Income Statement Line Item | | | | | Three Months |
| | | | | | 2024 | | | | | | | | 2024 | | 2023 |
| | PA tax rate change (a) | PA tax rate change (a) | Income Taxes | | $ | — | | | $ | — | | | $ | 1 | | | $ | — | |
| PPL Electric billing issue, net of tax of $2, $2 (b) | Other operation and maintenance | | (6) | | | — | | | (6) | | | — | |
| | PA tax rate change (a) | |
| | PA tax rate change (a) | |
| PPL Electric billing issue, net of tax of $4 (b) | |
| | Strategic corporate initiatives, net of tax of $0 (c) | |
| Strategic corporate initiatives, net of tax of $0 (c) | |
| Strategic corporate initiatives, net of tax of $0 (c) | |
| | Total Special Items | |
| | Total Special Items | |
| | PPL Electric billing issue, net of tax of $0, $0 (b) | Other Income (Expense) - net | | (1) | | | — | | | (1) | | | — | |
| Total Special Items | Total Special Items | | $ | (7) | | | $ | — | | | $ | (6) | | | $ | — | |
(a)Impact of Pennsylvania state tax reform. See Note 5 to the Financial Statements for additional information.
(b)Certain costsexpenses 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 thesethe 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 for the three month period primarily due to $156 million of lower PLR, partially offset by an $18 million increase in lowertransmission formula rate returns and an $11 million increase in distribution volumes primarily due to weather and $15higher 2024 usage.
•Lower energy purchases primarily due to $108 million of lower PLR partially offset by $13prices and $33 million of higher distribution prices and $9 million of higher transmission formula rate impacts.lower PLR volumes.
•Higher operating revenues for the six month periodoperation and maintenance expense primarily due to $98an $8 million of higher PLRincrease 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 higher energy prices and higher PLR customers, partially offset by lower customer volumes due to weather, $40 million of higher distribution prices, partially offset by $47 million of lower distribution volumes primarily due to weather and $17 million of transmission formula rate impacts.gross receipts tax.
•Lower energy purchases for the three month periodHigher interest income from affiliate primarily due to lower PLR volumes of $52 million, partially offset by higher PLR prices of $39 million.interest income on a short-term note receivable with an affiliated company.
•Higher energy purchases for the six month period primarily due to higher PLR prices of $161 million, partially offset by lower PLR volumes of $77 million.
•Higher interest expense for the three and six month periods primarily due to increased borrowings.
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 June 30March 31 include the following results.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months | | Six Months |
| 2023 | | 2022 | | $ Change (a) | | 2023 | | 2022 | | $ Change (a) |
| Operating revenues | $ | 377 | | | $ | 128 | | | $ | 249 | | | $ | 942 | | | $ | 128 | | | $ | 814 | |
| | | | | | | | | | | |
| Energy purchases | 108 | | | 38 | | | 70 | | | 394 | | | 38 | | | 356 | |
| Other operation and maintenance | 158 | | | 93 | | | 65 | | | 278 | | | 93 | | | 185 | |
| Depreciation | 40 | | | 15 | | | 25 | | | 79 | | | 15 | | | 64 | |
| Taxes, other than income | 36 | | | 14 | | | 22 | | | 80 | | | 14 | | | 66 | |
| Total operating expenses | 342 | | | 160 | | | 182 | | | 831 | | | 160 | | | 671 | |
| Other Income (Expense) - net | (6) | | | 2 | | | (8) | | | 4 | | | 2 | | | 2 | |
| Interest Expense | 20 | | | 7 | | | 13 | | | 39 | | | 7 | | | 32 | |
| | | | | | | | | | | |
| | | | | | | | | | | |
| Income Taxes | (1) | | | (8) | | | 7 | | | 12 | | | (8) | | | 20 | |
| Net Income | 10 | | | (29) | | | 39 | | | 64 | | | (29) | | | 93 | |
| Less: Special Items | (13) | | | (38) | | | 25 | | | (30) | | | (38) | | | 8 | |
| Earnings from Ongoing Operations | $ | 23 | | | $ | 9 | | | $ | 14 | | | $ | 94 | | | $ | 9 | | | $ | 85 | |
| | | | | | | | | | | |
(a)Primarily due to prior periods only including activity from the acquisition date on May 25, 2022. | | | | | | | | | | | | | | | | | | | | | | | |
| | | 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 June 30.March 31.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Income Statement Line Item | | Three Months | | Six Months | | |
| | 2023 | | 2022 | | 2023 | | 2022 | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Acquisition integration, net of tax of $5, $10, $8, $10 (a) | Other operation and maintenance | | $ | (13) | | | $ | (39) | | | $ | (30) | | | $ | (39) | | | | | |
| Acquisition integration, net of tax of $0, $0 (a) | Other Income and (Expense) - net | | — | | | 1 | | | — | | | 1 | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Total Special Items | | | $ | (13) | | | $ | (38) | | | $ | (30) | | | $ | (38) | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | |
| 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)Includes costs incurred primarily related toPrimarily includes certain TSA costs for IT systems that will not be part of PPL’sPPL's ongoing operations. 2022 also includes costs for certain commitments made during
The changes in the acquisition process.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
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 June 30.March 31.
76 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | 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 ContentsPPL'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 | | | $ | 91 | | | $ | 110 | | | $ | 10 | | | $ | (99) | | | | | $ | 112 | | | |
| Less: Special Items (expense) benefit: | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Talen litigation costs, net of tax of $1 (a) | | | — | | | — | | | — | | | (2) | | | | | (2) | | | |
| Strategic corporate initiatives, net of tax of $1 (b) | | | — | | | — | | | — | | | (3) | | | | | (3) | | | |
| Acquisition integration, net of tax of $3, $15 (c) | | | — | | | — | | | (13) | | | (60) | | | | | (73) | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| PPL Electric billing issue, net of tax of $2 | | | — | | | (7) | | | — | | | — | | | | | (7) | | | |
| FERC transmission credit refund, net of tax of $2 | | | (5) | | | — | | | — | | | — | | | | | (5) | | | |
| Other non-recurring charges, net of tax of $0 (f) | | | — | | | — | | | — | | | (13) | | | | | (13) | | | |
| Total Special Items | | | (5) | | | (7) | | | (13) | | | (78) | | | | | (103) | | | |
| Earnings from Ongoing Operations | | | $ | 96 | | | $ | 117 | | | $ | 23 | | | $ | (21) | | | | | $ | 215 | | | |
| | | | | | | | | | | | | | | |
| | | 2022 Three Months | | |
| | | KY
Regulated (e) | | PA
Regulated | | RI
Regulated | | Corporate
and Other (e) | | | | Total | | |
| Net Income | | | $ | 112 | | | $ | 124 | | | $ | (29) | | | $ | (88) | | | | | $ | 119 | | | |
| Less: Special Items (expense) benefit: | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Talen litigation costs, net of tax of ($2) (a) | | | — | | | — | | | — | | | 9 | | | | | 9 | | | |
| Strategic corporate initiatives, net of tax of $1, $3 (b) | | | (2) | | | — | | | — | | | (11) | | | | | (13) | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Acquisition integration, net of tax of $10, $16 (c) | | | — | | | — | | | (38) | | | (61) | | | | | (99) | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Total Special Items | | | (2) | | | — | | | (38) | | | (63) | | | | | (103) | | | |
| Earnings from Ongoing Operations | | | $ | 114 | | | $ | 124 | | | $ | 9 | | | $ | (25) | | | | | $ | 222 | | | |
| | | | | | | | | | | | | | | |
| | | 2023 Six Months | | |
| | | KY
Regulated | | PA
Regulated | | RI
Regulated | | Corporate
and Other | | | | Total | | |
| Net Income | | | $ | 257 | | | $ | 248 | | | $ | 64 | | | $ | (172) | | | | | $ | 397 | | | |
| Less: Special Items (expense) benefit: | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Talen litigation costs, net of tax of $1 (a) | | | — | | | — | | | — | | | (3) | | | | | (3) | | | |
| Strategic corporate initiatives, net of tax of $0, $1 (b) | | | (1) | | | — | | | — | | | (4) | | | | | (5) | | | |
| Acquisition integration, net of tax of $8, $27 (c) | | | — | | | — | | | (30) | | | (104) | | | | | (134) | | | |
| PA tax rate change | | | — | | | 1 | | | — | | | — | | | | | 1 | | | |
| Sale of Safari Holdings, net of tax of $2 (d) | | | — | | | — | | | — | | | (4) | | | | | (4) | | | |
| PPL Electric billing issue, net of tax of $2 | | | — | | | (7) | | | — | | | — | | | | | (7) | | | |
| FERC transmission credit refund, net of tax of $2 | | | (5) | | | — | | | — | | | — | | | | | (5) | | | |
| Other non-recurring charges, net of tax of $0 (f) | | | — | | | — | | | — | | | (13) | | | | | (13) | | | |
| Total Special Items | | | (6) | | | (6) | | | (30) | | | (128) | | | | | (170) | | | |
| Earnings from Ongoing Operations | | | $ | 263 | | | $ | 254 | | | $ | 94 | | | $ | (44) | | | | | $ | 567 | | | |
| | | | | | | | | | | | | | | |
| | | 2022 Six Months | | |
| | | KY
Regulated (e) | | PA
Regulated | | RI
Regulated | | Corporate
and Other (e) | | | | Total | | |
| Net Income | | | $ | 301 | | | $ | 267 | | | $ | (29) | | | $ | (147) | | | | | $ | 392 | | | |
| Less: Special Items (expense) benefit: | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Talen litigation costs, net of tax of ($1) (a) | | | — | | | — | | | — | | | 5 | | | | | 5 | | | |
| Strategic corporate initiatives, net of tax of $2, $4 (b) | | | (6) | | | — | | | — | | | (15) | | | | | (21) | | | |
| Acquisition integration, net of tax of $10, $22 (c) | | | — | | | — | | | (38) | | | (82) | | | | | (120) | | | |
| Solar panel impairment, net of tax of $0 | | | — | | | — | | | — | | | 1 | | | | | 1 | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Total Special Items | | | (6) | | | — | | | (38) | | | (91) | | | | | (135) | | | |
| Earnings from Ongoing Operations | | | $ | 307 | | | $ | 267 | | | $ | 9 | | | $ | (56) | | | | | $ | 527 | | | |
| | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | 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. See Note 10 to the Financial Statements for additional information.
(b)Costs incurred for 2023 includes corporate centralization and other strategic efforts. Costs incurred for 2022 primarily related to the acquisition of RIE andin 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.
(d)Final closing adjustments related to the sale of Safari Holdings. 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.
(e)The financing activity of LKE is presented in Corporate and Other beginning on January 1, 2023. Prior periods have been adjusted to reflect this change.
(f)Certain expenses related to distributed energy investments.
PPL Electric: Statement of Income Analysis
Statement of Income Analysis
Net income for the periods ended June 30March 31 includes the following results.
| | | |
| | | | Three Months | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change | | | | | | | | 2024 | | 2023 | | $ Change |
| Operating Revenues | Operating Revenues | $ | 667 | | | $ | 676 | | | $ | (9) | | | $ | 1,558 | | | $ | 1,451 | | | $ | 107 | |
| Operating Expenses | Operating Expenses | | | | | | | | | | | |
| Operation | Operation | |
| Operation | |
| Operation | |
| Energy purchases | |
| Energy purchases | |
| Energy purchases | Energy purchases | 204 | | | 218 | | | (14) | | | 562 | | | 474 | | | 88 | |
| | Other operation and maintenance | |
| Other operation and maintenance | |
| Other operation and maintenance | Other operation and maintenance | 141 | | | 128 | | | 13 | | | 303 | | | 288 | | | 15 | |
| Depreciation | Depreciation | 99 | | | 99 | | | — | | | 198 | | | 197 | | | 1 | |
| Taxes, other than income | Taxes, other than income | 30 | | | 32 | | | (2) | | | 74 | | | 69 | | | 5 | |
| Total Operating Expenses | Total Operating Expenses | 474 | | | 477 | | | (3) | | | 1,137 | | | 1,028 | | | 109 | |
| Operating Income | |
| Other Income (Expense) - net | Other Income (Expense) - net | 9 | | | 7 | | | 2 | | | 21 | | | 13 | | | 8 | |
| Interest Income from Affiliate | Interest Income from Affiliate | — | | | 2 | | | (2) | | | — | | | 4 | | | (4) | |
| Interest Expense | Interest Expense | 54 | | | 40 | | | 14 | | | 111 | | | 79 | | | 32 | |
| Income Before Income Taxes | |
| Income Taxes | Income Taxes | 38 | | | 44 | | | (6) | | | 83 | | | 94 | | | (11) | |
| Net Income | Net Income | $ | 110 | | | $ | 124 | | | $ | (14) | | | $ | 248 | | | $ | 267 | | | $ | (19) | |
Operating Revenues
The increase (decrease) in operating revenues was due to:
| | | | | | | | | | | |
| Three Months | | Six Months |
| Distribution price (a) | $ | 13 | | | $ | 40 | |
| Distribution volume (b) | (18) | | | (47) | |
| PLR (c) | (15) | | | 98 | |
| Transmission formula rate (d) | 9 | | | 17 | |
| | | |
| | | |
| Other | 2 | | | (1) | |
| Total | $ | (9) | | | $ | 107 | |
| | | | | | | |
| | | Three Months |
| Distribution price (a) | | | $ | 3 | |
| Distribution volume (b) | | | 11 | |
| PLR (c) | | | (156) | |
| Transmission formula rate (d) | | | 18 | |
| | | |
| | | |
| Other | | | 3 | |
| Total | | | $ | (121) | |
(a)The increases wereincrease was primarily due to reconcilable cost recovery mechanisms approved by the PAPUC.
(b)The decreases wereincrease was primarily due to lower volumes due to weather and other higher usage in 2023.2024.
(c)The increase for the six month perioddecrease was primarily the result of higherfewer PLR customers, and lower energy prices, and more PLR customers, partially offset by lowerhigher customer volumes due to weather.weather and other higher usage.
(d)The increases wereincrease 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 and returns on additional transmission capital investments, partially offset by a lower PPL zonal peak load billing factor in 2023.variance.
Energy Purchases
Energy purchases decreased $14$144 million for the three months ended June 30, 2023March 31, 2024 compared with 2022. This decrease was2023, primarily due to lower PLR volumes of $52 million, partially offset by higher PLR prices of $39 million.
Energy purchases increased $88$108 million for the six months ended June 30, 2023 compared with 2022. This increase was primarily due to higher PLR prices of $161 million, partially offset byand lower PLR volumes of $77$33 million.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| | | | | | | | | | | |
| Three Months | | Six Months |
| | | |
| Support costs | $ | (5) | | | $ | (8) | |
| | | |
| IT cloud amortization costs | 7 | | | 13 | |
| Vegetation management costs | (3) | | | (4) | |
| Storm costs | — | | | (3) | |
| Operation costs | 8 | | | 8 | |
| | | |
| Bad debts | 7 | | | 11 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Other | (1) | | | (2) | |
| Total | $ | 13 | | | $ | 15 | |
| | | | | | | |
| | | Three Months |
| | | |
| | | |
| | | |
| | | |
| Vegetation management expense | | | $ | 5 | |
| Storm costs | | | 8 | |
| Operations costs | | | (10) | |
| | | |
| Bad debts | | | 18 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Other | | | (2) | |
| Total | | | $ | 19 | |
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 ExpenseIncome from Affiliate
Interest expenseincome from affiliate increased $14 million and $32$10 million for the three and six months ended June 30, 2023March 31, 2024 compared with the corresponding periods in 2022,2023, primarily due to increased borrowings.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 June 30March 31 includes the following results.
| | | |
| | | | Three Months | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change | | | | | | | | 2024 | | 2023 | | $ Change |
| Operating Revenues | Operating Revenues | | | | | | | | | | | |
| Retail and wholesale | Retail and wholesale | $ | 347 | | | $ | 399 | | | $ | (52) | | | $ | 808 | | | $ | 880 | | | $ | (72) | |
| Retail and wholesale | |
| Retail and wholesale | |
| Electric revenue from affiliate | Electric revenue from affiliate | 8 | | | 11 | | | (3) | | | 21 | | | 23 | | | (2) | |
| Total Operating Revenues | Total Operating Revenues | 355 | | | 410 | | | (55) | | | 829 | | | 903 | | | (74) | |
| Operating Expenses | Operating Expenses | | | | | | | | | | | |
| Operation | Operation | |
| Operation | |
| Operation | |
| Fuel | |
| Fuel | |
| Fuel | Fuel | 68 | | | 90 | | | (22) | | | 147 | | | 171 | | | (24) | |
| Energy purchases | Energy purchases | 22 | | | 43 | | | (21) | | | 106 | | | 134 | | | (28) | |
| Energy purchases from affiliate | Energy purchases from affiliate | 2 | | | 7 | | | (5) | | | 3 | | | 9 | | | (6) | |
| Other operation and maintenance | Other operation and maintenance | 93 | | | 103 | | | (10) | | | 184 | | | 203 | | | (19) | |
| Depreciation | Depreciation | 76 | | | 75 | | | 1 | | | 151 | | | 149 | | | 2 | |
| Taxes, other than income | Taxes, other than income | 12 | | | 12 | | | — | | | 24 | | | 24 | | | — | |
| Total Operating Expenses | Total Operating Expenses | 273 | | | 330 | | | (57) | | | 615 | | | 690 | | | (75) | |
| Operating Income | |
| Other Income (Expense) - net | Other Income (Expense) - net | — | | | 4 | | | (4) | | | 2 | | | 3 | | | (1) | |
| | Interest Expense | Interest Expense | 26 | | | 21 | | | 5 | | | 51 | | | 41 | | | 10 | |
| Interest Expense | |
| Interest Expense | |
| Income Before Income Taxes | |
| Income Taxes | Income Taxes | 11 | | | 9 | | | 2 | | | 34 | | | 28 | | | 6 | |
| Net Income | Net Income | $ | 45 | | | $ | 54 | | | $ | (9) | | | $ | 131 | | | $ | 147 | | | $ | (16) | |
Operating Revenues
The increase (decrease) in operating revenues was due to:
| | | | | | | | | | | |
| Three Months | | Six Months |
| Fuel and other energy prices (a) | $ | (33) | | | $ | (21) | |
| | | |
| | | |
| Volumes (b) | (30) | | | (74) | |
| Economic relief billing credit, net of amortization of $0 | 6 | | | 12 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Other | 2 | | | 9 | |
| Total | $ | (55) | | | $ | (74) | |
| | | | | | | | |
| | | Three Months | |
| | | | |
| | | | |
| | | | |
| Fuel and other energy purchases (a) | | | $ | (6) | | |
| | | | |
| | | | |
| | | | |
| Volumes (b) | | | 12 | | |
| | | | |
| | | | |
| Other | | | (4) | | |
| Total | | | $ | 2 | | |
(a)The decreases weredecrease was primarily due to lower recoveries of fuel and energy purchases, due to lower commodity costs.partially offset by higher recoveries of fuel expense.
(b)The decreases wereincrease 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.
Fuel
Fuel decreased $22 million for the three months ended June 30, 2023 compared with 2022, due to a $13 million decrease in commodity costs and a $9 million decrease in volumes primarily due to weather.
Fuel decreased $24 million for the six months ended June 30, 2023 compared with 2022, due to a $14 million decrease in volumes primarily due to weather and an $11 million decrease in commodity costs.
Energy Purchases
Energy purchases decreased $21$13 million for the three months ended June 30, 2023March 31, 2024 compared with 2022,2023, primarily due to a decrease in commodity costs.
Energy purchases decreased $28 million for the six months ended June 30, 2023 compared with 2022, due to a $20 million decrease in volumes primarily due to weather and an $8 million decrease in commodity costs.
Energy Purchases from Affiliate
Energy purchases from affiliate decreased $5 million for the three months ended June 30, 2023 compared with 2022, primarily due to a $3$21 million decrease in commodity costs, andpartially offset by a $2$7 million decreaseincrease in volumes.volumes due to weather.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| | | | | | | | | | | | |
| Three Months | | Six Months | |
| Plant operations and maintenance expense | $ | (9) | | | $ | (12) | | |
| Transmission credits | 3 | | | 3 | | |
| Generation outage expenses | (1) | | | (2) | | |
| Vegetation management expenses | (2) | | | (4) | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Other | (1) | | | (4) | | |
| Total | $ | (10) | | | $ | (19) | | |
Interest Expense
Interest expense increased $5 million and $10 million for the three and six months ended June 30, 2023 compared with the corresponding periods in 2022, primarily due to increased borrowings.
KU: Statement of Income Analysis
Statement of Income Analysis
Net income for the periods ended June 30March 31 includes the following results.
| | | |
| | | | Three Months | | Six Months | | | Three Months |
| | | 2023 | | 2022 | | $ Change | | 2023 | | 2022 | | $ Change | | | | | | | | 2024 | | 2023 | | $ Change |
| Operating Revenues | Operating Revenues | | | | | | | | | | | |
| Retail and wholesale | Retail and wholesale | $ | 433 | | | $ | 484 | | | $ | (51) | | | $ | 931 | | | $ | 1,007 | | | $ | (76) | |
| Retail and wholesale | |
| Retail and wholesale | |
| Electric revenue from affiliate | Electric revenue from affiliate | 2 | | | 7 | | | (5) | | | 3 | | | 9 | | | (6) | |
| Total Operating Revenues | Total Operating Revenues | 435 | | | 491 | | | (56) | | | 934 | | | 1,016 | | | (82) | |
| Operating Expenses | Operating Expenses | | | | | | | | | | | |
| Operation | Operation | |
| Operation | |
| Operation | |
| Fuel | |
| Fuel | |
| Fuel | Fuel | 99 | | | 139 | | | (40) | | | 221 | | | 270 | | | (49) | |
| Energy purchases | Energy purchases | 6 | | | 7 | | | (1) | | | 12 | | | 12 | | | — | |
| Energy purchases from affiliate | Energy purchases from affiliate | 8 | | | 11 | | | (3) | | | 21 | | | 23 | | | (2) | |
| Other operation and maintenance | Other operation and maintenance | 117 | | | 120 | | | (3) | | | 226 | | | 233 | | | (7) | |
| Depreciation | Depreciation | 98 | | | 98 | | | — | | | 196 | | | 193 | | | 3 | |
| Taxes, other than income | Taxes, other than income | 12 | | | 11 | | | 1 | | | 22 | | | 22 | | | — | |
| Total Operating Expenses | Total Operating Expenses | 340 | | | 386 | | | (46) | | | 698 | | | 753 | | | (55) | |
| Operating Income | |
| Other Income (Expense) - net | Other Income (Expense) - net | 3 | | | 4 | | | (1) | | | 5 | | | 4 | | | 1 | |
| Interest Expense | Interest Expense | 33 | | | 28 | | | 5 | | | 66 | | | 55 | | | 11 | |
| Interest Expense with Affiliate | 1 | | | — | | | 1 | | | 1 | | | — | | | 1 | |
| | Income Before Income Taxes | |
| Income Before Income Taxes | |
| Income Before Income Taxes | |
| Income Taxes | Income Taxes | 13 | | | 15 | | | (2) | | | 35 | | | 39 | | | (4) | |
| Net Income | Net Income | $ | 51 | | | $ | 66 | | | $ | (15) | | | $ | 139 | | | $ | 173 | | | $ | (34) | |
Operating Revenues
The increase (decrease) in operating revenues was due to:
| | | | | | | | | | | | |
| Three Months | | Six Months | |
| | | | |
| | | | |
| | | | |
| Fuel and other energy prices (a) | $ | (27) | | | $ | (18) | | |
| | | | |
| | | | |
| Economic relief billing credit, net of amortization of $0 | 3 | | | 5 | | |
| Volumes (b) | (36) | | | (81) | | |
| | | | |
| | | | |
| Other | 4 | | | 12 | | |
| Total | $ | (56) | | | $ | (82) | | |
| | | | | | | | |
| | | Three Months | |
| | | | |
| | | | |
| | | | |
| Fuel and other energy purchases (a) | | | $ | 4 | | |
| | | | |
| | | | |
| | | | |
| Volumes (b) | | | 20 | | |
| | | | |
| | | | |
| Other | | | 2 | | |
| Total | | | $ | 26 | | |
(a)The decreases wereincrease was primarily due to lowerhigher recoveries of fuel and energy purchases due to lowerhigher commodity costs.costs and volumes.
(b)The decreases wereincrease was primarily due to weather.
Fuel
Fuel decreased $40 million for the three months ended June 30, 2023 compared with 2022, due to a $27 million decrease in commodity costs and a $14 million decrease in volumes primarily due to weather.
Fuel decreased $49 million for the six months ended June 30, 2023 compared with 2022, due to a $29 million decrease in volumes primarily due to weather and a $20 million decrease in commodity costs.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to: | | | | | | | | | | | | |
| Three Months | | Six Months | |
| | | | |
| Transmission credits | $ | 7 | | | $ | 7 | | |
| Generation outage expenses | (4) | | | (6) | | |
| Vegetation management expenses | (2) | | | (5) | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Other | (4) | | | (3) | | |
| Total | $ | (3) | | | $ | (7) | | |
| | | | | | | | |
| | | Three Months | |
| Plant operations and maintenance | | | $ | (3) | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Other | | | (4) | | |
| Total | | | $ | (7) | | |
Interest Expense
Interest expense increased $5 million and $11 million for the three and six months ended June 30, 2023 compared with the corresponding periods in 2022, primarily due to increased borrowings.
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, for all Registrants.applicable.
Liquidity and Capital Resources
(All Registrants)
The Registrants had the following at:
| | | | PPL | | PPL Electric | | LG&E | | KU | | PPL | | PPL Electric | | LG&E | | KU |
| June 30, 2023 | | | | | | | |
| March 31, 2024 | | March 31, 2024 | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 326 | | | $ | 26 | | | $ | 7 | | | $ | 9 | |
| | Short-term debt | |
| Short-term debt | |
| Short-term debt | Short-term debt | 243 | | | 130 | | | 21 | | | 92 | |
| Long-term debt due within one year | Long-term debt due within one year | 91 | | | 90 | | | — | | | — | |
| Notes payable to affiliates | Notes payable to affiliates | | — | | | — | | | 8 | |
| | December 31, 2022 | | | | | | | |
| December 31, 2023 | |
| December 31, 2023 | |
| December 31, 2023 | | | | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 356 | | | $ | 25 | | | $ | 93 | | | $ | 21 | |
| Short-term debt | Short-term debt | 985 | | | 145 | | | 179 | | | 101 | |
| Long-term debt due within one year | Long-term debt due within one year | 354 | | | 340 | | | — | | | 13 | |
| Notes payable to affiliates | 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 sixthree month periods ended June 30,March 31, and the changes between periods, were as follows.
| | | | PPL | | PPL Electric | | LG&E | | KU | | PPL | | PPL Electric | | LG&E | | KU |
| 2023 | | | | | | | |
| 2024 | | 2024 | | | |
| Operating activities | Operating activities | $ | 842 | | | $ | 236 | | | $ | 358 | | | $ | 298 | |
| Investing activities | Investing activities | (1,096) | | | (398) | | | (194) | | | (299) | |
| Financing activities | Financing activities | 224 | | | 163 | | | (250) | | | (11) | |
| 2022 | | | | | | | |
| 2023 | | 2023 | | | |
| Operating activities | Operating activities | $ | 979 | | | $ | 355 | | | $ | 317 | | | $ | 332 | |
| Investing activities | Investing activities | (4,683) | | | (117) | | | (183) | | | (273) | |
| Financing activities | Financing activities | 469 | | | (230) | | | (125) | | | (55) | |
| Change - Cash Provided (Used) | Change - Cash Provided (Used) | | | | | | | | Change - Cash Provided (Used) | | | |
| Operating activities | Operating activities | $ | (137) | | | $ | (119) | | | $ | 41 | | | $ | (34) | |
| Investing activities | Investing activities | 3,587 | | | (281) | | | (11) | | | (26) | |
| Financing activities | Financing activities | (245) | | | 393 | | | (125) | | | 44 | |
Operating Activities
The components of the change in cash provided by (used in) operating activities for the sixthree months ended June 30, 2023March 31, 2024 compared with 20222023 were as follows.
| | | | | | | | | | | | | | | | | | | | | | | |
| PPL | | PPL Electric | | LG&E | | KU |
| Change - Cash Provided (Used) | | | | | | | |
| Net income | $ | 5 | | | $ | (19) | | | $ | (16) | | | $ | (34) | |
| Non-cash components | 93 | | | (10) | | | 12 | | | 8 | |
| Working capital | (132) | | | (92) | | | 49 | | | 11 | |
| Defined benefit plan funding | — | | | (1) | | | 2 | | | 1 | |
| Other operating activities | (103) | | | 3 | | | (6) | | | (20) | |
| Total | $ | (137) | | | $ | (119) | | | $ | 41 | | | $ | (34) | |
| | | | | | | | | | | | | | | | | | | | | | | |
| 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 20232024 decreased $137$148 million compared with 2022.2023.
•Net income increased $5$22 million between the periods and included an increase in non-cash charges of $93$3 million. The increase in non-cash charges was primarily due to an increase in depreciation (primarily due to the acquisition of RIE) and an increase in deferred income taxes and investment tax credits (primarily due to the acquisition of RIE), partially offset by an increase in defined benefit plans income (primarily due to a higher expected return).
•The $132$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), a decrease in counterparty collateral (due to collateral requirements for energy pricing in the previous year) and an increase in fuel, materials and supplies (primarily due to weather), partially offset by an increase in regulatory liabilities (primarily due to prior years' refunds to customers related to the transmission formula rate return on equity reduction) and a decrease in unbilled revenues and accounts receivable (primarily due to weather).
•The $103$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 regulatory liabilitiesother assets (primarily duerelated to the acquisition of RIE)a decrease in costs associated with work optimization and management projects).
(PPL Electric) (LG&E)
PPL Electric'sLG&E's cash provided by operating activities in 20232024 decreased $119$98 million compared with 2022.2023.
•Net income decreased $19increased $7 million between the periods and included a decreasean increase in non-cash components of $10$4 million. The decrease in non-cash components was primarily due to a decrease in deferred income taxes and investment tax credits (primarily related to a change in state tax rates) and an increase in defined benefit plan income (primarily due to a higher expected return), partially offset by an increase in amortization expense (primarily due an increase in IT projects placed into service).
•The $92$117 million decrease in cash from changes in working capital was primarily due to an increase in accounts receivable, (primarily due to pricing), a decrease in accounts payable (primarily due to timing of payments), a decrease in counterparty collateral (due to collateral requirements for energy pricing in the previous year)unbilled revenues and an increase regulatory assets (primarily due to a decrease in rate recoveries driven by increased energy prices), partially offset by a decrease in unbilled revenuefuel, materials and supplies (primarily due to weather), and an increase in regulatory liabilities (primarily due to prior years' refunds to customers related to the transmission formula rate return on equity reduction).
•The $3 million increase in cash provided by other operating activities was driven primarily by other assets (primarily related to an increase in costs associated with work optimization and management projects).
(LG&E)
LG&E's cash provided by operating activities in 2023 increased $41 million compared with 2022.
•Net income decreased $16 million between the periods and included an increase in non-cash components of $12 million. The increase in non-cash components was primarily due to an increase in amortization expense (primarily due to the expiration of the economic relief billing credit in June 2022).
•The $49 million increase in cash from changes in working capital was primarily due to a decrease in accounts receivable and unbilled revenues (primarily due to weather), a decrease in accounts receivable from affiliates (primarily due to timing of payments) and a decrease in net regulatory assets (primarily due to the timing of rate recovery mechanisms), partially offset by a decreasean increase in accounts payable taxes payable and other current liabilities (primarily due to timing of payments).
•The $6$9 million decreaseincrease 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)assets in the prior year).
(KU)
KU's cash provided by operating activities in 2023 decreased $342024 increased $38 million compared with 2022.2023.
•Net income decreased $34increased $20 million between the periods and included an increase in non-cashperiods. Non-cash components of $8 million. The increase in non-cash components was primarily due to an increase in amortization expense (primarily due to the expiration of the economic relief billing credit in June 2022).were consistent between periods.
•The $11$3 million increasedecrease in cash from changes in working capital was primarily due to a decreasean increase in accounts receivable and unbilled revenues (primarily due to weather) and a decrease, an increase in net regulatory assets (primarily due to the
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) and a decrease in accounts payable, accounts payable to affiliates and taxes payable (primarily due to timing of payments).
•The $20$22 million decreaseincrease 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)assets in the prior year).
Investing Activities
(All Registrants)
The components of the change in cash provided by (used in) investing activities for the sixthree months ended June 30, 2023March 31, 2024 compared with 20222023 were as follows.
| | PPL | | PPL Electric | | LG&E | | KU |
| PPL | | | PPL | | PPL Electric | | LG&E | | KU |
| Change - Cash Provided (Used) | Change - Cash Provided (Used) | | | | | | | |
| Expenditures for PP&E | |
| Expenditures for PP&E | |
| Expenditures for PP&E | Expenditures for PP&E | $ | (81) | | | $ | 56 | | | $ | (3) | | | $ | (26) | |
| | Acquisition of Narragansett Electric, net of cash acquired | 3,674 | | | — | | | — | | | — | |
| | Notes receivable from affiliate | |
| | Notes receivable from affiliate | |
| | | Notes receivable from affiliate | Notes receivable from affiliate | — | | | (333) | | | (8) | | | — | |
| Other investing activities | Other investing activities | (6) | | | (4) | | | — | | | — | |
| Total | Total | $ | 3,587 | | | $ | (281) | | | $ | (11) | | | $ | (26) | |
For PPL, the increase in expenditures for PP&E was due to project expenditures at RIE and an increase in project expenditures at PPL Electric, RIE, LG&E and KU, offset by lower project expenditures at PPL Electric.KU. The decreaseincrease in expenditures at PPL Electric was primarily due to a reduction in transmission capital spending projects. Thean increase in expenditures at KU was primarily due to higher spending on various projects that are not individually significant. distribution projects.
For PPL Electric, the change in "Notes receivable from affiliate" activity resulted from payments received on a short-term note between affiliates in 2022, issuedthe funding of $554 million to support general corporate purposes. For LG&E, the change in "Notes receivable from affiliate" activity resulted from funds issued on a short-term note between affiliates in 2023 to support general corporate purposes.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 sixthree months ended June 30, 2023March 31, 2024 compared with 20222023 were as follows.
| | PPL | | PPL Electric | | LG&E | | KU |
| PPL | | | PPL | | PPL Electric | | LG&E | | KU |
| Change - Cash Provided (Used) | Change - Cash Provided (Used) | | | | | | | | Change - Cash Provided (Used) | | | |
| Debt issuance/retirement, net | Debt issuance/retirement, net | $ | 1,364 | | | $ | 179 | | | $ | 99 | | | $ | 86 | |
| | Dividends | Dividends | 105 | | | 2 | | | 49 | | | 67 | |
| | | Dividends | |
| | Dividends | |
| | Capital contributions/distributions, net | |
| Capital contributions/distributions, net | |
| Capital contributions/distributions, net | Capital contributions/distributions, net | — | | | 240 | | | (110) | | | (60) | |
| | Change in short-term debt, net | Change in short-term debt, net | (1,661) | | | (15) | | | (483) | | | (347) | |
| | Change in short-term debt, net | |
| | Change in short-term debt, net | |
| | Net increase (decrease) in notes payable with affiliate | |
| Net increase (decrease) in notes payable with affiliate | |
| Net increase (decrease) in notes payable with affiliate | Net increase (decrease) in notes payable with affiliate | — | | | — | | | 324 | | | 302 | |
| Other financing activities | Other financing activities | (53) | | | (13) | | | (4) | | | (4) | |
| Total | Total | $ | (245) | | | $ | 393 | | | $ | (125) | | | $ | 44 | |
See Note 7 to the Financial Statements in this Form 10-Q for information on 20232024 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 8 to the Financial Statements in the Registrants' 20222023 Form 10-K for information on 20222023 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 June 30, 2023,March 31, 2024, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:
External
| | Committed
Capacity | | Borrowed | | Letters of
Credit
and
Commercial
Paper Issued | | Unused
Capacity |
| Committed
Capacity | | | Committed
Capacity | | Borrowed | | Letters of
Credit
and
Commercial
Paper Issued | | Unused
Capacity |
| PPL Capital Funding Credit Facilities (a) | PPL Capital Funding Credit Facilities (a) | $ | 1,350 | | | $ | — | | | $ | — | | | $ | 1,350 | |
| PPL Electric Credit Facility | PPL Electric Credit Facility | 650 | | | — | | | 131 | | | 519 | |
| | LG&E Credit Facilities | LG&E Credit Facilities | 500 | | | — | | | 21 | | | 479 | |
| | LG&E Credit Facilities | |
| | LG&E Credit Facilities | |
| KU Credit Facilities | KU Credit Facilities | 400 | | | — | | | 92 | | | 308 | |
| Total Credit Facilities (b) | Total Credit Facilities (b) | $ | 2,900 | | | $ | — | | | $ | 244 | | | $ | 2,656 | |
|
(a)Includes a $1.25 billion syndicated credit facility with a $250$400 million borrowing sublimit for RIE and a $1 billion$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 |
| Committed
Capacity | | Borrowed | | Commercial Paper Issued | | Unused
Capacity |
| | LG&E Money Pool (a) | LG&E Money Pool (a) | $ | 750 | | | $ | — | | | $ | 21 | | | $ | 729 | |
| LG&E Money Pool (a) | |
| LG&E Money Pool (a) | |
| KU Money Pool (a) | KU Money Pool (a) | 650 | | | 8 | | | 92 | | | 550 | |
(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 June 30, 2023:March 31, 2024:
| | Capacity | | Commercial
Paper
Issuances | | Unused
Capacity |
| Capacity | | | Capacity | | Commercial
Paper
Issuances | | Unused
Capacity |
| PPL Capital Funding (a) | PPL Capital Funding (a) | $ | 1,350 | | | $ | — | | | $ | 1,350 | |
| Rhode Island Energy (a) | Rhode Island Energy (a) | 400 | | | — | | | 400 | |
| PPL Electric | PPL Electric | 650 | | | 130 | | | 520 | |
| | LG&E | LG&E | 500 | | | 21 | | | 479 | |
| LG&E | |
| LG&E | |
| KU | KU | 400 | | | 92 | | | 308 | |
| Total PPL | Total PPL | $ | 3,300 | | | $ | 243 | | | $ | 3,057 | |
(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 $250$400 million borrowing sublimit for RIE and a $1 billion$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.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.
Forecasted Uses of Cash (PPL)
Common Stock Dividends
In May 2023,February 2024, PPL declared a quarterly common stock dividend, payable July 3, 2023,April 1, 2024, of 24.025.75 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.
TheSince June 2023, the rating agencies have taken the followingno ratings actions related to the Registrants and their subsidiaries.
(PPL)
In June 2023, Moody’s assigned RIE's commercial paper a Short-Term Rating of P-2.
In June 2023, S&P assigned RIE's commercial paper a Short-Term Rating of A-2.
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 June 30, 2023.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' 20222023 Form 10-K.
Risk Management (All Registrants)
Market Risk
See Notes 13 and 14 to the Financial Statements for information about the Registrants' risk management objectives, valuation techniques and accounting designations.
The forward-looking information presented below provides estimates of what may occur in the future, assuming certain adverse market conditions and model assumptions. Actual future results may differ materially from those presented. These are not precise indicators of expected future losses, but are rather only indicators of possible losses under normal market conditions at a given confidence level.
Interest Rate Risk
PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.
The following interest rate hedges were outstanding at June 30, 2023.March 31, 2024.
| | Exposure
Hedged | | Fair Value,
Net - Asset
(Liability) (a) | | Effect of a
10% Adverse
Movement
in Rates (b) | | Maturities
Ranging
Through |
| Exposure
Hedged | | | Exposure
Hedged | | Fair Value,
Net - Asset
(Liability) (a) | | Effect of a
10% Adverse
Movement
in Rates (b) | | Maturities
Ranging
Through |
| PPL and LG&E | PPL and LG&E | | | | | | | | PPL and LG&E | | | | | |
| Economic hedges | Economic hedges | | | | | | | | Economic hedges | | | | | |
| Interest rate swaps (c) | Interest rate swaps (c) | $ | 64 | | | $ | (7) | | | $ | (1) | | | 2033 | Interest rate swaps (c) | $ | 64 | | | $ | | $ | (5) | | | $ | | $ | (1) | | | 2033 | | 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 June 30, 2023March 31, 2024 is shown below.
| | | | | | |
| | 10% Adverse
Movement
in Rates on Fair Value of Debt | |
| PPL | $ | 612630 | | |
| PPL Electric | 255271 | | |
| LG&E | 9894 | | |
| KU | 140135 | | |
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.
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' 20222023 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' 20222023 Form 10-K for additional informationinformation.
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 the share purchase agreement to acquire Narragansett Electric.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' 20222023 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' 20222023 Form 10-K for information on projected environmental capital expenditures for 20232024 through 2025.2026. 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.
The information below represents an update to “Item 1. Business – Environmental Matters” in the Registrants' 20222023 Form 10-K.
(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 arewere 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.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. InOn April 2023,25, 2024, the EPA proposed to increasereleased a pre-publication version of a final rule increasing the stringency of MATS and further reducereducing emissions of certain hazardous air pollutants by reducing certain particulate matter standards by approximately two-thirds to reflect perceived developments in control technologies. While the exact impact will depend on the provisions adopted in the final rule, PPL, LG&E, and KU are reviewing the final rule to determine its impact and do not expect significant operational changes or additional controls. PPL, LG&E, and KU will continuecontrols to monitor the ongoing rulemaking process.be required.
Proposed Greenhouse Gas Standards
On May 11, 2023,April 25, 2024, the EPA released proposed rulesa pre-publication version of a final rule under Section 111 of the Clean Air Act to establishwhich 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 proposed standards would require phased implementation of carbon mitigation technologies including state-of-the-art efficiency requirements, carbon capture and sequestration, low GHG hydrogen co-firing, and natural gas co-firing. New natural gas EGUs would be immediately subject to the stricter efficiency standard. The EPA’s proposed new GHG reduction requirements, if adopted, could potentially require significant additional compliance measures including changes in current operations, installation of capital equipment, and early retirement of certain coal-fired generating units. PPL, LG&E, and KU are unable to predict the precise impact of new GHG reduction requirements until issuancecompletion of final rulesa 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.
Waters of the U.S.
On May 25, 2023, the U.S. Supreme Court issued an opinion in Sackett v. EPA holding that the government’s jurisdiction to regulate wetlands under the Clean Water Act extends to wetlands with a continuous surface connection to bodies that are waters of the U.S. By limiting water bodies that fall within the jurisdiction of the Clean Water Act, the decision could reduce the number of projects or the scope of project activities subject to federal permitting for wetlands.
New Accounting Guidance (All Registrants)
There has been no new accounting guidance adopted in 2023 and there is no new2024. See Note 17 to the Financial Statements for discussion of significant accounting guidance pending adoption as of June 30, 2023.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' 20222023 Form 10-K for a discussion of each critical accounting policy.
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| | | | | 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 | | X |
Following is an update to the critical accounting policies disclosed in PPL's 2022 Form 10-K.
Revenue Recognition - Unbilled Revenues (PPL and PPL Electric)
For PPL Electric, unbilled revenues for a month are typically calculated by multiplying the actual unbilled volumes by the price per tariff. In the first quarter of 2023, PPL Electric estimated deliveries to customers due to a temporary issue. In the second quarter of 2023, the temporary issue was resolved and unbilled volumes resumed being calculated by multiplying the actual unbilled volumes by the price per tariff.
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 June 30, 2023,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' secondfirst 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 secondfirst quarter of 20232024 see:
•"Item 3. Legal Proceedings" in each Registrant's 20222023 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' 20222023 Form 10-K.
Item 4. Mine Safety Disclosures
Not applicable.
Item 5. Other Information
Securities Trading Plans of Directors and Executive Officers
During the three months ended June 30, 2023,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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| - | | | | | | | 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) |
| - | 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) |
| - | 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. |
| - | 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. |
| - | 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. |
| - | 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. |
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Certifications pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended June 30, 2023,March 31, 2024, filed by the following officers for the following companies: |
| | | |
| - | PPL Corporation's principal executive officer |
| - | PPL Corporation's principal financial officer |
| - | PPL Electric Utilities Corporation's principal executive officer |
| - | PPL Electric Utilities Corporation's principal financial officer |
| - | Louisville Gas and Electric Company's principal executive officer |
| - | Louisville Gas and Electric Company's principal financial officer |
| - | Kentucky Utilities Company's principal executive officer |
| - | Kentucky Utilities Company's principal financial officer |
| |
Certifications pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended June 30, 2023,March 31, 2024, furnished by the following officers for the following companies: |
| | | |
| - | PPL Corporation's principal executive officer and principal financial officer |
| - | PPL Electric Utilities Corporation's principal executive officer and principal financial officer |
| - | Louisville Gas and Electric Company's principal executive officer and principal financial officer |
| - | Kentucky Utilities Company's principal executive officer and principal financial officer |
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| 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. |
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.
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| | PPL Corporation |
| | (Registrant) | |
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| Date: | August 4, 2023May 1, 2024 | /s/ Marlene C. Beers | |
| | Marlene C. Beers
Vice President and Controller | |
| | (Principal Accounting Officer) | |
| | | |
| | | |
| | | |
| | PPL Electric Utilities Corporation |
| | (Registrant) | |
| | | |
| | | |
| | | |
| Date: | August 4, 2023May 1, 2024 | /s/ Marlene C. Beers | |
| | Marlene C. Beers
Vice President and Controller | |
| | (Principal Accounting and Financial Officer) | |
| | | |
| | | |
| | | |
| | Louisville Gas and Electric Company |
| | (Registrant) | |
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| | Kentucky Utilities Company |
| | (Registrant) | |
| | | |
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| Date: | August 4, 2023May 1, 2024 | /s/ Christopher M. Garrett | |
| | Christopher M. Garrett
Vice President-Finance and Accounting | |
| | (Principal Accounting and Financial Officer) | |