PPL CORPORATION
PPL ELECTRIC UTILITIES CORPORATION
LOUISVILLE GAS AND ELECTRIC COMPANY
KENTUCKY UTILITIES COMPANY
FORM 10-K ANNUAL REPORT TO
THE SECURITIES AND EXCHANGE COMMISSION
FOR THE YEAR ENDED DECEMBER 31, 20172021
TABLE OF CONTENTS
This combined Form 10-K is separately filed by the following Registrants in their individual capacity: PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, 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 and information relating to the subsidiaries of LG&E and KU Energy LLC is also attributed to LG&E and KU Energy LLC.Corporation.
Unless otherwise specified, references in this Report, individually, to PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, 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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| 3. | |||||||||||
| 4. | |||||||||||
| PART II | |||||||||||
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| 6. | |||||||||||
| 7. | |||||||||||
| Item | Page | ||
| PART I | |||
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| 1B. | |||
| 2. | |||
| 3. | |||
| 4. | |||
| PART II | |||
| 5. | |||
| 6. | |||
| 7. | |||
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| 7A. | |||||||||||
| 8. | Financial Statements and Supplementary Data | ||||||||||
| FINANCIAL STATEMENTS | |||||||||||
| PPL Corporation and Subsidiaries | |||||||||||
| PPL Electric Utilities Corporation and Subsidiaries | |||||||||||
| Louisville Gas and Electric Company | |||||||||||
| Kentucky Utilities Company | |||||||||||
| Item | Page | ||||||||||
| COMBINED NOTES TO FINANCIAL STATEMENTS | |||||||||||
| 9. | |||||||||||
| 9A. | |||||||||||
| 9B. | |||||||||||
| 9C. | |||||||||||
| PART III | |||||||||||
| 10. | |||||||||||
| 11. | |||||||||||
| 12. | |||||||||||
| 13. | |||||||||||
| 14. | |||||||||||
| PART IV | |||||||||||
| 15. | |||||||||||
| Item | Page | ||
| COMBINED NOTES TO FINANCIAL STATEMENTS | |||
| SUPPLEMENTARY DATA | |||
| Schedule I - Condensed Unconsolidated Financial Statements | |||
| 9. | |||
| 9A. | |||
| 9B. | |||
| PART III | |||
| 10. | |||
| 11. | |||
| 12. | |||
| 13. | |||
| 14. | |||
| PART IV | |||
| 15. | |||
GLOSSARY OF TERMS AND ABBREVIATIONS
PPL Corporation and its 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.
PPL - PPL Corporation, the ultimate parent holding company of PPL Electric, PPL Energy Funding, PPL Capital Funding, LKE and other subsidiaries.
PPL Capital Funding - PPL Capital Funding, Inc., a financing subsidiary of PPL that provides financing for the operations of PPL and certain subsidiaries. Debt issued by PPL Capital Funding is fully and unconditionally guaranteed as to payment by PPL.
PPL Electric - PPL Electric Utilities Corporation, a public utility subsidiary of PPL engaged in the regulated transmission and distribution of electricity in its Pennsylvania service area and that provides electricity supply to its retail customers in this area as a PLR.
PPL Energy Funding - PPL Energy Funding Corporation, a subsidiary of PPL and the parent holding company of PPL Global and other subsidiaries.
PPL Energy Holdings- PPL Energy Holdings, LLC, a subsidiary of PPL and the parent holding company of PPL Energy Funding, LKE and other subsidiaries. As of January 1, 2022, PPL Energy Holdings became the parent holding company of PPL Electric and PPL Services.
PPL EU Services - PPL EU Services Corporation, a subsidiary of PPL that providesprovided administrative, management and support services primarily to PPL Electric. On December 31, 2021, PPL EU Services merged into PPL Services.
PPL Global - PPL Global, LLC, a subsidiary of PPL Energy Funding that, prior to the sale of the U.K. utility business on June 14, 2021, primarily through its subsidiaries, ownsowned and operatesoperated WPD, PPL's regulated electricity distribution businesses in the U.K. PPL Global was not included in the sale of the U.K. utility business on June 14, 2021.
PPL Rhode Island Holdings - PPL Rhode Island Holdings, LLC, a subsidiary of PPL Energy Holdings formed for the purpose of acquiring Narragansett Electric to which certain interests of PPL Energy Holdings in the Narragansett SPA 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 - an indirectPPL WPD Limited, a U.K. subsidiary of PPL Global, which carries a liability for a closed defined benefit pension plan and a receivable from WPD plc. Following a reorganization in October 2015 and October 2017,Global. Prior to the sale of the U.K. utility business on June 14, 2021, PPL WPD Limited iswas an indirect parent to WPD plc having previously been a sister company.
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Other terms and abbreviations
£ - British pound sterling.
401(h) account(s) - a sub-account established within a qualified pension trust to provide for the payment of retiree medical costs.
Act 11 - Act 11 of 2012 that became effective on April 16, 2012. The Pennsylvania legislation authorized the PUC 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.
Adjusted Gross Margins - a non-GAAP financial measure of performance used in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).
Advanced Metering System Infrastructure -meters and meter-reading systemsmeter reading infrastructure that provide two-way communication capabilities, which communicate usage and other relevant data to LG&E and KU at regular intervals, and are also able to receive information from LG&E and KU, such as software upgrades and requests to provide meter readings in real time.
AFUDC - allowance for funds used during construction. The cost of equity and debt funds used to finance construction projects of regulated businesses, which is capitalized as part of construction costs.
AOCI - accumulated other comprehensive income or loss.
ARO - asset retirement obligation.
ATM Program - at-the-market stock offering program.
Cane Run Unit 7 - a natural gas combined-cycle generating unit in Kentucky, jointly owned by LG&E and KU.
CCR(s) -coal combustion residual(s). CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes.
CDP - a not-for-profit organization based in the United Kingdom formerly known as the Carbon Disclosure Project; that runs the global disclosure system that enables investors, companies, cities, states and regions to measure and manage their environmental impacts.
Clean Air Act - federal legislation enacted to address certain environmental issues related to air emissions, including acid rain, ozone and toxic air emissions.
Clean Water Act - federal legislation enacted to address certain environmental issues relating to water quality including effluent discharges, cooling water intake, and dredge and fill activities.
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 facility 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.
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DDCP - Directors Deferred Compensation Plan.
DNO - Distribution Network Operator in the U.K.
DRIP - PPL Amended and Restated Dividend Reinvestment and Direct Stock Purchase and Dividend Reinvestment Plan.
DSIC - the Distribution System Improvement Charge authorizedCharge. 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 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).
EBPB- Employee Benefit Plan Board. The administrator of PPL's U.S. qualified retirement plans, which is charged with the fiduciary responsibility to oversee and manage those plans and the investments associated with those plans.
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 by-productsbyproducts from the production of energy from coal.
ELG(s)- Effluent Limitation Guidelines, regulations promulgated by the EPA.
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.
GBP - British pound sterling.
GLT-gas line tracker. The KPSC approved mechanism for LG&E's recovery of costs associated with gas transmission lines, gas service lines gas risers,and leak mitigation,mitigation.
Green Tariff - a KPSC approved rate schedule, permitting customers to contract with LG&E or KU for the purchase of renewable energy certificates, construction of solar generation and gas main replacements.use of the energy produced, or the purchase of energy from a renewable energy generator.
GWh - gigawatt-hour, one million kilowatt hours.
IBEW- International Brotherhood of Electrical Workers.
ICP - The PPL Incentive Compensation Plan. This plan provides for incentive compensation to PPL's executive officers and certain other senior executives. New awards under the ICP were suspended in 2012 upon adoption of PPL's 2012 Stock Incentive Plan.
ICPKE - The PPL Incentive Compensation Plan for Key Employees. The ICPKE provides for incentive compensation to certain employees below the level of senior executive.
IRS - Internal Revenue Service, a U.S. government agency.
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KPSC - Kentucky Public Service Commission, the state agency that has jurisdiction over the regulation of rates and service of utilities in Kentucky.
KU 2010 Mortgage Indenture - KU's Indenture, dated as of October 1, 2010, to The Bank of New York Mellon, as supplemented.
kVA - kilovolt ampere.
kWh - kilowatt hour, basic unit of electrical energy.
LCIDA - Lehigh County Industrial Development Authority.
LG&E 2010 Mortgage Indenture - LG&E's Indenture, dated as of October 1, 2010, to The Bank of New York Mellon, as supplemented.
LIBOR - London Interbank Offered Rate.
MMBtu - one million British Thermal Units.
Moody's - Moody's Investors Service, Inc., a credit rating agency.
MW - megawatt, one thousand kilowatts.
NAAQS - National Ambient Air Quality Standards periodically adopted pursuant to the Clean Air Act.
Narragansett Electric - The Narragansett Electric Company, an entity that serves electric and natural gas customers in Rhode Island. In March 2021, PPL and its subsidiary, PPL Energy Holdings announced a pending acquisition of Narragansett Electric.
NERC - North American Electric Reliability Corporation.
NPNS - the normal purchases and normal sales exception as permitted by derivative accounting rules. Derivatives that qualify for this exception may receive accrual accounting treatment.
OCI - other comprehensive income or loss.
PEDFA - Pennsylvania Economic Development Financing Authority.
Performance unit - stock-based compensation award that represents a variable number of shares of PPL common stock that a recipient may receive based on PPL's attainment of (i) relative total shareowner return (TSR) over a three-year performance period as compared to companies in the Philadelphia Stock ExchangePHLX Utility Sector Index; or (ii) corporate return on equity (ROE) based on the average of the annual ROE for each year of the three-year performance period. In light of the transformational nature of the potential sale of the U.K. utility business in 2021, PPL's ROE-based performance units issued for 2021 were based on a one-year performance period from January 1, 2021 to December 31, 2021; however, these units retained the three year vesting schedule and other characteristics.
PJM - PJM Interconnection, L.L.C., operator of the electricity transmission network and electricity energy market in all or parts of Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia and the District of Columbia.
PLR - Provider of Last Resort, the role of PPL Electric in providing default electricity supply within its delivery area to retail customers who have not chosen to select an alternative electricity supplier under the Customer Choice Act.
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PP&E - property, plant and equipment.
PPL EnergyPlus- prior to the June 1, 2015 spinoff of 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 EnergyPlusMontana, 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 other subsidiaries.the Pacific Northwest.
PPL WPD Investments Limited - PPL WPD Investments Limited, which was, prior to the sale of the U.K. utility business on June 14, 2021, a subsidiary of PPL WPD Limited and parent to WPD plc. PPL WPD Investments Limited was included in the sale of the U.K. utility business on June 14, 2021.
PUC - Pennsylvania Public Utility Commission, the state agency that regulates certain ratemaking, services, accounting and operations of Pennsylvania utilities.
RCRA - Resource Conservation and Recovery Act of 1976.
Registrant(s) - refers to the Registrants named on the cover of this Report (each a "Registrant" and collectively, the "Registrants").
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.
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.
SIP - PPL Corporation's Amended and Restated 2012 Stock Incentive Plan.
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.
S&P - Standard & Poor'sS&P Global Ratings, Services, 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 Energy Marketing - Talen Energy Marketing, LLC, the newsuccessor name of PPL EnergyPlus, subsequent toafter 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.
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TCJA - Tax Cuts and Jobs Act. Comprehensive U.S. federal tax legislation enacted on December 22, 2017.
Total shareowner return - the change in market value of a share of the Company'scompany's common stock plus the value of all dividends paid on a share of the common stock during the applicable performance period, divided by the price of the common stock as of the beginning of the performance period. The price used for purposes of this calculation is the average share price for the 20 trading days at the beginning and end of the applicable period.
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.
VEBA - Voluntary Employee Benefit Association Trust, accounts for healthBeneficiary Association. A tax-exempt trust under the Internal Revenue Code Section 501 (c)(9) used by employers to fund and welfare plans for future benefit payments for employees, retirees or their beneficiaries.pay eligible medical, life and similar benefits.
VSCC - Virginia State Corporation Commission, the state agency that has jurisdiction over the regulation of Virginia corporations, including utilities.
WPD - Prior to the sale of the U.K. utility business on June 14, 2021, refers to PPL WPD Limited and its subsidiaries. WPD was included in the sale of the U.K. utility business on June 14, 2021.
WPD (East Midlands) - Western Power Distribution (East Midlands) plc, a British regional electricity distribution utility company. WPD (East Midlands) was included in the sale of the U.K. utility business on June 14, 2021.
WPD plc - Western Power Distribution plc, a U.K. indirect subsidiary of PPL WPD Limited. Its principal indirectly owned subsidiaries are WPD (East Midlands), WPD (South Wales), WPD (South West) and WPD (West Midlands). WPD plc was included in the sale of the U.K. utility business on June 14, 2021.
WPD Midlands- refers to WPD (East Midlands) and WPD (West Midlands), collectively. WPD Midlands was included in the sale of the U.K. utility business on June 14, 2021.
WPD (South Wales) - Western Power Distribution (South Wales) plc, a British regional electricity distribution utility company. WPD (South Wales) was included in the sale of the U.K. utility business on June 14, 2021.
WPD (South West) - Western Power Distribution (South West) plc, a British regional electricity distribution utility company. WPD (South West) was included in the sale of the U.K. utility business on June 14, 2021.
WPD (West Midlands)- Western Power Distribution (West Midlands) plc, a British regional electricity distribution utility company. WPD (West) Midlands) was included in the sale of the U.K. utility business on June 14, 2021.
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Forward-looking Information
Statements contained in this Annual Report 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 "Item 1A. Risk Factors" and in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in this Annual Report, 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, including the pending acquisition of Narragansett Electric, and our ability to consummate these business transactions or realize expected benefits from them;
•the COVID-19 pandemic and its continuing impact on economic conditions, financial markets and supply chains;
•other 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);
•the outcome of rate cases or other cost recovery or revenue filings;proceedings;
•significant decreases in demand for electricity in the U.S.;electricity;
•expansion of alternative and distributed sources of electricity generation and storage;
•the effectiveness of our risk management programs, including foreign currency and interest rate hedging;
•defaults by counterparties or suppliers for energy, capacity, coal, natural gas or key commodities, goods or services;
•capital market conditions, including the availability of capital, credit or credit,insurance, changes in interest rates and certain economic indices, and decisions regarding capital structure;
•a material decline in the market value of PPL's equity;
•significant decreases in the fair value of debt and equity securities and itstheir impact on the value of assets in defined benefit plans, and therelated potential cash funding requirements if the fair value declines;of those assets decline;
•interest rates and their effect on pension and retiree medical liabilities, ARO liabilities and interest payable on certain debt securities;
•volatility in or the impact of other changes in financial markets and economic conditions;conditions, including inflation;
•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;
•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;
•weather and other conditions affecting generation, transmission and distribution operations, operating costs and customer energy use;
•war, armed conflicts, terrorist attacks, or similar disruptive events;
•changes in political, regulatory or economic conditions in states, regions or countries where the Registrants or their subsidiaries conduct business;
•receipt of necessary governmental permits and approvals;
•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 any business or industry restructuring;
•development of new projects, markets and technologies;
•performance of new ventures;
•collective labor bargaining negotiations; and
•the outcome of litigation againstinvolving 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.
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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.
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PART I
ITEM 1. BUSINESS
General
(All Registrants)
PPL Corporation, headquartered in Allentown, Pennsylvania, is a utility holding company, incorporated in 1994, in connection with the deregulation of electricity generation in Pennsylvania, to serve as the parent company to the regulated utility, PPL Electric, and to generation and other unregulated business activities. PPL, Electric was founded in 1920 as Pennsylvania Power & Light Company. PPL, through its regulated utility subsidiaries, delivers electricity to customers in the U.K., Pennsylvania, Kentucky Virginia and Tennessee;Virginia; delivers natural gas to customers in Kentucky; and generates electricity from power plants in Kentucky. In June 2015, PPL completed the spinoff of PPL Energy Supply, which combined its competitive power generation businesses with those of Riverstone to form a new, stand-alone, publicly traded company named Talen Energy. See "Spinoff of PPL Energy Supply" below for more information.
PPL's principal subsidiaries at December 31, 20172021 are shown below (* denotes a Registrant).
| PPL Corporation* | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
PPL Electric* | LKE A holding company that owns regulated utility operations through its subsidiaries, LG&E and KU | PPL Capital Funding Provides financing for the operations of PPL and certain subsidiaries | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
LG&E* | KU* | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Pennsylvania Regulated Segment | Kentucky Regulated Segment | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
In addition to PPL, the other Registrants included in this filing are as follows.
PPL Electric Utilities Corporation, headquartered in Allentown, Pennsylvania, is a wholly owned subsidiary of PPL organized in Pennsylvania in 1920 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 PUC, 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, and KU Energy LLC, headquartered in Louisville, Kentucky, is a wholly owned subsidiary of PPL and a holding company that owns regulated utility operations through its subsidiaries, LG&E and KU, which constitute substantially all of LKE's assets. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also
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Segment Information
(PPL)
PPL is organized into threetwo reportable segments as depicted in the chart above: U.K. Regulated, Kentucky Regulated, and Pennsylvania Regulated. The U.K. Regulated segment has no related subsidiary Registrants. PPL's other reportable segments' resultswhich primarily representrepresents the results of its related subsidiary Registrants, except that the reportable segments are also allocated certain corporate level financingLG&E and other costs that are not included inKU, and Pennsylvania Regulated, which primarily represents the results of the applicable subsidiary Registrants. PPL also has corporateElectric. "Corporate and other costs whichOther" primarily includeincludes financing costs incurred at the corporate level that have not been allocated or assigned to the segments, as well as certain other unallocated costs. As a result of the June 1, 2015 spinoff of PPL Energy Supply, PPL no longer has a Supply segment. The operations of the Supply segment are included in "Loss from Discontinued Operations (net of income taxes)" on the Statements of Income.segments.
A comparison of PPL's three regulatedRegulated segments is shown below.
| Kentucky | Pennsylvania | ||||||||||
| Regulated | Regulated | ||||||||||
| For the year ended December 31, 2021: | |||||||||||
| Operating Revenues (in billions) | $ | 3.3 | $ | 2.4 | |||||||
| Net Income (in millions) | $ | 468 | $ | 445 | |||||||
| Electricity delivered (GWh) | 30,317 | 37,005 | |||||||||
| At December 31, 2021: | |||||||||||
| Regulatory Asset Base (in billions) (a) | $ | 11.3 | $ | 8.9 | |||||||
| Service area (in square miles) | 9,400 | 10,000 | |||||||||
| End-users (in millions) | 1.3 | 1.4 | |||||||||
| Kentucky | Pennsylvania | ||||||||||
| U.K. Regulated | Regulated | Regulated | |||||||||
| For the year ended December 31, 2017: | |||||||||||
| Operating Revenues (in billions) | $ | 2.1 | $ | 3.2 | $ | 2.2 | |||||
| Net Income (in millions) | $ | 652 | $ | 286 | $ | 359 | |||||
| Electricity delivered (GWh) | 74,317 | 31,839 | 35,996 | ||||||||
| At December 31, 2017: | |||||||||||
| Regulatory Asset Base (in billions) (a) | $ | 9.8 | $ | 9.2 | $ | 6.9 | |||||
| Service area (in square miles) | 21,600 | 9,400 | 10,000 | ||||||||
| End-users (in millions) | 7.9 | 1.3 | 1.4 | ||||||||
(a)Represents capitalization for Kentucky Regulated and rate base for Pennsylvania Regulated.
See Note 2 to the Financial Statements for additional financial information aboutby segment. The sale of the segments.U.K. utility business, which substantially represented PPL’s U.K. Regulated segment as reported in prior years, was completed on June 14, 2021,pursuant to a share purchase agreement entered into on March 17, 2021. As a result, PPL determined segment information for the U.K. Regulated segment would no longer be provided beginning with the Form 10-Q for the quarter ended March 31, 2021. See Note 9 to the Financial Statements for additional information.
(PPL Electric, LKE, LG&E and KU)
PPL Electric has two operating segments, thatdistribution and transmission, which are aggregated into a single reportable segment. LKE, LG&E and KU are individually single operating and reportable segments.
| 2017 | 2016 | 2015 | |||||||||
| Operating Revenues (a) | $ | 2,091 | $ | 2,207 | $ | 2,410 | |||||
| 2017 | 2016 | |||||||
| Taxes collected in revenues | £ | 57 | £ | 53 | ||||
| Taxes recorded under GAAP | 139 | 119 | ||||||
| Incentive Received | Calendar Year Ended Incentive | |||||
| Calendar Year Ended Incentive Earned | (in millions) | Included in Revenue | ||||
| 2014 | £ | 83 | 2016 | |||
| 2015 | 79 | 2017 | ||||
| 2016 | 76 | 2018 | ||||
| 2017 (a) | 65-80 | 2019 | ||||
| 2018 (a) | 70-85 | 2020 | ||||
(PPL, LKE, LG&E and KU)
LG&E and KU direct subsidiaries of LKE, are engaged in the regulated generation, transmission, distribution and sale of electricity in Kentucky and, in KU's case, Virginia and Tennessee.also Virginia. LG&E also engages in the distribution and sale of natural gas in Kentucky. LG&E provides electricelectricity service to approximately 411,000429,000 customers in Louisville and adjacent areas in Kentucky, covering approximately 700 square miles in nine counties and provides natural gas service to approximately 326,000333,000 customers in its electricelectricity service area and eight additional counties in Kentucky. KU provides electric service to approximately 525,000538,000 customers in 77 counties in central, southeastern and western Kentucky and approximately 28,000 customers in five counties in southwestern Virginia, and three customers in Tennessee, covering approximately 4,800 non-contiguous square miles. KU also sells wholesale electricity to 10two municipalities in Kentucky under load following contracts. See Note 3 to the Financial Statements for revenue information.
| 2017 | 2016 | 2015 | ||||||||||||||||||
| Revenue | % of Revenue | Revenue | % of Revenue | Revenue | % of Revenue | |||||||||||||||
| LKE | ||||||||||||||||||||
| Commercial | $ | 854 | 27 | $ | 834 | 27 | $ | 816 | 26 | |||||||||||
| Industrial | 603 | 19 | 601 | 19 | 628 | 20 | ||||||||||||||
| Residential | 1,259 | 40 | 1,261 | 40 | 1,245 | 40 | ||||||||||||||
| Other (a) | 280 | 9 | 288 | 9 | 267 | 9 | ||||||||||||||
| Wholesale - municipal | 112 | 4 | 116 | 4 | 114 | 4 | ||||||||||||||
| Wholesale - other (b) | 48 | 1 | 41 | 1 | 45 | 1 | ||||||||||||||
| Total | $ | 3,156 | 100 | $ | 3,141 | 100 | $ | 3,115 | 100 | |||||||||||
| 2017 | 2016 | 2015 | ||||||||||||||||||
| Revenue | % of Revenue | Revenue | % of Revenue | Revenue | % of Revenue | |||||||||||||||
| LG&E | ||||||||||||||||||||
| Commercial | $ | 453 | 31 | $ | 442 | 31 | $ | 436 | 30 | |||||||||||
| Industrial | 187 | 13 | 185 | 13 | 199 | 14 | ||||||||||||||
| Residential | 637 | 44 | 627 | 44 | 633 | 44 | ||||||||||||||
| Other (a) | 123 | 8 | 135 | 9 | 117 | 8 | ||||||||||||||
| Wholesale - other (b) | 53 | 4 | 41 | 3 | 59 | 4 | ||||||||||||||
| Total | $ | 1,453 | 100 | $ | 1,430 | 100 | $ | 1,444 | 100 | |||||||||||
| 2017 | 2016 | 2015 | ||||||||||||||||||
| Revenue | % of Revenue | Revenue | % of Revenue | Revenue | % of Revenue | |||||||||||||||
| KU | ||||||||||||||||||||
| Commercial | $ | 401 | 23 | $ | 392 | 22 | $ | 380 | 22 | |||||||||||
| Industrial | 416 | 24 | 416 | 24 | 429 | 25 | ||||||||||||||
| Residential | 622 | 36 | 634 | 36 | 612 | 35 | ||||||||||||||
| Other (a) | 157 | 9 | 153 | 9 | 150 | 9 | ||||||||||||||
| Wholesale - municipal | 112 | 6 | 116 | 7 | 114 | 7 | ||||||||||||||
| Wholesale - other (b) | 36 | 2 | 38 | 2 | 43 | 2 | ||||||||||||||
| Total | $ | 1,744 | 100 | $ | 1,749 | 100 | $ | 1,728 | 100 | |||||||||||
Franchises and Licenses
LG&E and KU provide electricity delivery service, and LG&E provides natural gas distribution service, in their respective service territories pursuant to certain franchises, licenses, statutory service areas, easements and other rights or permissions granted by state legislatures, cities or municipalities or other entities.
4
Competition
There are currently no other electric public utilities operating within the electricelectricity service areas of LKE.LG&E and KU. From time to time, bills are introduced into the Kentucky General Assembly which seek to authorize, promote or mandate increased distributed generation, customer choice or other developments. Neither the Kentucky General Assembly nor the KPSC has adopted or approved a plan or timetable for retail electric industry competition in Kentucky. The nature or timing of legislative or regulatory actions, if any, regarding industry restructuring and their impact on LKE,LG&E and KU, which may be significant, cannot currently
be predicted. Virginia, formerly a deregulated jurisdiction, has enacted legislation that implemented a hybrid model of cost-based regulation. KU's operations in Virginia have been and remain regulated.
Alternative energy sources such as electricity, oil, propane and other fuels indirectly impact LG&E's natural gas revenues. Marketers may also compete to sell natural gas to certain large end-users. LG&E's natural gas tariffs include gas price pass-through mechanisms relating to its sale of natural gas as a commodity; therefore,commodity. Therefore, customer natural gas purchases from alternative suppliers do not generally impact LG&E's profitability. Some large industrial and commercial customers, however, may physically bypass LG&E's facilities and seek delivery service directly from interstate pipelines or other natural gas distribution systems.
Power Supply
At December 31, 2017, LKE2021, LG&E owned controlled or had a minority ownership interest in generating capacity of 8,0172,760 MW and KU owned generating capacity of which 2,920 MW related to LG&E and 5,097 MW related to KU, in Kentucky, Indiana, and Ohio.4,775 MW. See "Item 2. Properties - Kentucky Regulated Segment" for a complete list of LKE's generating facilities.
The system capacity of LKE'sLG&E's and KU's owned or controlled generation is based upon a number ofseveral factors, including the operating experience and physical condition of the units, and may be revised periodically to reflect changes in circumstances.
During 2017, LKE's2021, LG&E's and KU's power plants generated the following amounts of electricity.electricity:
| GWh | |||||||||||
| Fuel Source | LG&E | KU | |||||||||
| Coal | 10,297 | 14,718 | |||||||||
| Gas | 1,395 | 4,382 | |||||||||
| Hydro | 263 | 89 | |||||||||
| Solar | 7 | 12 | |||||||||
| Total (a) | 11,962 | 19,201 | |||||||||
| GWh | ||||||||
| Fuel Source | LKE | LG&E | KU | |||||
| Coal (a) | 28,519 | 12,161 | 16,358 | |||||
| Gas | 4,625 | 1,105 | 3,520 | |||||
| Hydro | 337 | 278 | 59 | |||||
| Solar | 18 | 7 | 11 | |||||
| Total (b) | 33,499 | 13,551 | 19,948 | |||||
(a)This generation represents increases for LG&E and KU of 4% and 5% from 2020 output.
The majority of LG&E's and KU's generated electricity was used to supply their retail and KU's municipal customer base.bases.
LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail and municipal customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa.
LG&E and KU received approval from the KPSC to develop a 4 MW solar shareSolar Share facility to service a solar shareSolar Share program. The solar shareSolar Share program is an optional,a voluntary program that allows customers to subscribe capacity in the solar shareSolar Share facility. Construction is expected to begin,commences, in 500-kilowatt phases, when subscription is complete. AsConstruction of four 500-kilowatt phases was completed as of December 31, 2017,2021. The subscription for the fifth 500-kilowatt phase was completed with construction expected to be completed in 2022. LG&E and KU have not yet constructed the first solar share facility and are actively marketingcontinue to market the program and continuehave started receiving subscriptions for the sixth 500-kilowatt phase.
On January 23, 2020, LG&E and KU applied to receive interest from customers.
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PPL, LG&E and KU do not anticipate that these arrangements will have a combined capacitysignificant impact on their results of 563operations or financial condition.
On October 6, 2021, LG&E and KU entered into an agreement to purchase the initial 20 years of output of a proposed 125 MW atthird-party solar generation facility in connection with the Cane Run plant.Green Tariff option established in the 2018 Kentucky base rate cases. Pursuant to the agreements, LG&E and KU would purchase output of the facility and resell power as renewable energy to certain large customers. The generation facility is currently expected to be operational in the fourth quarter of 2024. PPL, LG&E and KU do not anticipate that this agreement will have a significant impact on their results of operations or financial condition.
Fuel Supply
Coal and natural gas will continueare expected to be the predominant fuelfuels used by LG&E and KU for generation for the foreseeable future. Natural gas used for generation is primarily purchased using contractual arrangements separate from LG&E's natural gas distribution operations. Natural gas and oil will continue to beare also used for intermediate and peaking capacity and flame stabilization in coal-fired boilers.
Fuel inventory is maintained at levels estimated to be necessary to avoid operational disruptions at coal-fired generating units. Reliability of coal deliveries can be affected from time to time by a number ofseveral factors including fluctuations in demand, coal mine production issues, high or low river level events, lock outages and other supplier or transporter operating or financial difficulties.
LG&E and KU have entered into coal supply agreements with various suppliers for coal deliveries through 20232026 and augment their coal supply agreements with spot market purchases, as needed.
For their existing units, LG&E and KU expect, for the foreseeable future, to purchase most of their coal from western Kentucky, southern Indiana, southern Illinois, northern West Virginia and southern Illinois.western Pennsylvania. LG&E and KU continue to purchase certain quantities of ultra-low sulfur content coal from Wyoming for blending at Trimble County Unit 2. Coal is delivered to the generating plants primarily by barge and rail.
To enhance the reliability of natural gas supply, LG&E and KU have secured firm long-term pipeline transport capacity services with contracts of various durations from 2019 tothrough 2024 on the interstate pipeline serving Cane Run Unit 7. This pipeline also serves the six simple cycle combustion turbine units located at the Trimble County site as well as fourtwo other simple cycle units at the Cane Run and Paddy's Run sites. LG&E has also secured long-term firm pipeline transport capacity on an interstate pipeline for the summer months through October 2018 to serve an additional simple cycle gas turbine operated under a tolling agreement that ends April 30, 2019.site. For the seven simple cycle combustion turbines at the E.W. Brown facility, no firm long-term pipeline transport capacity has been purchased due to the facility being interconnectedfacility's connection to two interstate pipelines and some of the units having dual fuel capability.
LG&E and KU have firm contracts for a portion of the natural gas fuel for Cane Run Unit 7 for delivery in future months.through October 2024. The bulk of the natural gas fuel remains purchased on the spot market.
(PPL LKE and LG&E)
Natural Gas Distribution Supply
Five underground natural gas storage fields, with a current working natural gas capacity of approximately 15 billion cubic feet (Bcf), are used in providingto provide natural gas service to LG&E's firm sales customers. By using natural gas storage facilities, LG&E avoids the costs typically associated with more expensive pipeline transportation capacity to serve peak winter heating loads. Natural gas is stored during the summer season for withdrawal during the following winter heating season. Without this storage capacity, LG&E would be requiredneed to purchase additional natural gas and pipeline transportation services during winter months when customer demand increases and the prices for natural gas supply and transportation services can beare expected to be at their highest.higher. At December 31, 2017,2021, LG&E had 12 Bcf of natural gas stored underground with a carrying value of $43$54 million.
LG&E has a portfolio of supply arrangements of varying durations and terms that provide competitively priced natural gas designed to meet its firm sales obligations. These natural gas supply arrangements include pricing provisions that are market-responsive. In tandem with pipeline transportation services, these natural gas supplies provide the reliability and flexibility necessary to serve LG&E's natural gas customers.
LG&E purchases natural gas supply transportation services from two pipelines. LG&E has contracts with one pipeline that are subject to termination by LG&E between 20202023 and 2023.2026. Total winter season capacity under these contracts is 184,900 MMBtu/day and summer season capacity is 60,000 MMBtu/day. With this same pipeline, LG&E also has another contract for
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pipeline capacity through 2026 in the amount offor 60,000 MMBtu/day during both the winter and summer seasons. LG&E has a single contract with a second pipeline with a total capacity of 20,000 MMBtu/day during both the winter and summer seasons that expires in 2023.
LG&E expects to purchase natural gas supplies for its gas distribution operations from onshore producing regions in South Texas, East Texas, North Louisiana and Arkansas, as well as gas originating in the Marcellus and Utica production areas.
(PPL, LKE, LG&E and KU)
Transmission
LG&E and KU contract with the Tennessee Valley Authority to act as their transmission reliability coordinator and contract with TranServ International, Inc. to act as their independent transmission organization.
Rates
LG&E is subject to the jurisdiction of the KPSC and the FERC, and KU is subject to the jurisdiction of the KPSC, the FERC and the VSCC. LG&E and KU operate under a FERC-approved open access transmission tariff.
LG&E's and KU's Kentucky base rates are calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets in Kentucky.
KU's Virginia base rates are calculated based on a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except for regulatory assets and liabilities related to the levelized fuel factor, accumulated deferred income taxes, pension and postretirement benefits, and AROs related to certain CCR impoundments, are excluded from the return on rate base utilized in the calculation of Virginia base rates, no return is earned on the related assets.
KU's rates to 10 municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except regulatory assets recorded for AROs related to CCR impoundments,accumulated deferred income taxes, are excluded from the return on rate base utilized in the development of municipal rates, no return is earned on the related assets. In April 2014, ninecertain municipalities submitted notices of termination under the notice period provisions, to cease taking power under the wholesale requirements contracts. Such terminations areKU's service to beeight municipalities terminated effective in 2019, except in the case of one municipality that terminated service in 2017.
See "Financial and Operational Developments" in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" and Note 67 to the Financial Statements for additional information on cost recoverycurrent rate proceedings and rate mechanisms.
Pennsylvania Regulated Segment(PPL)
(PPL and PPL Electric)
PPL Electric delivers electricity to approximately 1.4 million customers in a 10,000-square mile territory in 29 counties ofwithin eastern and central Pennsylvania. PPL Electric also provides electricity supply to retail customers in this areaterritory as a PLR under the Customer Choice Act. See Note 3 to the Financial Statements for revenue information.
| 2017 | 2016 | 2015 | ||||||||||||||||||
| Revenue | % of Revenue | Revenue | % of Revenue | Revenue | % of Revenue | |||||||||||||||
| Distribution | ||||||||||||||||||||
| Residential | $ | 1,351 | 62 | $ | 1,327 | 61 | $ | 1,338 | 63 | |||||||||||
| Industrial | 44 | 2 | 42 | 2 | 58 | 3 | ||||||||||||||
| Commercial | 349 | 16 | 338 | 16 | 377 | 18 | ||||||||||||||
| Other (a) | (36 | ) | (2 | ) | (4 | ) | — | (44 | ) | (2 | ) | |||||||||
| Transmission | 487 | 22 | 453 | 21 | 395 | 18 | ||||||||||||||
| Total | $ | 2,195 | 100 | $ | 2,156 | 100 | $ | 2,124 | 100 | |||||||||||
Franchise, Licenses and Other Regulations
PPL Electric is authorized to provide electric public utility service throughout its service area as a result of grants by the Commonwealth of Pennsylvania in corporate charters to PPL Electric and companies which it has succeeded, and as a result of certification by the PUC. PPL Electric is granted the right to enter the streets and highways by the Commonwealth subject to certain conditions. In general, such conditions have been met by ordinance, resolution, permit, acquiescence or other action by an appropriate local political subdivision or agency of the Commonwealth.
7
Competition
Pursuant to authorizations from the Commonwealth of Pennsylvania and the PUC, PPL Electric operates a regulated distribution monopoly in its service area. Accordingly, PPL Electric does not face competition in its electricity distribution business. Pursuant to the Customer Choice Act, generation of electricity is a competitive business in Pennsylvania, and PPL Electric does not own or operate any generation facilities.
The PPL Electric transmission business, operating under a FERC-approved PJM Open Access Transmission Tariff, is subject to competition pursuant to FERC Order 1000 from entities that are not incumbent PJM transmission owners with respect to the construction and ownership of transmission facilities within PJM.
Rates and Regulation
Transmission
PPL Electric's transmission facilities are within PJM, which operates the electricity transmission network and electric energy market in the Mid-Atlantic and Midwest regions of the U.S.
PJM serves as a FERC-approved Regional Transmission Operator (RTO) to promote greater participation and competition in the region it serves. In addition to operating the electricity transmission network, PJM also administers regional markets for energy, capacity and ancillary services. A primary objective of any RTO is to separate the operation of, and access to, the transmission grid from market participants that buy or sell electricity in the same markets. Electric utilities continue to own the transmission assets and to receive their share of transmission revenues, but the RTO directs the control and operation of the transmission facilities. Certain types of transmission investmentinvestments are subject to competitive processes outlined in the PJM tariff.
As a transmission owner, PPL Electric's transmission revenues are recovered through PJM and billed in accordance with a FERC-approved Open Access Transmission Tariff that allows recovery of incurred transmission costs, a return on transmission-related plant and an automatic annual update based on a formula-based rate recovery mechanism. Under this formula, rates are put into effect in June of each year based upon prior year actual expenditures and current year forecasted capital additions. Rates are then adjusted the following year to reflect actual annual expenses and capital additions, as reported in PPL Electric’s annual FERC Form 1, filed under the FERC’s Uniform System of Accounts. Any difference between the revenue requirement in effect for the prior year and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability. Any change in the prior year PPL zonal peak load billing factor applied on January 1st1 of each year will result in an increase or decrease in revenue until the next annual rate update goes into effectis effective on June 1st1 of that same year.
As a PLR, PPL Electric also purchases transmission services from PJM. See "PLR" below.
See "Financial and Operational Developments" in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" and Note 67 to the Financial Statements for additional information on rate mechanisms.mechanisms and regulatory matters.
Distribution
PPL Electric's distribution base rates are calculated based on a return on rate base (net utility plant plus a cash working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). All regulatory assets and liabilities, except accumulated deferred income taxes, are excluded from the return on rate base; therefore,base. Therefore, no return is earned on the related assets unless specifically provided for by the PUC. Currently, PPL Electric's Smart Meter rider and the DSIC are the only riders authorized to earn a return. Certain operating expenses are also included in PPL Electric's distribution base rates including wages and benefits, other operation and maintenance expenses, depreciation and taxes.
Pennsylvania's Alternative Energy Portfolio Standard (AEPS) requires electricity distribution companies and electricity generation suppliers to obtain from alternative energy resources a portion of the electricity sold to retail customers in Pennsylvania. Under the default service procurement plans approved by the PUC, PPL Electric purchases all of the alternative energy generation supply it needs to comply with the AEPS.
Act 129 created an energy efficiency and conservation program, a demand side management program, smart metering technology requirements, new PLR generation supply procurement rules, remedies for market misconduct and changes to the existing AEPS.
8
Act 11 authorizes the PUC to approve two specific ratemaking mechanisms: the use of a fully projected future test year in base rate proceedings and, subject to certain conditions, the use of a DSIC. Such alternative ratemaking procedures and mechanisms provide opportunity for accelerated cost-recovery and, therefore, are important to PPL Electric as it is in a period of significant capital investment to maintain and enhance the reliability of its delivery system, including the replacement of aging assets. PPL Electric has utilized the fully projected future test year mechanism in its 2015 base rate proceeding. PPL has had the ability to utilize the DSIC recovery mechanism since July 2013.
See "Regulatory Matters - Pennsylvania Activities" in Note 67 to the Financial Statements for additional information regarding Act 129on rate mechanisms and other legislative and regulatory impacts.matters.
PLR
The Customer Choice Act requires Electric Distribution Companies (EDCs),electric distribution companies, including PPL Electric, or an alternative supplier approved by the PUC, to act as a PLR of electricity supply for customers who do not choose to shop for supply with a competitive supplier and provides that electricity supply costs will be recovered by the PLR pursuant to PUC regulations. In 2017,2021, the following average percentages of PPL Electric's customer load were provided by competitive suppliers: 46%39% of residential, 85%79% of small commercial and industrial and 98% of large commercial and industrial customers. The PUC continues to favor expanding the competitive market for electricity. See "Regulatory Matters - Pennsylvania Activities - Act 129" in Note 6 to the Financial Statements for additional information.
PPL Electric's cost ofElectric’s electricity generation iscosts are established based onupon the results of a competitive solicitation process. TheOn December 17, 2020, the PUC approved PPL Electric'sElectric’s default service plan for the period June 20151, 2021 through May 2017,31, 2025, which included 4includes a total of eight solicitations for electricity supply held semiannually in April and October. The PUC approved PPL Electric's default servicefirst two auctions of the plan for the period June 2017 through May 2021, whichwere completed in 2021. This plan also includes a total of 8eight solicitations for electricity supplyalternative energy credits held semiannually in AprilJanuary and October. July. Through January 2022, two alternative energy credit solicitations have been completed. All contracts from previous default service plans concluded on or before November 30, 2021.
Pursuant to both the current and future plans, PPL Electric contracts for all of the electricity supply for residential, customers and commercial and industrial customers who elect to take thatdefault service from PPL Electric. These solicitations includecontain a mix of products including 5-year block energy contracts for residential customers, 6- and 12-month fixed-price load-following contracts for residential and small commercial and industrial customers, and 12-
Numerous alternative suppliers have offered to provide generation supply in PPL Electric's service territory. Sincearea. As the cost of generation supply is a pass-through cost for PPL Electric, its financial results are not impacted if its customers purchase electricity supply from these alternative suppliers.
Corporate and Other
(PPL)PPL Services provides PPL subsidiaries with administrative, management and support services. The costs of these services are charged directly to the respective recipients for the services provided or indirectly charged to applicable recipients based on an average of the recipients' relative invested capital, operation and maintenance expenses and number of employees or a ratio of overall direct and indirect costs.
PPL Capital Funding PPL's financing subsidiary, provides financing for the operations of PPL and certain subsidiaries. PPL's growth in rate-regulated businesses provides the organization with an enhanced corporate level financing alternative, through PPL Capital Funding, that enables PPL to cost effectively support targeted credit profiles across all of PPL's rated companies. As a result, PPL plans to utilizeutilizes PPL Capital Funding as a source of capital in future financings, in addition to continued direct financing by thecertain operating companies.subsidiaries.
Unlike PPL Services, PPL Capital Funding's costs are not generally charged to PPL subsidiaries. Costs are charged directly to PPL. However, PPL Capital Funding participated significantly in the financing for the acquisitionsacquisition of LKE and WPD Midlands and certain associated financing costs were allocated to the Kentucky Regulated and U.K. Regulated segments. TheSegment. Prior to 2021, the associated financing costs, as well as the financing costs associated with prior issuances of certain other PPL Capital Funding securities, have beenwere assigned to the appropriate segments for purposes of PPL management's assessment of segment performance. In 2021, corporate level financing costs are no longer allocated to the reportable segments. The financing costs associated primarily with PPL Capital Funding's securities issuances, beginning in 2013, with certain exceptions, have not been directly assigned or allocated to any segment.
ENVIRONMENTAL MATTERS
(All Registrants)
The Registrants are subject to certain existing and developing federal, regional, state and local laws and regulations with respect to air and water quality, land use and other environmental matters, and may be subject to different and more stringent such laws and regulations enacted in the future. The EPA and other federal agencies with jurisdiction over environmental matters have issued numerous environmental regulations relating to air, water and waste that directly affect the electric power industry. Due to these environmental issues, it may be necessary for the Registrants to modify or cease certain operations or operation of certain facilities to comply with statutes, regulations and other requirements of regulatory bodies or courts. In addition, legal challenges to environmental permits or rules add uncertainty to estimating future costs of complying with such permits and rules. The Biden administration is currently undertaking changes in a wide range of environmental programs.
See “Legal Matters” in Note 14 to the Financial Statements for a discussion of environmental commitments and contingencies. 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" for information on projected environmental capital expenditures for 2022 through 2024.
LG&E and KU are entitled to recover, through the ECR mechanism, certain costs of complying with the Clean Air Act, as amended, and other federal, state and local environmental requirements applicable to coal combustion wastes and by-products from coal-fired generating facilities upon KPSC review. Costs not covered by the ECR mechanism for LG&E and KU and all such costs for PPL Electric are subject to rate recovery at the discretion of the companies' respective state regulatory authorities, or the FERC, if applicable. Because PPL Electric does not own any generating plants, it has less exposure to related environmental compliance costs. The Registrants can provide no assurances as to the ultimate outcome of future proceedings before regulatory authorities.
Air
NAAQS (PPL, LG&E and KU)
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 National Ambient Air Quality Standards, known as 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 is currently reconsidering those decisions. PPL, LG&E, and KU are unable to predict the outcome of future evaluations by the EPA and the states with respect to the NAAQS standards.
Applicable regulations require each state to identify areas within its boundaries that fail to meet the NAAQS, (known as nonattainment areas), and develop a state implementation plan to achieve and maintain compliance. States that are found to contribute significantly to another state's nonattainment with ozone standards are required to establish "good neighbor" state implementation plans. In addition, for attainment of ozone and fine particulates standards, certain states, including Kentucky, are subject to a regional EPA program known as the Cross-State Air Pollution Rule (CSAPR).
In January 2018, the EPA designated Jefferson County, Kentucky (Louisville) as being in nonattainment with the existing 2015 ozone standard. In 2020 and 2021, LG&E entered into agreements with the Louisville Metro Air Pollution Control District for temporary nitrogen oxide emission limits at LG&E's Mill Creek Station during those years to facilitate compliance with the ozone standard. If Jefferson County is unable to demonstrate attainment within the specified timeframes, it may be “bumped up” to the moderate nonattainment classification and thus subject to additional requirements including requirements for installation of reasonably available control technology on coal-fired generating units.Compliance with such requirements may require installation of additional pollution controls or other compliance actions. LG&E is unable to determine the impact on operations until certain compliance determinations are made by the EPA and Kentucky.
In April 2021, the EPA published final revisions to the CSAPR providing for reductions in ozone season nitrogen oxide emissions for 2021 and subsequent years from sources in 12 states, including Kentucky. Additionally, the EPA reversed its previous approval of the Kentucky State Implementation Plan with respect to these requirements. The CSAPR revisions are aimed at ensuring compliance with the 2008 ozone NAAQS, so additional nitrogen oxide emission reductions could potentially be required for compliance with the revised 2015 ozone NAAQS. PPL, LG&E and KU do not currently expect the impact of the CSAPR revisions on operations to be material. Pursuant to the President’s executive order, the EPA is currently reconsidering its previous determinations made in December 2020 to retain the existing NAAQS for ozone and particulate matter without change, with final determinations by the EPA expected in 2022 for particulate matter and 2023 for ozone.
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PPL, LG&E, and KU are unable to predict future emission reductions that may be required by future federal rules or state implementation actions. Compliance with the NAAQS, CSAPR 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.
Climate Change (All Registrants)
There is continuing world-wide attention focused on issues related to climate change. In 2015, 195 nations, including the U.S., signed the Paris Agreement on Climate, establishing non-binding targets to reduce GHG emissions from both developed and developing nations. In 2017, President Trump announced a U.S. withdrawal from the Paris Agreement, effective November 2020. In January 2021, the Biden presidential administration initiated the process to rejoin the Paris Agreement, which was completed in February 2021. The Biden administration also issued executive orders directing agencies to conduct a general review of regulations and executive actions relating to the environment and reestablished a framework for considering the social cost of carbon as part of certain agency cost-benefit analyses for new regulations. The Biden administration is exploring wide-ranging efforts to address climate change. Recent government actions and policy developments, including the President’s announced goal of a carbon free electricity sector by 2035, and targeting net-zero emissions for the federal government by 2050, could have significant impacts on PPL’s business operations, products, and services. Certain of the efforts announced by the Biden administration are preliminary or ongoing in nature. Additionally, there are ongoing efforts by various state and local governments to assess potential changes to legislation, rules, policies, directives, and other requirements applicable to greenhouse gas emissions. PPL, LG&E and KU cannot predict the outcome of ongoing developments.
PPL has adopted a goal of net-zero carbon emissions by 2050, which includes continuing to retire coal-fired generation and investing in research and innovation that will help to achieve this goal, while maintaining reliable and affordable energy in our service territories. The net-zero goal relates to direct and indirect carbon emissions consistent with Greenhouse Gas Protocol guidance and referenced by the EPA Center for Corporate Climate Leadership. Through 2020, PPL has reduced carbon emissions nearly 60% from 2010 levels and is targeting a 70% reduction from 2010 levels by 2035 and an 80% reduction by 2040.
PPL is also aware of the various risks associated with climate change, including increased frequency and severity of severe weather. To address these risks, PPL continues to work to advance the grid and improve the Company's equipment to help mitigate the impacts of extreme weather events and improve reliability.
The EPA's Affordable Clean Energy Rule (PPL, LG&E and KU)
In July 2019, the EPA repealed the Clean Power Plan and finalized the Affordable Clean Energy (ACE) Rule which gives states broad latitude to establish emission guidelines providing for plant-specific efficiency upgrades or "heat-rate improvements" to reduce GHG emissions per unit of electricity generated. Various entities filed petitions for review and petitions for reconsideration. On January 19, 2021, the D.C. Circuit Court issued an opinion finding that the EPA had erroneously repealed the Clean Power Plan. The D.C Circuit Court's opinion also vacated and remanded the ACE Rule to the EPA. On October 29, 2021, the U.S. Supreme Court granted review of the D.C. Circuit Court’s ruling.PPL, LG&E, and KU cannot predict the outcome of the pending litigation and regulatory proceedings or changes that may be pursued by the Biden administration, but believe that the costs would be subject to rate recovery.
Water/Waste
(PPL, LG&E and KU)
Clean Water Act
Regulations under the federal Clean Water Act dictate permitting and mitigation requirements for facilities and construction projects that impact "Waters of the United States." Many other requirements relate to power plant operations, including the treatment of pollutants in effluents prior to discharge, the temperature of effluent discharges and the location, design and construction of cooling water intake structures at generating facilities, and standards intended to protect aquatic organisms that become trapped at or pulled through cooling water intake structures at generating facilities. These requirements could impose significant costs for LG&E and KU, which are expected to be subject to rate recovery.
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Clean Water Act Jurisdiction
Environmental groups and others have claimed that discharges to groundwater from leaking CCR impoundments at power plants are subject to Clean Water Act permitting. On April 12, 2019, the EPA released regulatory clarification finding that Clean Water Act jurisdiction does not cover such discharges to groundwater. On January 23, 2020, the EPA announced a final rule modifying the jurisdictional scope of the Clean Water Act. The announced rule revises the definition of the "Waters of the United States," including a revision to exclude groundwater from the definition. In April 2020, the U.S. Supreme Court issued a ruling that Clean Water Act jurisdiction may apply to certain discharges to groundwater that result in the functional equivalent of a direct discharge to navigable waters. PPL, LG&E, and KU are unaware of any unpermitted releases from their facilities that are subject to Clean Water Act jurisdiction, but future regulatory developments and judicial rulings could potentially subject certain releases from CCR impoundments and landfills to additional permitting and remediation requirements, which could impose substantial costs. Any associated costs are expected to be subject to rate recovery. PPL, LG&E and KU are unable to predict the outcome or financial impact of future regulatory proceedings and litigation.
Waters of the United States
PPL, LG&E, and KU are subject to permitting and mitigation requirements for certain construction activities that impact “Waters of the United States.” On April 21, 2020, the EPA and U.S. Army Corps of Engineers published a final rule revising the definition of “Waters of the United Status” to exclude jurisdiction over certain surface waters. On August 30, 2021, a U.S. District Court in Arizona vacated and remanded the rule. On December 7, 2021, the EPA and U.S. Army Corps of Engineers proposed to repeal the rule and restore the definition of “Waters of the United States” that was in place prior to 2015. On January 24, 2022, the U.S. Supreme Court granted review of a case raising the issue of the appropriate scope of the definition of “Waters of the United States” under the Clean Water Act. PPL, LG&E and KU are unable to predict the outcome of current or future litigation or regulatory proceedings, but do not expect a material impact on operations.
Superfund and Other Remediation
(All Registrants)
From time to time, PPL's subsidiaries undertake testing, monitoring or remedial action in response to spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary to comply with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL's operations and undertake similar actions necessary to resolve environmental matters that arise in the course of normal operations. Based on analyses to date, resolution of these environmental matters is not expected to have a significant adverse impact on the operations of PPL common shares ownedElectric, LG&E and KU.
Future cleanup or remediation work at sites not yet identified may result in significant additional costs for the Registrants. Insurance policies maintained by PPL shareownersLG&E and KU may be available to cover certain of the costs or other obligations related to these matters, but the numberamount of shares of PPL common stock outstanding. The transaction is intended toinsurance coverage or reimbursement cannot be tax-free to PPL and its shareowners for U.S. federal income tax purposes.estimated or assured.
See “Legal Matters” in Note 814 to the Financial Statements for additional information.
(All Registrants)
SEASONALITY
The demand for and market prices of electricity and natural gas are affected by weather. As a result, the Registrants' operating results in the future may fluctuate substantially on a seasonal basis, especially when unpredictable weather conditions make such fluctuations more pronounced. The pattern of this fluctuation may change depending on the type and location of the facilities owned. See "Environmental Matters" in Note 13 to the Financial Statements"Item 1. Business - Environmental Matters - Air - Climate Change" for additional information regarding climate change.information.
FINANCIAL CONDITION
See "Financial Condition" in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" for this information.
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CAPITAL EXPENDITURE REQUIREMENTS
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" for information concerning projected capital expenditure requirements for 20182022 through 2022.2024. See Note 13 to the Financial Statements"Item 1. Business - Environmental Matters" for additional information concerning the potential impact on capital expenditures from environmental matters.
PPL, together with its subsidiaries, is committed to fostering an exceptional workplace for employees. PPL pledges to enable the success of its current and future workforce by cultivating a diverse, equitable and inclusive culture, fostering professional development, encouraging employee engagement, and ensuring a safe and healthy work environment. Matters related to these priorities and corporate culture are overseen by PPL's senior management, which provides updates to the PPL Board of Directors (the Board). Pursuant to its charter, the Compensation Committee of the Board of Directors also periodically reviews and assesses the Company’s strategy for human capital management. PPL's investment in the success of our workforce is embodied in the following areas with dedicated leadership and Board oversight:
•Diversity, equity and inclusion (DEI) – Foster an inclusive, respectful and diverse workplace through a comprehensive DEI strategy and commitments. Senior management reviews demographic metrics, DEI objectives and associated programs semi-annually. The RegistrantsBoard also receives periodic updates from senior management on PPL's DEI strategy and initiatives.
•Employee engagement – Create a workplace that fosters an engaged, high-quality workforce. PPL's operating companies regularly conduct assessments related to employee engagement, safety and culture. Senior management reviews corporate culture with the Board annually.
•Professional development –Invest in our current and future workforce through training and development, succession planning and creation of a pipeline for internal advancement. Senior management reviews succession planning with the Compensation Committee of the Board on an annual basis.
•Comprehensive benefits - In addition to challenging careers and competitive salaries, PPL offers competitive benefits programs to attract and retain talent and support employees' well-being. PPL offers competitive vacation time, expanded leave for new parents, retirement programs, and internal and external development opportunities, including tuition reimbursement offerings for undergraduate and certain graduate degrees. Senior management conduct annual benchmarking of employee compensation and benefits.
•Safety and Compliance - PPL is also committed to maintaining an ethical and safe workplace culture. Additional steps to ensure Board oversight in these areas include:
•Safety – PPL carries out programs focused on health and safety, including emergency preparedness, vehicle safety and accident prevention. Employees receive safety training and are subjectencouraged to certain existingshare, implement, and developing federal, regional, statefollow best practices. Senior management receives monthly safety data updates to determine whether additional safety measures should be implemented. The Board annually reviews the company's safety programs and local laws and regulations with respectresults. The Board is also immediately engaged in the event of a fatality.
•Compliance – The Corporate Compliance Committee, including senior executives, meets quarterly to air and water quality, land usediscuss metrics and other environmental matters. The EPA has issued numerous environmental regulations relating to air, water and waste that directly affect the electric power industry. 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" for information on projected environmental capital expenditures for 2018 through 2022. Also, see "Environmental Matters" in Note 13 to the Financial Statements for additional information and Note 6 to the Financial Statements for informationmatters related to the recoverycompliance and ethics culture. Among the items discussed are statistics regarding Ethics Helpline reports and employee concerns. This information is also reviewed with the Audit Committee of environmental compliance costs.the Board quarterly.
At December 31, 2017,2021, PPL and its subsidiaries had the following full-time employees and employees represented by labor unions.unions:
| Total Full-Time Employees | Number of Union Employees | Percentage of Total Workforce | |||||||||||||||
| PPL | 5,607 | 1,744 | 31 | % | |||||||||||||
| PPL Electric | 1,596 | 932 | 58 | % | |||||||||||||
| LG&E | 1,001 | 627 | 63 | % | |||||||||||||
| KU | 873 | 115 | 13 | % | |||||||||||||
Total Full-Time Employees | Number of Union Employees | Percentage of Total Workforce | ||||||
| PPL | 12,512 | 6,113 | 49 | % | ||||
| PPL Electric | 1,755 | 1,084 | 62 | % | ||||
| LKE | 3,470 | 782 | 23 | % | ||||
| LG&E | 986 | 660 | 67 | % | ||||
| KU | 910 | 122 | 13 | % | ||||
(PPL and PPL Electric)
For PPL and PPL Electric, labor agreement negotiations with the IBEW commenced in February 2022. The current five-year agreement expires in May 2022.
CYBERSECURITY MANAGEMENT
The Registrants and their subsidiaries are subject to risks from cyber-attacks that have the potential to cause significant interruptions to the operation of their businesses. The frequency of these attempted intrusions has increased in recent years and the sources, motivations and techniques of attack continue to evolve and change rapidly. PPL has undertakenadopted a variety of actionsmeasures to monitor and address cyber-related risks.risks and continues to implement and explore additional cybersecurity measures. Cybersecurity and the effectiveness of PPL’sPPL's cybersecurity strategy are regular topics of discussion at Board and Audit Committeeof Directors meetings. PPL's strategy for managing cyber-related risks is risk-based and, where appropriate, integrated within the company'sPPL's enterprise risk management processes. PPL’sPPL's Chief Information Security Officer (CISO), who reports directly to the Chief ExecutiveOperating Officer, leads a dedicated cybersecurity team and is responsible for the design, implementation, and execution of cyber-risk management strategy. AmongIn addition, among other things, the CISO and the cybersecurity team actively monitor the Registrants' systems, regularly review policies, compliance, regulations and best practices, perform penetration testing, leadconduct incident response exercises and internal ethical phishing campaigns, and provide training and communication across the organization to strengthen secure behavior.behavior and foster a culture of security. The cybersecurity team also routinely participates in industry-wide programs to further information sharing, intelligence gathering, and unity of effort in responding to potential or actual attacks. In addition, PPL has a formal internal policy and procedures for communicating cybersecurity incidents on an enterprise-wide basis.
In addition to these enterprise-wide initiatives, PPL’sPPL's Kentucky and Pennsylvania operations are subject to extensive and rigorous mandatory cybersecurity requirements that are developed and enforced by NERC and approved by the FERC to protect grid security and reliability. LG&E is also subject to certain security directives related to cybersecurity issued by the Department of Homeland Security’s Transportation Security Administration in 2021. See Note 14 to the Financial Statements for additional information on these directives. Finally, PPL purchases insurance to protect against a wide range of costs that could be incurred in connection with cyber-related incidents. There can be no assurance, however, that these efforts will be effective to prevent interruption of services or other damage to the Registrants' businesses or operations or that PPL's insurance coverage will cover all costs incurred in connection with any cyber-related incident.
AVAILABLE INFORMATION
PPL's Internet website is www.pplweb.com. Under the Investors heading of that website, PPL provides access to all SEC filings of the Registrants (including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to these reports filed or furnished pursuant to Section 13(d) or 15(d)) free of charge, as soon as reasonably practicable after filing with the SEC. The information contained on, or available through, PPL's Internet website is not, and shall not be deemed to be, incorporated by reference into this report. Additionally, the Registrants' filings are available at the SEC's website (www.sec.gov) and at the SEC's Public Reference Room at 100 F Street, NE, Washington, DC 20549, or by calling 1-800-SEC-0330..
ITEM 1A. RISK FACTORS
The Registrants face various risks associated with their businesses. Our businesses, financial condition, cash flows or results of operations could be materially adversely affected by any of these risks. In addition, this report also contains forward-looking and other statements about our businesses that are subject to numerous risks and uncertainties. See "Forward-Looking Information," "Item 1. Business," "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" and Note 1314 to the Financial Statements for moreadditional information concerning the risks described below and for other risks, uncertainties and factors that could impact our businesses and financial results.
As used in this Item 1A., the terms "we," "our" and "us" generally refer to PPL and its consolidated subsidiaries taken as a whole, or PPL Electric and its consolidated subsidiaries taken as a whole within the Pennsylvania Regulated segment discussion or LKE and its consolidated subsidiaries taken as a whole within the Kentucky Regulated segment discussion.
Order of Subsection Presentation
A.Risks Related to Registrant Holding Company
B.Risks Related to Regulated Utility Operations
C.Risks Specific to Kentucky Regulated Segment
D.Risks Specific to Pennsylvania Regulated Segment
E.Risks Related to All Segments
(PPL)
PPL is a holding company and political conditions and policiesconducts its operations primarily through subsidiaries. Substantially all of the U.K. governmentconsolidated assets of PPL are held by its subsidiaries. Accordingly, PPL's cash flows and ability to meet debt and guaranty obligations, as well as PPL's ability to pay dividends, are largely dependent upon the earnings of those subsidiaries and the European Union. These risks may adversely impact the results of operations of our U.K. distribution business or affect our ability to access U.K. revenues forother payment of distributions or for other corporate purposessuch earnings in the U.S.
Because PPL is a holding company, its debt and lackguaranty obligations are effectively subordinated to all existing and future liabilities of localits subsidiaries. Although certain agreements to which certain subsidiaries are parties limit their ability to incur additional indebtedness, PPL and its subsidiaries retain the ability to incur substantial additional indebtedness and other liabilities. Therefore, PPL's rights and the rights of its creditors, including rights of debt holders, to participate in the assets of any of its subsidiaries, in the event that such a subsidiary is liquidated or reorganized, will be subject to the prior claims of such subsidiary's creditors.
(All Registrants)
B. Risks Related to Regulated Utility Operations
Our regulated utility businesses face many of the same risks, in addition to those risks that are unique to each of the Kentucky Regulated and Pennsylvania Regulated segments. Set forth below are risk factors common to both domestic regulated segments, followed by sections identifying separately the risks specific to each of these segments.
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Our profitability is highly dependent on our ability to recover the costs of providing energy and utility services to our customers and earn an adequate return on our capital or loans;
The rates we charge our utility customers must be approved by the U.K. of its intent to withdraw from the European Union.
Our utility businesses are subject to significant and complex governmentalregulation.
In addition to regulating the rates we charge, various federal and state regulatory authorities regulate many aspects of our domestic utility operations, including:
•the terms and conditions of our service and operations;
•financial and capital structure matters;
•siting, construction and operation of facilities;
•mandatory reliability and safety standards under the withdrawal. PPLEnergy Policy Act of 2005 and other standards of conduct;
•accounting, depreciation and cost allocation methodologies;
•tax matters;
•affiliate transactions;
•acquisition and disposal of utility assets and issuance of securities; and
•various other matters, including energy efficiency.
Such regulations or changes thereto may subject us to higher operating costs or increased capital expenditures and failure to comply could result in sanctions or possible penalties which may not be recoverable from customers.
Our regulated businesses undertake significant capital projects and these activities are subjectto unforeseen costs, delays or failures, as well as risk of inadequate recovery ofresulting costs.
The regulated utility businesses are capital intensive and require significant investments in energy generation (in the case of LG&E and KU) and transmission, distribution and other infrastructure projects, such as projects for environmental compliance and system reliability. The completion of these projects without delays or cost overruns is subject to risks in many areas, including:
•approval, licensing and permitting;
•land acquisition and the availability of suitable land;
•skilled labor or equipment shortages;
•construction problems or delays, including disputes with third-party intervenors;
•increases in commodity prices or labor rates;
•potential supply chain disruptions or delays; and
•contractor performance.
Failure to complete our capital projects on schedule or on budget, or at all, could adversely affect our financial performance, operations and future growth if such expenditures are not granted rate recovery by our regulators.
We are or may be subject to costs of remediation of environmental contamination at facilities owned or operated by our former subsidiaries.
We may be subject to liability for the costs of environmental remediation of property now or formerly owned by us with respect to substances that we may have generated regardless of whether the liabilities arose before, during or after the time we owned or operated the facilities. We also have current or previous ownership interests in sites associated with the production of
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manufactured gas for which we may be liable for additional costs related to investigation, remediation and monitoring of these sites. Remediation activities associated with our former manufactured gas plant operations are one source of such costs. Citizen groups or others may bring litigation regarding environmental issues including claims of various types, such as property damage, personal injury and citizen challenges to compliance decisions on the enforcement of environmental requirements, which could subject us to penalties, injunctive relief and the cost of litigation. We cannot predict the impact, in eitheramount and timing of future expenditures (including the short-termpotential or long-term, on foreign exchange ratesmagnitude of fines or PPL’s long-term financial condition that may be experienced as a result of the actions taken by the U.K. governmentpenalties) related to withdraw from the European Union,such environmental matters, although such impactsthey could be significant.material.
C. Risks Specific to Kentucky Regulated Segment
(PPL, LG&E and KU)
We are subject to foreign currency exchange ratefinancial, operational, regulatory and other risks because a significant portion of our cash flowsrelated to requirements, developments and reported earningsuncertainties in environmental regulation, including those affecting coal-fired generation facilities.
Extensive federal, state and local environmental laws and regulations are currently generated by our U.K. business operations.
We are subject to revenue variability based on operational, performance.regulatory and other risks regarding natural gas supply infrastructure.
A failure by any of our U.K. regulated businesses to comply with the terms ofnatural gas pipeline explosion or associated incident could have a distribution license may lead to the issuance of an enforcement order by Ofgemsignificant impact on LG&E’s natural gas operations or result in significant damages and penalties that could have an adverse impact on PPL.
D. Risks Specific to Pennsylvania Regulated Segment
(PPL and PPL Electric)
We face competition for transmission projects, which could adversely affect our rate base growth.
FERC Order 1000, issued in July 2011, establishes certain procedural and substantive requirements relating to participation, cost allocation and non-incumbent developer aspects of regional and inter-regional electricity transmission planning activities. The PPL Electric transmission business, operating under a FERC-approved PJM Open Access Transmission Tariff, is subject to
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competition pursuant to FERC Order 1000 from entities that are not incumbent PJM transmission owners with respect to the operationsconstruction and financial conditionownership of transmission facilities within PJM. Increased competition can result in lower rate base growth.
We could be subject to higher costs and/or penalties related to Pennsylvania Conservation and Energy Efficiency Programs.
PPL Electric is subject to Act 129, which contains requirements for energy efficiency and conservation programs and for the U.K. regulated businessesuse of smart metering technology, imposes PLR electricity supply procurement rules, provides remedies for market misconduct, and PPL.made changes to the existing Alternative Energy Portfolio Standard. The law also requires electric utilities to meet specified goals for reduction in customer electricity usage and peak demand. Utilities not meeting these Act 129 requirements are subject to significant penalties that cannot be recovered in rates. Numerous factors outside of our control could prevent compliance with these requirements and result in penalties to us.
E. Risks Related to All Segments
(All Registrants)
The operationCOVID-19 pandemic and resultant impact on business and economic conditions could negatively affect our business.
The COVID-19 pandemic has disrupted the U.S. and global economies and continues to present challenges to businesses, communities, workforces, markets and increasingly to supply chains. In the U.S. and throughout the world, governmental authorities have taken actions to contain the spread of the virus and mitigate known or foreseeable impacts. In the Registrants’ service territories, mitigation measures have included quarantines, stay-at-home orders, travel restrictions, reduced operations orclosures of businesses, schools and governmental agencies, and executive, legislative or regulatory actions to address health or other pandemic-related concerns. The Delta and Omicron variants of the virus have extended and exacerbated the risks arising from the pandemic and have led to the extension of many of these remediation strategies. The responses to these variants may continue to affect risks and related remediation efforts going forward, perhaps substantially, and future variants may have similar effects.
Until the COVID-19 virus is contained, it poses significant risks to the health and welfare of the Registrants’ customers, employees, contractors and suppliers, and to the conduct of their business. Mandates to stay at home, shelter in place, or quarantine and resulting lock-down or closures of non-essential businesses could reduce demand for electricity and gas, and continue to cause shifts in demand between residential, commercial and industrial customers that could negatively impact the Registrants’ financial condition. Customers experiencing financial strain from unemployment, furloughs, or reduced work hours may not be able to pay their bills on a timely basis, which could negatively impact our businessesliquidity. New or changing legislation or regulatory orders may unfavorably impact the Registrants or the utility industry generally.
The COVID-19 pandemic is also subjecting the Registrants to growing shortages that are creating risks of potential equipment and fuel supply chain disruptions. If issues in the supply chains continue, Registrants may be forced to rely on a larger pool of suppliers, which could pose operational risks. Such suppliers may fail to follow established health, safety and other regulatory standards. Additionally, suppliers may need to engage subcontractors that have not been previously vetted, which could result in contractual and regulatory risks. This could also create an inability to effectively monitor a supplier’s work or the need to depend on limited contractors, resulting in higher costs and potential financial and reputational risks.
All of these factors have the potential to materially and adversely affect the Registrants’ business and operations, especially if they remain in effect for a prolonged period of time. At this time, the Registrants’ cannot predict the extent to which these or other pandemic-related factors may affect their business, earnings or other financial results, as it depends on the duration and scope of the outbreak, the measures undertaken in response and other future developments, all of which are highly uncertain and continue to evolve in response to additional variants. In addition to the factors discussed above, investors should be aware that other COVID-19-related risks may emerge in the future and may prove to be significant, including potentially the cost of ongoing remediation efforts, such as testing, and the potential for increased effects on global markets and supply chains. Investors should carefully consider the discussion of COVID-19 related items presented in this Annual Report on Form 10-K, especially to the extent that the COVID-19 pandemic may exacerbate or increase those risks.
Our business operations are continually subject to cyber-based security and data integrity risks.risks from vulnerabilities related to our IT systems, operational technology infrastructure and supply chain relationships.
Numerous functions affecting the efficient operation of our businesses are dependent on the secure and reliable storage, processing and communication of electronic data and the use of sophisticated computer hardware and software systems. The operation of our transmission and distribution operations,systems, including gas distribution systems, as well as our generation plants, are all reliant on cyber-based technologies and, therefore, subject to the risk that suchthese systems could be the target of disruptive
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actions principally by terrorists, nation state actors or criminals or otherwise be compromised by unintentional events. Attacks may come through ransomware, software updates or patches, use of opensource software, firmware that hackers can manipulate to include malicious codes for exploitation at a later date, orthe compromising of hardware by bad actors, creating serious risks to our security, the security of our customers' information, and potentially to our ability to provide power. As a result, operations could be interrupted, property could be damaged and sensitive customer information lost or stolen, causing us to incur significant losses of revenues, other substantial liabilities and damages, costs to replace or repair damaged equipment and damage to our reputation. Threats to our systems and operations continue to emerge as new ways to compromise components of our systems or networks are developed. Additionally, cybersecurity risks also threaten our supply chains, including aspects that are not under our control, such as the incorporation of opensource software in systems or software that we use, that despite our efforts do not meet our current security standards.
In addition, under the Energy Policy Act of 2005, users, owners and operators of the bulk power transmission system, including PPL Electric, LG&E and KU, are subject to mandatory reliability standards promulgated by NERC and SERC and enforced by the FERC. As thean operator of natural gas distribution systems, LG&E is also subject to mandatory reliability standards of the U.S. Department of Transportation.Transportation and is also subject to certain security directives related to cybersecurity issued by the Department of Homeland Security (DHS) Transportation Security Administration (TSA) in 2021. Failure to comply with suchthese standards could result in the imposition of fines or civil penalties, and potential exposure to third party claims for alleged violations of suchthe standards.
We are subject to risks associated with federal and state tax laws and regulations.
Changes in tax law including the recent enactment of the TCJA, as well as the inherent difficulty in quantifying potential tax effects of business decisions could negatively impact our results of operations.operations and cash flows. We are required to make judgments in order to estimate our obligations to taxing authorities. These tax obligations include income, property, gross receipts, franchise, sales and use, employment-related and other taxes. We also estimate our ability to utilize deferred tax benefitsassets and tax credits. Due toDependent upon the revenue needs of the jurisdictions in which our businesses operate, various tax and fee increases may be proposed or considered. We cannot predict changes in tax law or regulation or the effect of any such changes on our businesses. Any such changes could increase tax expense and could have a significant negative impact on our results of operations and cash flows.
The TCJA had a significant impact on our 2017 financial statements and expected future operating cash flows. We have completed or made reasonable estimates of the effects of the TCJA have been reflected in our December 31, 2017 financial statements, butand we continue to evaluate the application of various components of the law in the calculation ofcalculating income tax expense.
Increases in electricity prices and/or a weak economy, can lead to changes in legislative and regulatory policy, including the promotion of energy efficiency, conservation and distributed generation or self-generation, which may adversely impact our business.
Energy consumption is significantly impacted by overall levels of economic activity and costs of energy supplies. Economic downturns or periods of high energy supply costs can lead to changes in or the development of legislative and regulatory policy designed to promote reductions in energy consumption and increased energy efficiency, alternative and renewable energy sources, and distributed or self-generation by customers. This focus on conservation, energy efficiency and self-generation may result in a decline in electricity demand, which could adversely affect our business.
We could be negatively affected by rising interest rates, downgrades to our credit ratings, adverse credit market conditions or other negative developments in our ability to access capital markets.
A downgrade in our credit ratings could negatively affect our ability to access capital and increase the cost of maintaining our credit facilities and any new debt.
Credit ratings assigned by Moody's and S&P to our businesses and their financial obligations have a significant impact on the cost of capital incurred by our businesses. A ratings downgrade could increase our short-term borrowing costs and negatively affect our ability to fund liquidity needs and access new long-term debt at acceptable interest rates. See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - Ratings Triggers" for additional information on the financial impact of a downgrade in our credit ratings.
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Our operating revenues could fluctuate on a seasonal basis, especially as a result of extreme weather conditions.conditions, including conditions caused or exacerbated by climate change.
Our businesses are subject to seasonal demand cycles. For example, in some markets demand for, and market prices of, electricity peak during hot summer months, while in other markets such peaks occur in cold winter months. As a result, our overall operating results may fluctuate substantially on a seasonal basis if weather conditions diverge adversely from seasonal norms. The effects of climate change may accelerate or magnify fluctuations in our operating results.
Operating expenses could be affected by weather conditions, including storms, as well as by significant man-made or accidentaldisturbances, including terrorism or natural disasters.
Weather and these other factors can significantly affect our profitability or operations by causing outages, damaging infrastructure and requiring significant repair costs. Storm outages and damage often directly decrease revenues and increase expenses, due to reduced usage and restoration costs.
Our businesses are subject to physical, market and economic risks relating to potentialeffects of climate change.
Climate change may produce changes in weather or other environmental conditions, including temperature or precipitation levels, and thus may impact consumer demand for electricity. In addition, the potential physical effects of climate change, such as increased frequency and severity of storms, floods, and other climatic events, could disrupt our operations and cause us to incur significant costs to prepare for or respond to these effects. These or other meteorological changes could lead to increased operating costs, capital expenses or power purchase costs. Greenhouse gas regulation could increase the cost of electricity, particularly power generated by fossil fuels, and such increases could have a depressive effect on regional economies. Reduced economic and consumer activity in our service areas -- both generally and specific to certain industries and consumers accustomed to previously lower cost power -- could reduce demand for the power we generate, market and deliver. Also, demand for our energy-related services could be similarly lowered by consumers' preferences or market factors favoring energy efficiency, low-carbon power sources or reduced electricity usage. The Registrants' responses to such climate-related risks include compliance with evolving governmental policy and developing and implementing strategies designed to meet net zero carbon emissions goals, which may affect our financial condition, results of operations or cash flows.
We cannot predict the outcome of the legal proceedings andor investigations currently being conducted with respectrelated to our current and past business activities.businesses in which we are periodically involved. An adverseunfavorable outcome or determination in any of these matters could have a material adverse effect on our financial condition, results of operations or cash flows.
We are involved in legal proceedings, claims and litigation and periodically are subject to ongoing state and federal investigations arising out of our business operations, the most significant of which are summarized in "FederalItem 1. Business and "Regulatory Matters" in Note 67 to the Financial Statements and in "Legal Matters,"Matters" and "Regulatory Issues" and "Environmental Matters" in Note 1314 to the Financial Statements. We cannot predict the ultimate outcome of these matters, nor can we reasonably estimate the costs or liabilities that could potentially result from a negative outcome in each case.
Significant increases in our operation and maintenance expenses, including health care and pension costs, could adversely affect our future earnings and liquidity.
We continually focus on limiting and reducing our operation and maintenance expenses. However, we expect to continue to face increased cost pressures in our operations. Increased costs of materials and labor may result from general inflation, increased regulatory requirements (especially in respect of environmental regulations), the need for higher-cost expertise in the workforce or other factors. In addition, pursuant to collective bargaining agreements, we are contractually committed to provide specified levels of health care and pension benefits to certain current employees and retirees. These benefits give rise to significant expenses. Due to general inflation with respect to such costs, the aging demographics of our workforce and other factors, we have experienced significant health care cost inflation in recent years, and we expect our health care costs, including prescription drug coverage, to continue to increase despite measures that we have taken and expect to take to require employees and retirees to bear a higher portion of the costs of their health care benefits. In addition, we expect to continue to incur significant costs with respect to the defined benefit pension plans for our employees and retirees. The measurement of our expected future health care and pension obligations, costs and liabilities is highly dependent on a variety of assumptions, most of which relate to factors beyond our control. These assumptions include investment returns, interest rates, health care cost trends, inflation rates, benefit improvements, salary increases and the demographics of plan participants. If our assumptions prove to be inaccurate, our future costs and cash contribution requirements to fund these benefits could increase significantly.
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We may incur liabilities in connection with discontinued operations.divestitures.
In connection with various divestitures, and certain other transactions, we have indemnified or guaranteed parties against certain liabilities. These indemnities and guarantees relate, among other things, to liabilities which may arise with respect to the period during which we or our subsidiaries operated a divested business, and to certain ongoing contractual relationships and entitlements with respect to which we or our subsidiaries made commitments in connection with the divestiture. See "Guarantees and Other Assurances" in Note 1314 to the Financial Statements.
We are subject to liability risks relating to our generation,transmission and distribution operations.
The conduct of our physical and commercial operations subjects us to many risks, including risks of potential physical injury, property damage or other financial liability, caused to or by employees, customers, contractors, vendors, contractual or financial counterparties and other third parties.
Our facilities may not operate as planned, which may increase our expenses and decrease our revenues and have an adverse effect on our financial performance.
Operation of power plants, transmission and distribution facilities, information technology systems and other assets and activities subjects us to a variety of risks, including the breakdown or failure of equipment, accidents, security breaches, viruses or outages affecting information technology systems, labor disputes, obsolescence, delivery/transportation problems and disruptions of fuel supply and performance below expected levels. These events may impact our ability to conduct our businesses efficiently and lead to increased costs, expenses or losses. Operation of our delivery systems below our expectations may result in lost revenue and increased expense, including higher maintenance costs, which may not be recoverable from customers. Planned and unplanned outages at our power plants may require us to purchase power at then-current market prices to satisfy our commitments or, in the alternative, pay penalties and damages for failure to satisfy them.
Although we maintain customary insurance coverage for certain of these risks, we do not carry insurance for all of these risks and no assurance can be given that such insurance coverage will be sufficient to compensate us in the event losses occur.
We are required to obtain, and to comply with, government permits and approvals.
We are required to obtain, and to comply with, numerous permits, approvals, licenses and certificates from governmental agencies. The process of obtaining and renewing necessary permits can be lengthy and complex and can sometimes result in the establishment of permit conditions that make the project or activity for which thea permit was sought unprofitable or otherwise unattractive. In addition, such permits or approvals may be subject to denial, revocation or modification under various circumstances. Failure to obtain or comply with the conditions of permits or approvals, or failure to comply with any applicable laws or regulations, may result in the delay or temporary suspension of our operations and electricity sales or the curtailment of our power delivery and may subject us to penalties and other sanctions. Although various regulators routinely renew existing licenses, renewal could be denied or jeopardized by various factors, including failure to provide adequate financial assurance for closure; failure to comply with environmental, health and safety laws and regulations or permit conditions; local community, political or other opposition; and executive, legislative or regulatory action.
Our cost or inability to obtain and comply with the permits and approvals required for our operations could have a material adverse effect on our operations and cash flows. In addition, new environmental legislation or regulations, if enacted, or changed interpretations of existing laws may elicit claims that historical routine modification activities at our facilities violated applicable laws and regulations. In addition to the possible imposition of fines in such cases, we may be required to undertake significant capital investments in pollution control technology and obtain additional operating permits or approvals, which could have an adverse impact on our business, results of operations, cash flows and financial condition.
War, other armed conflicts or terrorist attacks could have a material adverse effect on our business.
War, terrorist attacks and unrest have caused and may continue to cause instability in the world's financial and commercial markets and have contributed to high levels of volatility in prices for oil and gas.markets. In addition, unrest in the Middle East could lead to acts of terrorism in the United States the United Kingdom or elsewhere, and acts of terrorism could be directed against companies such as ours. Armed conflicts and terrorism and their effects on us or our markets may significantly affect our business and results of operations in the future. In addition, we may incur increased costs for security, including additional physical plant security and security personnel or additionalincreased capability following a terrorist incident.
21
We are subject to counterparty performance, credit or other risk in theirthe provision of goods or services to us, which could adversely affect our ability to operate our facilities or conduct business activities.
We purchase from a variety of suppliers energy, capacity, fuel, natural gas, transmission service and certain commodities used in the physical operation of our businesses, as well as goods or services, including information technology rights and services, used in the administration of our businesses. Delivery of these goods and services is dependent on the continuing operational performance and financial viability of our contractual counterparties and also the markets, infrastructure or third-partiesthird parties they use to provide such goods and services to us. As a result, we are subject to the risks of disruptions, curtailments or increased costs in the operation of our businesses if such goods or services are unavailable or become subject to price spikes or if a counterparty fails to perform. Such disruptions could adversely affect our ability to operate our facilities or deliver our services and collect our revenues, which could result in lower sales and/or higher costs and thereby adversely affect our results of operations. The performance of coal markets and producers may be the subject of increased counterparty risk to LKE, LG&E and KU currently due to weaknesses in such markets and suppliers. The coal industry is subject to increasing competitive pressures from natural gas markets, political pressures and new or more stringent environmental regulation, including greenhouse gases or other air emissions,regulation of combustion byproducts and water inputs or discharges. Consequently, the coal industry faces increased production costs or closed customer markets.
We are subject to the risk that our workforce and its knowledge base may become depleted in coming years.
We are experiencing an increase inexperience attrition due primarily to the number of retiring employees, with the risk that critical knowledge will be lost and that it may be difficult to replace departed personnel, and to attract and retain new personnel, with appropriate skills and experience, due to a declining trend in the number of available skilled workers and an increase in competition for such workers.
ITEM 1B. UNRESOLVED STAFF COMMENTS
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
None.
22
ITEM 2. PROPERTIES
Kentucky Regulated Segment(PPL, LKE, LG&E and KU)
LG&E's and KU's properties consist primarily of regulated generation facilities, electricity transmission and distribution assets and natural gas transmission and distribution assets in Kentucky. The capacity of generation units is based on a number of factors, including the operating experience and physical condition of the units, and may be revised periodically to reflect changed circumstances. The electricity generating capacity at December 31, 20172021 was:
| LKE | LG&E | KU | LG&E | KU | ||||||||||||||||||||||||||||||||||||||||
| Primary Fuel/Plant | Total MW Capacity Summer | Ownership or Other Interest in MW | % Ownership or Other Interest | Ownership or Other Interest in MW | % Ownership or Other Interest | Ownership or Other Interest in MW | Primary Fuel/Plant | Total MW Capacity Summer | % Ownership or Other Interest | Ownership or Other Interest in MW | % Ownership or Other Interest | Ownership or Other Interest in MW | ||||||||||||||||||||||||||||||||
| Coal | Coal | |||||||||||||||||||||||||||||||||||||||||||
| Ghent - Units 1- 4 | 1,919 | 1,919 | 100.00 | 1,919 | Ghent - Units 1- 4 | 1,919 | 100.00 | 1,919 | ||||||||||||||||||||||||||||||||||||
| Mill Creek - Units 1- 4 | 1,465 | 1,465 | 100.00 | 1,465 | Mill Creek - Units 1- 4 | 1,465 | 100.00 | 1,465 | ||||||||||||||||||||||||||||||||||||
| E.W. Brown - Units 1-3 | 681 | 681 | 100.00 | 681 | ||||||||||||||||||||||||||||||||||||||||
| E.W. Brown - Unit 3 | E.W. Brown - Unit 3 | 412 | 100.00 | 412 | ||||||||||||||||||||||||||||||||||||||||
| Trimble County - Unit 1 (a) | 493 | 370 | 75.00 | 370 | Trimble County - Unit 1 (a) | 493 | 75.00 | 370 | ||||||||||||||||||||||||||||||||||||
| Trimble County - Unit 2 (a) | 732 | 549 | 14.25 | 104 | 60.75 | 445 | Trimble County - Unit 2 (a) | 732 | 14.25 | 104 | 60.75 | 445 | ||||||||||||||||||||||||||||||||
| OVEC - Clifty Creek (b) | 1,164 | 95 | 5.63 | 66 | 2.50 | 29 | ||||||||||||||||||||||||||||||||||||||
| OVEC - Kyger Creek (b) | 956 | 78 | 5.63 | 54 | 2.50 | 24 | ||||||||||||||||||||||||||||||||||||||
| 7,410 | 5,157 | 2,059 | 3,098 | 5,021 | 1,939 | 2,776 | ||||||||||||||||||||||||||||||||||||||
| Natural Gas/Oil | Natural Gas/Oil | |||||||||||||||||||||||||||||||||||||||||||
| E.W. Brown Unit 5 (c) | 130 | 130 | 53.00 | 69 | 47.00 | 61 | ||||||||||||||||||||||||||||||||||||||
| E.W. Brown Unit 5 (b) | E.W. Brown Unit 5 (b) | 130 | 53.00 | 69 | 47.00 | 61 | ||||||||||||||||||||||||||||||||||||||
| E.W. Brown Units 6 - 7 | 292 | 292 | 38.00 | 111 | 62.00 | 181 | E.W. Brown Units 6 - 7 | 292 | 38.00 | 111 | 62.00 | 181 | ||||||||||||||||||||||||||||||||
| E.W. Brown Units 8 - 11 (c) | 484 | 484 | 100.00 | 484 | ||||||||||||||||||||||||||||||||||||||||
| E.W. Brown Units 8 - 11 (b) | E.W. Brown Units 8 - 11 (b) | 484 | 100.00 | 484 | ||||||||||||||||||||||||||||||||||||||||
| Trimble County Units 5 - 6 | 318 | 318 | 29.00 | 92 | 71.00 | 226 | Trimble County Units 5 - 6 | 318 | 29.00 | 92 | 71.00 | 226 | ||||||||||||||||||||||||||||||||
| Trimble County Units 7 - 10 | 636 | 636 | 37.00 | 235 | 63.00 | 401 | Trimble County Units 7 - 10 | 636 | 37.00 | 235 | 63.00 | 401 | ||||||||||||||||||||||||||||||||
| Paddy's Run Units 11 - 12 | 35 | 35 | 100.00 | 35 | ||||||||||||||||||||||||||||||||||||||||
| Paddy's Run Unit 12 | Paddy's Run Unit 12 | 23 | 100.00 | 23 | ||||||||||||||||||||||||||||||||||||||||
| Paddy's Run Unit 13 | 147 | 147 | 53.00 | 78 | 47.00 | 69 | Paddy's Run Unit 13 | 147 | 53.00 | 78 | 47.00 | 69 | ||||||||||||||||||||||||||||||||
| Haefling - Units 1 - 2 | 24 | 24 | 100.00 | 24 | Haefling - Units 1 - 2 | 24 | 100.00 | 24 | ||||||||||||||||||||||||||||||||||||
| Zorn Unit | 14 | 14 | 100.00 | 14 | ||||||||||||||||||||||||||||||||||||||||
| Cane Run Unit 7 | 662 | 662 | 22.00 | 146 | 78.00 | 516 | Cane Run Unit 7 | 662 | 22.00 | 146 | 78.00 | 516 | ||||||||||||||||||||||||||||||||
| Cane Run Unit 11 | 14 | 14 | 100.00 | 14 | ||||||||||||||||||||||||||||||||||||||||
| 2,756 | 2,756 | 794 | 1,962 | 2,716 | 754 | 1,962 | ||||||||||||||||||||||||||||||||||||||
| Hydro | Hydro | |||||||||||||||||||||||||||||||||||||||||||
| Ohio Falls - Units 1-8 | 64 | 64 | 100.00 | 64 | Ohio Falls - Units 1-8 | 64 | 100.00 | 64 | ||||||||||||||||||||||||||||||||||||
| Dix Dam - Units 1-3 | 32 | 32 | 100.00 | 32 | Dix Dam - Units 1-3 | 32 | 100.00 | 32 | ||||||||||||||||||||||||||||||||||||
| 96 | 96 | 64 | 32 | 96 | 64 | 32 | ||||||||||||||||||||||||||||||||||||||
| Solar | Solar | |||||||||||||||||||||||||||||||||||||||||||
| E.W. Brown Solar (d) | 8 | 8 | 39.00 | 3 | 61.00 | 5 | ||||||||||||||||||||||||||||||||||||||
| E.W. Brown Solar (c) | E.W. Brown Solar (c) | 8 | 39.00 | 3 | 61.00 | 5 | ||||||||||||||||||||||||||||||||||||||
| Total | 10,270 | 8,017 | 2,920 | 5,097 | Total | 7,841 | 2,760 | 4,775 | ||||||||||||||||||||||||||||||||||||
(a)Trimble County Unit 1 and Trimble County Unit 2 are jointly owned with Illinois Municipal Electric Agency and Indiana Municipal Power Agency. Each owner is entitled to its proportionate share of the units' total output and funds its proportionate share of capital, fuel and other operating costs. See Note 13 to the Financial Statements for additional information.
(b)There is an inlet air cooling system attributable to these units. This inlet air cooling system is not jointly owned; however, it is used to increase production on the units to which it relates, resulting in an additional 12 MW of capacity for LG&E and an additional 86 MW of capacity for KU.
(c)This unit is a 10 MW facility and achieves such production. The 8 MW solar facility summer capacity rating is reflective of an average expected output across the peak hours during the summer period based on average weather conditions at the solar facility.
For a description of LG&E's and KU's service areas, see "Item 1. Business - General - Segment Information - Kentucky Regulated Segment." At December 31, 2017,2021, LG&E's and KU's electricity transmission system included in the aggregate, 45 substations (31 of which are shared with theand distribution system) with a total capacity of 8 million kVAsystems and 669 pole miles of lines. LG&E's distribution system included 97 substations (31 of which are shared with the transmission system) with a total capacity of 5 million kVA, 3,892 circuit miles of overhead lines and 2,553 underground cable miles. KU's transmission system included 142 substations (60 of which are shared with the distribution system) with a total capacity of 14 million kVA and 4,066 pole miles of lines. KU's distribution system included 469 substations (60 of which are shared with the transmission system) with a total capacity of 7 million kVA, 14,016circuit miles of overhead lines and2,484underground cable miles.
LG&E's natural gas transmission system includes 4,310 milesand distribution systems were:
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| LG&E | KU | |||||||||||||||||||||||||
| Distribution | Transmission | Distribution | Transmission | |||||||||||||||||||||||
| Electricity System | ||||||||||||||||||||||||||
| Substations (a) | 96 | 77 | 460 | 211 | ||||||||||||||||||||||
| Capacity (in millions of kVA) | 5 | 8 | 8 | 15 | ||||||||||||||||||||||
| Overhead lines (circuit miles) | 3,883 | 669 | 14,046 | 4,056 | ||||||||||||||||||||||
| Underground lines (circuit miles) | 2,753 | — | 2,699 | — | ||||||||||||||||||||||
| Natural Gas System | ||||||||||||||||||||||||||
| Distribution mains (miles) | 4,418 | — | — | — | ||||||||||||||||||||||
| Transmission pipeline (miles) | — | 233 | — | — | ||||||||||||||||||||||
| Transmission storage lines (miles) | — | 118 | — | — | ||||||||||||||||||||||
| Combustion turbine lines (miles) | — | 19 | — | 12 | ||||||||||||||||||||||
| Storage fields | — | 5 | — | — | ||||||||||||||||||||||
| Storage field capacity (Bcf) | — | 15 | — | — | ||||||||||||||||||||||
(a)191 substations (61 at LG&E and 130 at KU) are shared between the distribution mains and 396 miles of gas transmission mains, consisting of 260 miles of gas transmission pipeline, 117 miles of gas transmission storage lines, 18 miles of gas combustion turbine lines and one mile of gas transmission pipeline in regulator facilities. Five underground natural gas storage fields, with a total working natural gas capacity of approximately 15 Bcf, are used in providing natural gas service to ultimate consumers. KU's service area includes an additional 11 miles of gas transmission pipeline providing gas supply to natural gas combustion turbine electricity generating units.systems.
Substantially all of LG&E's and KU's respective real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and, in the case of LG&E, the storage and distribution of natural gas, is subject to the lien of either the LG&E 2010 Mortgage Indenture or the KU 2010 Mortgage Indenture. See Note 78 to the Financial Statements for additional information.
LG&E and KU continuously reexamine development projects based on market conditions and other factors to determine whether to proceed with the projects, sell, cancel or expand them or pursue other options. In 2016,See Item 1. Business for a discussion related to LG&E&E's and KU received approval from the KPSC to develop a 4 MW solar share facility to service a solar shareKU's Solar Share program. The solar share program is an optional, voluntary program that allows customers to subscribe capacity in the solar share facility. Construction is expected to begin, in 500-kilowatt phases, when subscription is complete. As of December 31, 2017, LG&E and KU have not yet constructed the first solar share facility and are actively marketing the program and continue to receive interest from customers.
Pennsylvania Regulated Segment(PPL and PPL Electric)
For a description of PPL Electric's service territory,area, see "Item 1. Business - General - Segment Information - Pennsylvania Regulated Segment." PPL Electric has electric transmission and distribution lines in public streets and highways pursuant to franchises and rights-of-way secured from property owners. At December 31, 2017,2021, PPL Electric's transmission system includes 4951 substations with a total capacity of 2831 million kVA and 5,400 circuit miles in service. PPL Electric's distribution system includes 351352 substations with a total capacity of 14 million kVA, 37,19536,488 circuit miles of overhead lines and 8,5498,714 underground circuit miles. All of PPL Electric's facilities are located in Pennsylvania. Substantially all of PPL Electric's distribution properties and certain transmission properties are subject to the lien of the PPL Electric 2001 Mortgage Indenture. See Note 78 to the Financial Statements for additional information.
ITEM 3. LEGAL PROCEEDINGS
See Notes 5, 6, 7, 9 and 1314 to the Financial Statements for information regarding legal, tax litigation,and regulatory matters and environmental proceedings and matters.proceedings.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
24
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY,
RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES
See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Liquidity and Capital Resources - Forecasted Uses of Cash" for information regarding certain restrictions on the ability to pay dividends for all Registrants.
PPL Corporation
Additional information for this item is set forth in the sections entitled "Quarterly Financial, Common Stock Price and Dividend Data," "Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters" and "Shareowner and Investor Information" of this report. At January 31, 2018,2022 there were 55,40948,597 common stock shareowners of record.
| Period | Total Number of Shares (or Units) Purchased | Average Price Paid per Share (or Unit) | Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs | Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs (a) | |||||||||||||||||||
| October 1 to October 31, 2021 | 8,257,699 | $ | 28.60 | 8,257,699 | $ | 2,450,000,033 | |||||||||||||||||
| November 1 to November 30, 2021 | 11,453,324 | 28.65 | 11,453,324 | 2,121,807,982 | |||||||||||||||||||
| December 1 to December 31, 2021 | 4,309,556 | 28.76 | 4,309,556 | 1,997,876,503 | |||||||||||||||||||
| Total | 24,020,579 | $ | 28.65 | 24,020,579 | $ | 1,997,876,503 | |||||||||||||||||
| Period | Total Number of Shares (or Units) Purchased (1) | Average Price Paid per Share (or Unit) | Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans of Programs | Maximum Number (or Approximate Dollar Value) of Shares(or Units) that May Yet Be Purchased Under the Plans or Programs (1) | |||
| October 1 to October 31, 2017 | |||||||
| November 1 to November 30, 2017 | |||||||
| December 1 to December 31, 2017 | 6,956 | $ | 36.27 | ||||
| Total | 6,956 | $ | 36.27 | ||||
(a)PPL Corporation's Board of Directors approved a share repurchase plan in August 2021. See "Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial and Operational Developments - Share Repurchases" for additional information.
PPL Electric Utilities Corporation
There is no established public trading market for PPL Electric's common stock, as PPL owns 100% of the outstanding common shares. Dividends paid to PPL on those common shares are determined by PPL Electric's Board of Directors. PPL Electric paid common stock dividends to PPL of $336$334 million in 20172021 and $288$400 million in 2016.2020.
Louisville Gas and Electric Company
There is no established public trading market for LG&E's common stock, as LKE owns 100% of the outstanding common shares. Dividends paid to LKE on those common shares are determined by LG&E's Board of Directors. LG&E paid common stock dividends to LKE of $192 million in 20172021 and $128$161 million in 2016.2020.
Kentucky Utilities Company
There is no established public trading market for KU's common stock, as LKE owns 100% of the outstanding common shares. Dividends paid to LKE on those common shares are determined by KU's Board of Directors. KU paid common stock dividends to LKE of $226$250 million in 20172021 and $248$200 million in 2016.2020.
ITEM 6. SELECTED FINANCIAL AND OPERATING DATA
| PPL Corporation (a) (b) | 2017 | 2016 | 2015 | 2014 | 2013 | |||||||||||||||
Income Items (in millions) | ||||||||||||||||||||
| Operating revenues | $ | 7,447 | $ | 7,517 | $ | 7,669 | $ | 7,852 | $ | 7,263 | ||||||||||
| Operating income | 3,068 | 3,048 | 2,831 | 2,867 | 2,561 | |||||||||||||||
| Income from continuing operations after income taxes attributable to PPL shareowners | 1,128 | 1,902 | 1,603 | 1,437 | 1,368 | |||||||||||||||
Income (loss) from discontinued operations (net of income taxes) (f) | — | — | (921 | ) | 300 | (238 | ) | |||||||||||||
| Net income attributable to PPL shareowners (f) | 1,128 | 1,902 | 682 | 1,737 | 1,130 | |||||||||||||||
Balance Sheet Items (in millions) | ||||||||||||||||||||
| Total assets (d) | 41,479 | 38,315 | 39,301 | 48,606 | 45,889 | |||||||||||||||
| Short-term debt (d) | 1,080 | 923 | 916 | 836 | 701 | |||||||||||||||
| Long-term debt (d) | 20,195 | 18,326 | 19,048 | 18,054 | 18,269 | |||||||||||||||
| Common equity (d) | 10,761 | 9,899 | 9,919 | 13,628 | 12,466 | |||||||||||||||
| Total capitalization (d) | 32,036 | 29,148 | 29,883 | 32,518 | 31,436 | |||||||||||||||
| Financial Ratios | ||||||||||||||||||||
| Return on common equity - % (d)(f) | 10.9 | 19.2 | 5.8 | 13.0 | 9.8 | |||||||||||||||
| Ratio of earnings to fixed charges (c) | 3.1 | 3.8 | 2.8 | 2.8 | 2.4 | |||||||||||||||
| Common Stock Data | ||||||||||||||||||||
| Number of shares outstanding - Basic (in thousands) | ||||||||||||||||||||
| Year-end | 693,398 | 679,731 | 673,857 | 665,849 | 630,321 | |||||||||||||||
| Weighted-average | 685,240 | 677,592 | 669,814 | 653,504 | 608,983 | |||||||||||||||
Income from continuing operations after income taxes available to PPL common shareowners - Basic EPS | $ | 1.64 | $ | 2.80 | $ | 2.38 | $ | 2.19 | $ | 2.24 | ||||||||||
Income from continuing operations after income taxes available to PPL common shareowners - Diluted EPS | $ | 1.64 | $ | 2.79 | $ | 2.37 | $ | 2.16 | $ | 2.12 | ||||||||||
| Net income available to PPL common shareowners - Basic EPS | $ | 1.64 | $ | 2.80 | $ | 1.01 | $ | 2.64 | $ | 1.85 | ||||||||||
| Net income available to PPL common shareowners - Diluted EPS | $ | 1.64 | $ | 2.79 | $ | 1.01 | $ | 2.61 | $ | 1.76 | ||||||||||
| Dividends declared per share of common stock | $ | 1.58 | $ | 1.52 | $ | 1.50 | $ | 1.49 | $ | 1.47 | ||||||||||
| Book value per share (d) | $ | 15.52 | $ | 14.56 | $ | 14.72 | $ | 20.47 | $ | 19.78 | ||||||||||
| Market price per share | $ | 30.95 | $ | 34.05 | $ | 34.13 | $ | 36.33 | $ | 30.09 | ||||||||||
| Dividend payout ratio - % (e)(f) | 96 | 55 | 149 | 57 | 84 | |||||||||||||||
| Dividend yield - % (g) | 5.1 | 4.5 | 4.4 | 4.1 | 4.9 | |||||||||||||||
| Price earnings ratio (e)(f)(g) | 18.9 | 12.2 | 33.8 | 13.9 | 17.1 | |||||||||||||||
| Sales Data - GWh | ||||||||||||||||||||
| Domestic - Electric energy supplied - wholesale | 2,084 | 2,177 | 2,241 | 2,365 | 2,383 | |||||||||||||||
| Domestic - Electric energy delivered - retail | 65,751 | 67,474 | 67,798 | 68,569 | 67,848 | |||||||||||||||
| U.K. - Electric energy delivered | 74,317 | 74,728 | 75,907 | 75,813 | 78,219 | |||||||||||||||
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
(All Registrants)
This "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by PPL, PPL Electric, LKE, LG&E and KU. Information contained herein relating to any individual Registrant is filed by such Registrant solely on its own behalf, and no Registrant makes any representation as to information relating to any other Registrant. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for individual Registrants when significant.
The following should be read in conjunction with the Registrants' Consolidated Financial Statements and the accompanying Notes. Capitalized terms and abbreviations are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted.
"Management's Discussion and Analysis of Financial Condition and Results of Operations" includes the following information:
•"Overview" provides a description of each Registrant's business strategy and a discussion of important financial and operational developments.
•"Results of Operations" for all Registrants includes a "Statement of Income Analysis," which discusses significant changes in principal line items on the Statements of Income, comparing 20172021 with 2016 and 2016 with 2015.2020. For PPL, "Results of Operations" also includes "Segment Earnings" and "Margins""Adjusted Gross Margins," which provide a detailed analysis of earnings by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Margins""Adjusted Gross Margins" and provide explanations of the non-GAAP financial measures and a reconciliation of the non-GAAP financial measures to the most comparable GAAP measure. The "2018 Outlook" discussion identifies key factors expected to impact 2018 earnings. For PPL Electric, LKE, LG&E and KU, a summary of earnings and margins is also provided.
•"Financial Condition - Liquidity and Capital Resources" provides an analysis of the Registrants' liquidity positions and credit profiles. This section also includes a discussion of forecasted sources and uses of cash and rating agency actions.
•"Financial Condition - Risk Management" provides an explanation of the Registrants' risk management programs relating to market and credit risk.
•"Application of Critical Accounting Policies" provides an overview of the accounting policies that are particularly important to the results of operations and financial condition of the Registrants and that require their management to make significant estimates, assumptions and other judgments of inherently uncertain matters.
For comparison of the Registrants’ results of operations and cash flows for the years ended December 31, 2020 to December 31, 2019, refer to “Item 7. Combined Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the 2020 Form 10-K, filed with the SEC on February 18, 2021.
Overview
For a description of the Registrants and their businesses, see "Item 1. Business."
Business Strategy
(All Registrants)
PPL's strategy, which is supported by the other Registrants, 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 earningsfinancial foundation and dividend growth potential that will create significantlong-term value for its shareowners and positions PPL well for continued growth and success.
exceptional workplace; and to build strong communities in areas that we serve.
26
and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, the KPSC has adopted a series of regulatory mechanisms (ECR, DSM, GLT, fuel adjustment clause, and gas supply clauseclause) and recovery on construction work-in-progress)work-in-progress that reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs. In addition, the KPSC requires a utility to obtain a CPCN prior to constructing a facility, unless the construction is an ordinary extension of existing facilities in the usual course of business or does not involve sufficient capital outlay to materially affect the utility's financial condition. Although such KPSC proceedings do not directly address cost recovery issues, the KPSC, in awarding a CPCN, concludes that the public convenience and necessity require the construction of the facility on the basis that the facility is the lowest reasonable cost alternative to address the need. In Pennsylvania, the FERC transmission formula rate, DSIC mechanism, Smart Meter Rider and other recovery mechanisms are in placeoperate to reduce regulatory lag and provide for timely recovery of and a return on, as appropriate, prudently incurred costs.
company focused on building the utilities is expectedof the future. These transactions are intended to result instrengthen PPL’s credit metrics,
enhance long-term earnings growth forand predictability, and provide the foreseeable future. In 2017, earnings fromcompany with greater financial flexibility to invest in
sustainable energy solutions. See Note 9 to the Financial Statements, and the "Sale of the U.K. Regulated segment declined mainly dueUtility Business" and "Share Purchase Agreement to the unfavorable impact of lower GBP to U.S. dollar exchange rates. RAV growth is expectedAcquire Narragansett Electric" discussions in the U.K. Regulated segment during the RIIO-ED1 price control period which ends on March 31, 2023 and to result in earnings growth in 2018 through at least 2020. See "Item 1. Business - Segment Information - U.K. Regulated Segment" for additional information on RIIO-ED1.
Financial and Operational Developments
Sale of the U.K. Utility Business
On December 22, 2017, President Trump signedMarch 17, 2021, PPL WPD Limited (WPD Limited) entered into lawa share purchase agreement (WPD SPA) to sell PPL's U.K. utility business to National Grid Holdings One plc (National Grid U.K.), a subsidiary of National Grid plc. Pursuant to the TCJA. Substantially allWPD SPA, National Grid U.K. would acquire 100% of the provisionsissued share capital of PPL WPD Investments Limited (WPD Investments) for £7.8 billion in cash. WPD Limited would also receive an additional amount of £548,000 for each day during the period from January 1, 2021 to the closing date if the dividends usually declared by WPD Investments to WPD Limited were not paid for that period.
On June 14, 2021, the sale of the TCJA are effective for taxable years beginningU.K. utility business was completed.The transaction resulted in cash proceeds of $10.7 billion inclusive of foreign currency hedges executed by PPL. PPL received net proceeds, after December 31, 2017. The TCJA includes significant changestaxes and fees, of $10.4 billion, resulting in a pre-tax loss on sale of $1.6 billion. See Note 9 to the taxationFinancial Statements for additional information on the sale of corporations, including provisions specifically applicablethe U.K. utility business.
WPD Limited and National Grid U.K. each made customary representations and warranties in the WPD SPA. National Grid
U.K., at its expense, purchased warranty and indemnity insurance. WPD Limited agreed to regulated public utilities.indemnify National Grid U.K. for
certain tax related matters. See Note 11 to the Financial Statements for additional information. PPL has not had and will not
have any significant involvement with the U.K. utility business after completion of the sale.
Share Purchase Agreement to Acquire Narragansett Electric
On March 17, 2021, PPL and its subsidiary, PPL Energy Holdings, entered into a share purchase agreement (Narragansett SPA) with National Grid USA (National Grid U.S.), a subsidiary of National Grid plc, to acquire 100% of the outstanding shares of common stock of Narragansett Electric for approximately $3.8 billion in cash. On May 3, 2021, an Assignment and Assumption Agreement was entered into by PPL, PPL Energy Holdings, PPL Rhode Island Holdings and National Grid U.S. whereby certain interests of PPL Energy Holdings in the Narragansett SPA were assigned to and assumed by PPL Rhode Island Holdings. Pursuant to that Assignment and Assumption Agreement, PPL Rhode Island Holdings became the purchasing entity under the Narragansett SPA. The more significant changes that impactacquisition is expected to be funded with proceeds from the Registrants are:sale of the U.K. utility business. PPL has agreed to guarantee all obligations of PPL Energy Holdings and PPL Rhode Island Holdings under the Narragansett SPA and the related Assignment and Assumption Agreement.
The reduction inclosing of the acquisition is subject to the receipt of certain U.S. federal corporate income tax rate from a top marginal rateregulatory approvals or waivers, and other customary conditions to closing. To date, several required regulatory approvals or waivers have been received, though the order granting the waiver by the Massachusetts Department of 35%Public Utilities is subject to a flat ratepending appeal. See Note 9 to the Financial Statements for additional information regarding the current status of 21%, effective January 1, 2018;this appeal. PPL anticipates receiving a final order from the Rhode Island Division of Public Utilities and Carriers with respect to the acquisition by March 2022. The regulatory approvals remain subject to any applicable appeal periods. The consummation of the transaction is not subject to a financing condition.
See Note 9 to the associated "transition tax;"
Debt Redemption
PPL Capital Funding paid $3.883 billion to tender and/or redeem an aggregate total of certain rate normalization requirements for accelerated depreciation benefits. For non-regulated businesses, the TCJA generally provides for full expensing of property acquired after September 27, 2017.
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Income tax expense (benefit) | $ | 321 | $ | (13 | ) | $ | 112 | $ | — | $ | — | ||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Income tax expense (benefit) | $ | 220 | $ | (13 | ) | $ | 112 | $ | — | $ | — | ||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Net Increase in Regulatory Liabilities | $ | 2,185 | $ | 1,019 | $ | 1,166 | $ | 532 | $ | 634 | |||||||||
PPL's Board of Directors authorized share repurchases of up to $3 billion of PPL common shares. During 2021, PPL repurchased 34.8 million shares at a cost of $1.0 billion. See "Equity Securities" in European Union (PPL)Note 8 to the Financial Statements for additional information.
LKE Debt Redemption
On March 29, 2017,July 1, 2021, LKE redeemed, at par, its $250 million 4.375% Senior Notes due 2021 and on July 9, 2021, LKE filed a Form 15 with the SEC to suspend its duty to file reports under sections 13 and 15(d) of the Securities Exchange Act of 1934. As a result, beginning with the June 30, 2021 Form 10-Q, LKE was no longer reported as a Registrant.
U.K. Corporation Tax Rate Change
In 2021, the U.K. formally notifiedFinance Act 2021 increased the European CouncilU.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the European Union (EU) of its intent to withdraw from the EU, thereby commencing the two-year negotiation period to establish the terms of that withdrawal under Article 50corporation tax rate increase was an increase in deferred tax liabilities of the Lisbon Treaty. Article 50 specifies that ifU.K. utility business, which was sold on June 14, 2021, and a member state decides to withdraw from the EU, it must notify the European
Regulatory Requirements
(All Registrants)
The Registrants cannot predict the impact that future regulatory requirements may have on their financial condition or results of operations.
The businesses of LKE, LG&E and KU are subject to extensive federal, state and local environmental laws, rules and regulations, including those pertaining to CCRs, GHG, ELGs and the Clean Power Plan.ELGs. See Note 6, Note 13Notes 7, 14 and Note 1920 to the Financial Statements for a discussion of these significant environmental matters. These and other stringent environmental requirements led PPL, LKE, LG&E and KU to retire approximately 8001,200 MW of coal-fired generating plants in Kentucky primarilysince 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 2015. Additionally, KUdetermining when to retire generation assets. As a result of environmental requirements and aging infrastructure, LG&E anticipates retiring two older coal-fired units at the Mill Creek Plant and KU anticipates retiring one coal-fired unit at the E.W. Brown plantplant. Mill Creek Unit 1 has 300 MW of capacity and is expected to be retired in 2019 with a combined summer rating capacity2024. Mill Creek Unit 2 and E.W. Brown Unit 3 have capacities of 272 MW.
PPL Electric Transmission Formula Rate Case Proceedings
Return on Equity (PPL LKE,and PPL Electric)
On May 21, 2020, PP&L Industrial Customer Alliance (PPLICA) filed a complaint with the FERC alleging that PPL Electric's base return on equity (ROE) of 11.18% used to determine PPL Electric's formula transmission rate was unjust and unreasonable.
On August 20, 2021, PPL Electric entered into a settlement agreement (the Settlement) with PPLICA and all other parties, including intervenors, with respect to the complaint filed by PPLICA on May 21, 2020.
The key aspects of the Settlement include:
•changes to PPL Electric’s base ROE:
◦beginning as of May 21, 2020 and continuing through May 31, 2022, the ROE shall be 9.90%;
◦beginning on June 1, 2022 and continuing through May 31, 2023, the ROE shall be 9.95%;
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◦beginning on June 1, 2023, the ROE shall be 10.00%, which shall continue in effect unless and until changed as permitted by the terms of the Settlement;
•changes the equity component of PPL Electric’s capital structure to be the lower of (i) PPL Electric’s actual equity component, calculated in accordance with the formula rate template, or (ii) 56.00%;
•allows modification of the current rate year of June 1 to May 31 to a calendar year of January 1 to December 31; and
•allows modification of the current formula rate based on a historic test year to a projected test year.
In 2021, PPL Electric recorded a revenue reduction of $78 million ($55 million after-tax), of which $73 million ($52 million after-tax) represents revenue subject to refund for the period May 21, 2020 through November 30, 2021. The reduction recorded includes $28 million ($20 million after-tax) related to the period from May 21, 2020 to December 31, 2020. The $73 million of revenue to be refunded will be returned to customers from January 1, 2022 through May 31, 2022 and is based on the difference between charges that were calculated using the ROE in effect at the time and charges calculated using the revised ROE provided for the Settlement, plus interest at the FERC interest rate.
The FERC approved the Settlement on November 5, 2021. Interim rates reflecting the agreed-to-base ROE in the Settlement were effective December 1, 2021.
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 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 FERC's orders on the elimination of the mitigation and required transition mechanism. Oral arguments in the appellate proceeding occurred on February 14, 2022.LG&E and KU cannot predict the outcome of the respective appellate and FERC proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms and such rate recovery would be anticipated to be adjusted consistent with potential changes or terminations of the waivers and credits, as such become effective.
Rate Case Proceedings
(PPL, LG&E and KU)
On November 2016,25, 2020, LG&E and KU filed requests with the KPSC for increasesan increase in annual base electricity and gas rates. LG&E'srevenues of approximately $331 million ($131 million and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program.
LG&E’s and KU’s applications also included a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky.
The applications were based on a forecasted test year of July 1, 2021 through June 30, 2022 and requested an authorized return on equity of 10.0%.
On April 19, 2021, LG&E and KU entered into an agreement with all intervening parties to the proceeding, filedproceedings resolving all matters in their applications, with the explicit exception of LG&E's and KU's net metering proposals.
On June 30, 2021 and December 6, 2021, the KPSC stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things,issued orders approving the proposed stipulationsagreement filed in April 2021, with certain modifications. The orders provided for increases in annual revenue requirements associated withrevenues of $207 million ($74 million and $110 million in electricity revenues at LG&E base electricity rates of $59 million, LG&E base gas rates of $8 million and KU base electricity rates of $55and $23 million reflecting a returnin gas revenues at LG&E) based on equity of 9.75%, the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates.
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9.425%. Consistent withThe orders grant an authorized 9.35% return on equity for the stipulations,ECR and GLT mechanisms and do not modify the requested one-year billing credit. The orders approved LG&E'sthe CPCN to deploy Advanced Metering Infrastructure and KU's requestprovide regulatory asset treatment for implementing a Distribution Automation program and their withdrawalthe remaining net book value of a request for a CPCN forlegacy meters upon full implementation of the Advanced Metering SystemInfrastructure program. The orders also approved newthe establishment of a Retired Asset Recovery (RAR) rider 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. In respect of the RAR rider, LG&E and KU continue to use currently approved depreciation rates for Mill Creek Units 1 and 2 and Brown Unit 3. The orders also approved a four-year "stay out" commitment from LG&E and KU that resulted in higher depreciation of approximately $15 million ($4 million for LG&E and $11 million for KU) in 2017, exclusive of net additions to PP&E. The orders resulted inrefrain from effective base electricity and gas rate increases of 5.2% and 2.1% at LG&E and a base electricity rate increase of 3.2% at KU. The new base rates and all elements of the orders became effectivebefore July 1, 2017.2025, subject to certain exceptions. On June 23, 2017,September 24, 2021, the KPSC issued orders establishing an authorized return on equity of 9.7% for all of LG&E's and KU's existing approved ECR plans and projects, replacingproviding adjustments to previous net metering proposals. These adjustments did not impact the prior authorized return on equity levels of 9.8% for CCR projects and 10% for all other ECR approved projects, effective with bills issued in August 2017. The annual impact of the new authorized return for ECR projects is not expected to be significant.revenue increases.
On September 29, 2017,August 31, 2021, KU filed a request seeking approval fromwith the VSCC tofor an annual increase annualin Virginia base electricity revenue by $7 million, representing an increaserates of 10.4%.approximately $12 million. KU's request is based on an authorized 10.42%10.4% return on equity. A hearing on the matter is scheduled for March 17, 2022. Subject to regulatory review and approval, new rates would become effective July 1, 2018.
Results of Operations
(PPL)
The "Statement of Income Analysis" discussion below describes significant changes in principal line items on PPL's Statements of Income, comparing year-to-year changes.2021 with 2020. The "Segment Earnings" and "Margins""Adjusted Gross Margins" discussions for PPL provide a review of results by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Margins,"Adjusted Gross Margins," and provide explanations of the non-GAAP financial measures and a reconciliation of those measures to the most comparable GAAP measure. The "2018 Outlook" discussion identifies key factors expected to impact 2018 earnings.
(PPL Electric, LKE, LG&E and KU)
A "Statement of Income Analysis, Earnings and Margins"Analysis" is presented separately for PPL Electric, LKE, LG&E and KU.
The "Statement of Income Analysis" discussion below describes significant changes in principal line items on the Statements of Income, comparing year-to-year changes.2021 with 2020. The "Earnings" discussion providesresults of operations section for PPL Electric, LG&E and KU is presented in a summaryreduced disclosure format in accordance with General Instructions (I)(2)(a) of earnings. The "Margins" discussion includes a reconciliationForm 10-K.
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PPL: Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins
Statement of Income Analysis
Net income for the years ended December 31 includes the following results.results:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Operating Revenues | $ | 5,783 | $ | 5,474 | $ | 309 | |||||||||||
| Operating Expenses | |||||||||||||||||
| Operation | |||||||||||||||||
| Fuel | 710 | 632 | 78 | ||||||||||||||
| Energy purchases | 752 | 634 | 118 | ||||||||||||||
| Other operation and maintenance | 1,608 | 1,420 | 188 | ||||||||||||||
| Depreciation | 1,082 | 1,022 | 60 | ||||||||||||||
| Taxes, other than income | 207 | 180 | 27 | ||||||||||||||
| Total Operating Expenses | 4,359 | 3,888 | 471 | ||||||||||||||
| Other Income (Expense) - net | 15 | 2 | 13 | ||||||||||||||
| Interest Expense | 918 | 634 | 284 | ||||||||||||||
| Income (Loss) from Continuing Operations Before Income Taxes | 521 | 954 | (433) | ||||||||||||||
| Income Taxes | 503 | 314 | 189 | ||||||||||||||
| Income (Loss) from Continuing Operations After Income Taxes | 18 | 640 | (622) | ||||||||||||||
| Income (Loss) from Discontinued Operations (net of income taxes) (Note 9) | (1,498) | 829 | (2,327) | ||||||||||||||
| Net Income (Loss) | $ | (1,480) | $ | 1,469 | $ | (2,949) | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating Revenues | $ | 7,447 | $ | 7,517 | $ | 7,669 | $ | (70 | ) | $ | (152 | ) | |||||||
| Operating Expenses | |||||||||||||||||||
| Operation | |||||||||||||||||||
| Fuel | 759 | 791 | 863 | (32 | ) | (72 | ) | ||||||||||||
| Energy purchases | 685 | 706 | 855 | (21 | ) | (149 | ) | ||||||||||||
| Other operation and maintenance | 1,635 | 1,745 | 1,938 | (110 | ) | (193 | ) | ||||||||||||
| Depreciation | 1,008 | 926 | 883 | 82 | 43 | ||||||||||||||
| Taxes, other than income | 292 | 301 | 299 | (9 | ) | 2 | |||||||||||||
| Total Operating Expenses | 4,379 | 4,469 | 4,838 | (90 | ) | (369 | ) | ||||||||||||
| Other Income (Expense) - net | (255 | ) | 390 | 108 | (645 | ) | 282 | ||||||||||||
| Interest Expense | 901 | 888 | 871 | 13 | 17 | ||||||||||||||
| Income Taxes | 784 | 648 | 465 | 136 | 183 | ||||||||||||||
| Income from Continuing Operations After Income Taxes | 1,128 | 1,902 | 1,603 | (774 | ) | 299 | |||||||||||||
| Loss from Discontinued Operations (net of income taxes) | — | — | (921 | ) | — | 921 | |||||||||||||
| Net Income | $ | 1,128 | $ | 1,902 | $ | 682 | $ | (774 | ) | $ | 1,220 | ||||||||
Operating Revenues
The increase (decrease) in operating revenues was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Domestic: | |||||||
| PPL Electric Distribution price (a) | $ | 53 | $ | 126 | |||
| PPL Electric Distribution volume | (21 | ) | (9 | ) | |||
| PPL Electric PLR Revenue (b) | (16 | ) | (135 | ) | |||
| PPL Electric Transmission Formula Rate | 34 | 59 | |||||
| LKE Base rates | 58 | 68 | |||||
| LKE Volumes (c) | (73 | ) | 1 | ||||
| LKE Fuel and other energy prices (d) | 10 | (81 | ) | ||||
| LKE ECR | 10 | 39 | |||||
| Other | (9 | ) | (17 | ) | |||
| Total Domestic | 46 | 51 | |||||
| U.K.: | |||||||
| Price | 60 | 98 | |||||
| Volume | (30 | ) | (36 | ) | |||
| Foreign currency exchange rates | (154 | ) | (255 | ) | |||
| Other | 8 | (10 | ) | ||||
| Total U.K. | (116 | ) | (203 | ) | |||
| Total | $ | (70 | ) | $ | (152 | ) | |
| 2021 vs. 2020 | |||||
| 19 | |||||
| PPL Electric PLR (a) | 83 | ||||
| PPL Electric transmission formula rate (b) | (35) | ||||
| LG&E fuel and other energy prices | 53 | ||||
| LG&E volumes (d) | 25 | ||||
| LG&E retail rates (e) | 46 | ||||
| LG&E Economic relief billing credit, net of | (12) | ||||
| KU fuel and other energy prices (c) | 43 | ||||
| KU volumes (d) | 27 | ||||
| KU retail rates (e) | 53 | ||||
| 7 | |||||
| 309 | |||||
(a) The increase was primarily the result of higher energy prices and higher customer usage, partially offset by higher volumes of shopping customers.
(c) The increases were primarily due to higher recoveries of fuel usage drivenand energy purchases due to higher commodity costs.
(d) The increases were primarily due to favorable weather.
(e) The increases were due to new base rates approved by milder weather in 2017.the KPSC effective July 1, 2021.
Fuel
Fuel decreased $72increased $78 million in 20162021 compared with 20152020, primarily due to a decrease$59 million increase at KU due to a $39 million increase in market prices for coalcommodity costs and natural gas.a $19 million increase in volumes driven by weather as well a $19 million increase at LG&E due to a $10 million increase in volumes driven by weather and an $8 million increase in commodity costs.
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Energy Purchases
Energy purchases decreased $21increased $118 million in 20172021 compared with 2016 primarily due to lower PLR prices of $17 million.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Domestic: | |||||||
| LKE plant operations and maintenance (a) | $ | (2 | ) | $ | (19 | ) | |
| LKE pension expense | 1 | (12 | ) | ||||
| PPL Electric payroll-related costs | (12 | ) | (26 | ) | |||
| PPL Electric Act 129 | 9 | (15 | ) | ||||
| PPL Electric contractor related expenses | (4 | ) | 7 | ||||
| PPL Electric vegetation management | (17 | ) | 4 | ||||
| PPL Electric universal service programs | (3 | ) | 3 | ||||
| Storm costs | 4 | 6 | |||||
| Bad debts | (17 | ) | (5 | ) | |||
| Stock compensation expense | 5 | (6 | ) | ||||
| Third-party costs related to the spinoff of PPL Energy Supply (Note 8) | — | (13 | ) | ||||
| Separation benefits related to the spinoff of PPL Energy Supply (Note 8) | — | (8 | ) | ||||
| Corporate costs previously included in discontinued operations | — | 8 | |||||
| Other | (1 | ) | 18 | ||||
| U.K.: | |||||||
| Pension expense (b) | (67 | ) | (86 | ) | |||
| Foreign currency exchange rates | (15 | ) | (33 | ) | |||
| Third-party engineering | 6 | (8 | ) | ||||
| Other | 3 | (8 | ) | ||||
| Total | $ | (110 | ) | $ | (193 | ) | |
| 2021 vs. 2020 | |||||
| PPL Electric storm costs | $ | 20 | |||
| PPL Electric inventory adjustments | 9 | ||||
| LG&E plant operations and maintenance | 10 | ||||
| KU plant outages | 8 | ||||
| KU plant operations and maintenance | 6 | ||||
| KU distribution operations and maintenance | 5 | ||||
| KU transmission operations and maintenance | 6 | ||||
| Solar panel impairment (Note 1) | 37 | ||||
| Charges related to | 26 | ||||
| Charges related to the sale of the U. K. utility business | 8 | ||||
| Stock compensation expense | 6 | ||||
| Payroll-related | 6 | ||||
| Other | 28 | ||||
| Total | $ | 188 | |||
Depreciation
The increase (decrease) in depreciation was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Additions to PP&E, net | $ | 93 | $ | 76 | |||
| Foreign currency exchange rates | (16 | ) | (27 | ) | |||
| Depreciation rates (a) | 15 | — | |||||
| Other | (10 | ) | (6 | ) | |||
| Total | $ | 82 | $ | 43 | |||
| 2021 vs. 2020 | |||||
| Additions to PP&E, net | $ | 36 | |||
| Depreciation rate change effective July 2021 | 11 | ||||
| Other | 1 | ||||
| Total | $ | 60 | |||
Taxes, Other Than Income
The increase (decrease) in taxes, other than income was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| State gross receipts tax (a) | $ | 3 | $ | 11 | |||
| Domestic property tax expense | 4 | 4 | |||||
| Domestic capital stock tax | (6 | ) | — | ||||
| Foreign currency exchange rates | (8 | ) | (15 | ) | |||
| Other | (2 | ) | 2 | ||||
| Total | $ | (9 | ) | $ | 2 | ||
| 2021 vs. 2020 | |||||
| State gross receipts tax (a) | $ | 13 | |||
| Domestic property tax expense | 10 | ||||
| Total | $ | 27 | |||
(a)The increase was primarily due to a favorable settlement of 2008 - 2010 gross receipts tax assessments in 2020.
Other Income (Expense) - net
| 2021 vs. 2020 | |||||
| Defined benefit plans - non-service credits (Note 12) | $ | 23 | |||
| Charitable contributions | (11) | ||||
| Other | 1 | ||||
| Total | $ | 13 | |||
Interest Expense
The increase (decrease) in interest expense was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Long-term debt interest expense (a) | $ | 34 | $ | 63 | |||
| Short-term debt interest | 7 | 2 | |||||
| Hedging activities and ineffectiveness | 1 | (4 | ) | ||||
| Foreign currency exchange rates | (26 | ) | (43 | ) | |||
| Other | (3 | ) | (1 | ) | |||
| Total | $ | 13 | $ | 17 | |||
| Loss on | $ | 395 | |||
| Long-term debt interest | (93) | ||||
| Other | (18) | ||||
| Total | $ | 284 | |||
Income Taxes
The increase (decrease) in income taxes was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Change in pre-tax income at current period tax rates | $ | (223 | ) | $ | 184 | ||
| Valuation allowance adjustments (a) | 20 | (8 | ) | ||||
| Federal and state tax reserve adjustments (b) | — | 22 | |||||
| Foreign income tax return adjustments | (10 | ) | 2 | ||||
| U.S. income tax on foreign earnings net of foreign tax credit (c) | 89 | (50 | ) | ||||
| Impact of U.K. Finance Acts (d) | 33 | 42 | |||||
| Deferred tax impact of U.S. tax reform (e) | 220 | — | |||||
| Stock-based compensation (f) | 7 | (10 | ) | ||||
| Other | — | 1 | |||||
| Total | $ | 136 | $ | 183 | |||
| 2021 vs. 2020 | |||||
| Change in pre-tax income | $ | (116) | |||
| Valuation allowance adjustments (a) | |||||
| Federal and state income tax | 6 | ||||
| Impact of the U.K. Finance Acts on deferred tax | 282 | ||||
| Other | 4 | ||||
| Total | $ | 189 | |||
(a)In 2021, PPL recorded a $31 million state deferred tax benefit on a net operating loss and an offsetting valuation allowance in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. See Note 8 for additional information on the tender offer.
(b)The U.K. Finance Act 2015, enacted in November 2015, reduced the U.K. statutory incomecorporation tax rate from 20%was scheduled to 19% effective April 1, 2017 andbe reduced from 19% to 18%17%, effective April 1, 2020. As a result, PPL reduced its netIn 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction to 17%, thereby maintaining the corporation tax rate at 19% for financial years 2020 and 2021. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and recognized a $90 millioncorresponding deferred income tax benefit during 2015, relatedexpense of $106 million. In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to both25%, effective April 1, 2023. The primary impact of the corporation tax rate decreases.increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million.
See Note 56 to the Financial Statements for additional information on income taxes.
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Segment Earnings
PPL's Net Income by reportable segments was as follows:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Kentucky Regulated | $ | 468 | $ | 418 | $ | 50 | |||||||||||
| Pennsylvania Regulated | 445 | 497 | (52) | ||||||||||||||
| Corporate and Other (a)(b) | (895) | (275) | (620) | ||||||||||||||
| Discontinued Operations (c) | (1,498) | 829 | (2,327) | ||||||||||||||
| Net Income | $ | (1,480) | $ | 1,469 | $ | (2,949) | |||||||||||
(a)Primarily represents financing and certain other costs incurred at the corporate level that have not been allocated or assigned to the segments, which are presented to reconcile segment information to PPL's consolidated results.
(b)The amount for 2020 has been adjusted for certain costs that were previously included in the U.K. Regulated segment.
(c)See Note 9 to the Financial Statements for additional information.
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| U.K. Regulated | $ | 652 | $ | 1,246 | $ | 1,121 | $ | (594 | ) | $ | 125 | ||||||||
| Kentucky Regulated | 286 | 398 | 326 | (112 | ) | 72 | |||||||||||||
| Pennsylvania Regulated | 359 | 338 | 252 | 21 | 86 | ||||||||||||||
| Corporate and Other (a) | (169 | ) | (80 | ) | (96 | ) | (89 | ) | 16 | ||||||||||
| Discontinued Operations (b) | — | — | (921 | ) | — | 921 | |||||||||||||
| Net Income | $ | 1,128 | $ | 1,902 | $ | 682 | $ | (774 | ) | $ | 1,220 | ||||||||
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 effectivestatutory tax rate of the entity where the activity is recorded. Special items include: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 were as follows:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Kentucky Regulated | $ | 465 | $ | 423 | $ | 42 | |||||||||||
| Pennsylvania Regulated | 465 | 498 | (33) | ||||||||||||||
| Corporate and Other (a) | (124) | (147) | 23 | ||||||||||||||
| Earnings from Ongoing Operations | $ | 806 | $ | 774 | $ | 32 | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| U.K. Regulated | $ | 885 | $ | 1,015 | $ | 968 | $ | (130 | ) | $ | 47 | ||||||||
| Kentucky Regulated | 395 | 398 | 343 | (3 | ) | 55 | |||||||||||||
| Pennsylvania Regulated | 349 | 338 | 252 | 11 | 86 | ||||||||||||||
| Corporate and Other | (76 | ) | (77 | ) | (74 | ) | 1 | (3 | ) | ||||||||||
| Earnings from Ongoing Operations | $ | 1,553 | $ | 1,674 | $ | 1,489 | $ | (121 | ) | $ | 185 | ||||||||
(a)The amount for 2020 has been adjusted for certain costs that were previously included in the U.K. Regulated segment.
See "Reconciliation of Earnings from Ongoing Operations" below for a reconciliation of this non-GAAP financial measure to Net Income.
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating revenues | $ | 2,091 | $ | 2,207 | $ | 2,410 | $ | (116 | ) | $ | (203 | ) | |||||||
| Other operation and maintenance | 272 | 344 | 477 | (72 | ) | (133 | ) | ||||||||||||
| Depreciation | 230 | 233 | 242 | (3 | ) | (9 | ) | ||||||||||||
| Taxes, other than income | 127 | 135 | 148 | (8 | ) | (13 | ) | ||||||||||||
| Total operating expenses | 629 | 712 | 867 | (83 | ) | (155 | ) | ||||||||||||
| Other Income (Expense) - net | (261 | ) | 386 | 123 | (647 | ) | 263 | ||||||||||||
| Interest Expense | 397 | 402 | 417 | (5 | ) | (15 | ) | ||||||||||||
| Income Taxes | 152 | 233 | 128 | (81 | ) | 105 | |||||||||||||
| Net Income | 652 | 1,246 | 1,121 | (594 | ) | 125 | |||||||||||||
| Less: Special Items | (233 | ) | 231 | 153 | (464 | ) | 78 | ||||||||||||
| Earnings from Ongoing Operations | $ | 885 | $ | 1,015 | $ | 968 | $ | (130 | ) | $ | 47 | ||||||||
| Income Statement Line Item | 2017 | 2016 | 2015 | ||||||||||
| Foreign currency economic hedges, net of tax of $59, $4, ($30) (a) | Other Income (Expense) - net | $ | (111 | ) | $ | (8 | ) | $ | 55 | ||||
| U.S. tax reform (b) | Income Taxes | (122 | ) | — | — | ||||||||
| Settlement of foreign currency contracts, net of tax of $0, ($108), $0 (c) | Other Income (Expense) - net | — | 202 | — | |||||||||
| Change in U.K. tax rate (d) | Income Taxes | — | 37 | 78 | |||||||||
| WPD Midlands acquisition-related adjustment, net of tax of $0, $0, ($1) | Other operation and maintenance | — | — | 2 | |||||||||
| Settlement of certain income tax positions (e) | Income Taxes | — | — | 18 | |||||||||
| Total | $ | (233 | ) | $ | 231 | $ | 153 | ||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| U.K. | |||||||
| Gross margins | $ | 30 | $ | 62 | |||
| Other operation and maintenance | 64 | 94 | |||||
| Depreciation | (14 | ) | (18 | ) | |||
| Interest expense | (21 | ) | (28 | ) | |||
| Other | (6 | ) | (3 | ) | |||
| Income taxes | 11 | (18 | ) | ||||
| U.S. | |||||||
| Interest expense and other | 1 | (2 | ) | ||||
| Income taxes | (10 | ) | 41 | ||||
| Foreign currency exchange, after-tax | (185 | ) | (81 | ) | |||
| Earnings from Ongoing Operations | (130 | ) | 47 | ||||
| Special items, after-tax | (464 | ) | 78 | ||||
| Net Income | $ | (594 | ) | $ | 125 | ||
Kentucky Regulated Segment
The Kentucky Regulated segment consists primarily of LKE'sLG&E's and KU's regulated electricity generation, transmission and distribution operations, of LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. In addition, certain acquisition-related financing costs are allocated to the Kentucky Regulated segment. The Kentucky Regulated segment represents 25% of PPL's Net Income for 2017 and 35% of PPL's assets at December 31, 2017.
Net Income and Earnings from Ongoing Operations include the following results.results:
34
| Change | Change | |||||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||||||||||||||||
| Operating revenues | $ | 3,156 | $ | 3,141 | $ | 3,115 | $ | 15 | $ | 26 | Operating revenues | $ | 3,348 | $ | 3,106 | $ | 242 | |||||||||||||||||||
| Fuel | 759 | 791 | 863 | (32 | ) | (72 | ) | Fuel | 710 | 632 | 78 | |||||||||||||||||||||||||
| Energy purchases | 178 | 171 | 184 | 7 | (13 | ) | Energy purchases | 186 | 143 | 43 | ||||||||||||||||||||||||||
| Other operation and maintenance | 806 | 804 | 837 | 2 | (33 | ) | Other operation and maintenance | 905 | 834 | 71 | ||||||||||||||||||||||||||
| Depreciation | 439 | 404 | 382 | 35 | 22 | Depreciation | 647 | 606 | 41 | |||||||||||||||||||||||||||
| Taxes, other than income | 65 | 62 | 57 | 3 | 5 | Taxes, other than income | 87 | 77 | 10 | |||||||||||||||||||||||||||
| Total operating expenses | 2,247 | 2,232 | 2,323 | 15 | (91 | ) | Total operating expenses | 2,535 | 2,292 | 243 | ||||||||||||||||||||||||||
| Other Income (Expense) - net | (3 | ) | (9 | ) | (13 | ) | 6 | 4 | Other Income (Expense) - net | (2) | 2 | (4) | ||||||||||||||||||||||||
| Interest Expense | 261 | 260 | 232 | 1 | 28 | Interest Expense | 196 | 223 | (27) | |||||||||||||||||||||||||||
| Interest Expense with Affiliate (a) | Interest Expense with Affiliate (a) | 53 | 77 | (24) | ||||||||||||||||||||||||||||||||
| Income Taxes | 359 | 242 | 221 | 117 | 21 | Income Taxes | 94 | 98 | (4) | |||||||||||||||||||||||||||
| Net Income | 286 | 398 | 326 | (112 | ) | 72 | Net Income | 468 | 418 | 50 | ||||||||||||||||||||||||||
| Less: Special Items | (109 | ) | — | (17 | ) | (109 | ) | 17 | Less: Special Items | 3 | (5) | 8 | ||||||||||||||||||||||||
| Earnings from Ongoing Operations | $ | 395 | $ | 398 | $ | 343 | $ | (3 | ) | $ | 55 | Earnings from Ongoing Operations | $ | 465 | $ | 423 | $ | 42 | ||||||||||||||||||
(a)Borrowings between LKE and PPL were $2,166 million and $1,451 million as of December 31, 2021 and 2020.
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. Operations:
| Income Statement Line Item | 2021 | 2020 | |||||||||||||||
| Valuation allowance adjustment (a) | Income taxes | $ | 4 | $ | — | ||||||||||||
| Strategic corporate initiatives, net of tax of $0, $0 (b) | Other Income (Expense) | (1) | — | ||||||||||||||
| COVID-19 impact, net of tax of $0, $2 (c) | Other operation and maintenance | — | (5) | ||||||||||||||
| Total | $ | 3 | $ | (5) | |||||||||||||
| Income Statement Line Item | 2017 | 2016 | 2015 | ||||||||||
| U.S. tax reform (a) | Income Taxes | $ | (112 | ) | $ | — | $ | — | |||||
| Adjustment to investment, net of tax of $0, $0, $0 (b) | Other Income (Expense) - net | (1 | ) | — | — | ||||||||
| Settlement of indemnification agreement, net of tax of ($2), $0, $0 (c) | Other Income (Expense) - net | 4 | — | — | |||||||||
| Certain income tax valuation allowances (d) | Income Taxes | — | — | (12 | ) | ||||||||
| LKE acquisition - related adjustment, net of tax of $0, $0, $0 (e) | Other Income (Expense) - net | �� | — | (5 | ) | ||||||||
| Total | $ | (109 | ) | $ | — | $ | (17 | ) | |||||
(a)Adjustment of valuation allowances related to certain tax credits recorded in 2017 as a result of the TCJA.
(b)Costs incurred related to PPL's strategic repositioning.
(c)Incremental costs for outside services, customer payment processing, personal protective equipment and other safety related actions associated with the COVID-19 pandemic.
The changes in the components of the Kentucky Regulated segment's results between these periods were due to the factors set forth below, which reflect amounts classified as Kentucky Adjusted Gross Margins and the items that management considers special on separate lines and not in their respective Statement of Income line item.
| 2021 vs. 2020 | |||||
| Kentucky Adjusted Gross Margins | $ | 174 | |||
| Other operation and maintenance | (81) | ||||
| Depreciation | (90) | ||||
| Taxes, other than income | (11) | ||||
| Other Income (Expense) - net | (3) | ||||
| Interest Expense | 27 | ||||
| Interest Expense with Affiliate | 24 | ||||
| Income Taxes | 2 | ||||
| Earnings from Ongoing Operations | 42 | ||||
| Special Items, after-tax | 8 | ||||
| Net Income | $ | 50 | |||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Kentucky Gross Margins | $ | 29 | $ | 83 | |||
| Other operation and maintenance | — | 42 | |||||
| Depreciation | (27 | ) | (4 | ) | |||
| Taxes, other than income | (2 | ) | (4 | ) | |||
| Other Income (Expense) - net | 1 | (1 | ) | ||||
| Interest Expense | (1 | ) | (28 | ) | |||
| Income Taxes | (3 | ) | (33 | ) | |||
| Earnings from Ongoing Operations | (3 | ) | 55 | ||||
| Special Items, after-tax | (109 | ) | 17 | ||||
| Net Income | $ | (112 | ) | $ | 72 | ||
•See "Margins"Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Kentucky Adjusted Gross Margins.
35
to base rates as a result of coal units retired in 2015 at the Cane Run2020 Kentucky rate case and Green River plants, partially offset by $5 million of additionalvarious support costs for Cane Run Unit 7 plant operations and $12 million of lower pension expense mainly due to higher discount rates and deferred amortization of actuarial losses.other items that were not individually significant.
•Higher depreciation expense in 20172021 compared with 2016to 2020, primarily due to additionsa $60 million increase related to PP&E,certain ECR and GLT depreciation expenses transferred to base rates as a result of the 2020 Kentucky rate case, a $21 million increase due to additional assets placed into service, net of retirements and a $9 million increase due to higher depreciation rates, effective July 1, 2017.2021.
Pennsylvania Regulated Segment
The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. In addition, certain costs are allocated to the Pennsylvania Regulated segment. The Pennsylvania Regulated segment represents 32% of PPL's Net Income for 2017 and 24% of PPL's assets at December 31, 2017.
Net Income and Earnings from Ongoing Operations include the following results.results:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Operating revenues | $ | 2,402 | $ | 2,330 | $ | 72 | |||||||||||
| Energy purchases | 566 | 491 | 75 | ||||||||||||||
| Other operation and maintenance | 557 | 513 | 44 | ||||||||||||||
| Depreciation | 424 | 403 | 21 | ||||||||||||||
| Taxes, other than income | 120 | 107 | 13 | ||||||||||||||
| Total operating expenses | 1,667 | 1,514 | 153 | ||||||||||||||
| Other Income (Expense) - net | 26 | 20 | 6 | ||||||||||||||
| Interest Expense | 162 | 172 | (10) | ||||||||||||||
| Income Taxes | 154 | 167 | (13) | ||||||||||||||
| Net Income | 445 | 497 | (52) | ||||||||||||||
| Less: Special Items | (20) | (1) | (19) | ||||||||||||||
| Earnings from Ongoing Operations | $ | 465 | $ | 498 | $ | (33) | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating revenues | $ | 2,195 | $ | 2,156 | $ | 2,124 | $ | 39 | $ | 32 | |||||||||
| Energy purchases | |||||||||||||||||||
| External | 507 | 535 | 657 | (28 | ) | (122 | ) | ||||||||||||
| Intersegment | — | — | 14 | — | (14 | ) | |||||||||||||
| Other operation and maintenance | 571 | 601 | 607 | (30 | ) | (6 | ) | ||||||||||||
| Depreciation | 309 | 253 | 214 | 56 | 39 | ||||||||||||||
| Taxes, other than income | 107 | 105 | 94 | 2 | 11 | ||||||||||||||
| Total operating expenses | 1,494 | 1,494 | 1,586 | — | (92 | ) | |||||||||||||
| Other Income (Expense) - net | 16 | 17 | 8 | (1 | ) | 9 | |||||||||||||
| Interest Expense | 142 | 129 | 130 | 13 | (1 | ) | |||||||||||||
| Income Taxes | 216 | 212 | 164 | 4 | 48 | ||||||||||||||
| Net Income | 359 | 338 | 252 | 21 | 86 | ||||||||||||||
| Less: Special Items | 10 | — | — | 10 | — | ||||||||||||||
| Earnings from Ongoing Operations | $ | 349 | $ | 338 | $ | 252 | $ | 11 | $ | 86 | |||||||||
The following after-tax gain,gains (losses), which management considers a special item,items, impacted the Pennsylvania Regulated segment's results and isare excluded from Earnings from Ongoing Operations. Operations:
| Income Statement Line Item | 2021 | 2020 | |||||||||||||||
| Transmission formula rate return on equity settlement, net of tax of $8, $0 (a) | Operating revenues | $ | (20) | $ | — | ||||||||||||
| COVID-19 impact, net of tax of $0, $0 (b) | Other operation and maintenance | — | (1) | ||||||||||||||
| Total | $ | (20) | $ | (1) | |||||||||||||
| Income Statement Line Item | 2017 | 2016 | 2015 | ||||||||||
| U.S. tax reform (a) | Income Taxes | $ | 10 | $ | — | $ | — | ||||||
| Total | $ | 10 | $ | — | $ | — | |||||||
(a)Represents the portion of the revenue reduction recognized in the December 31, 2021, Statement of Income related to the period from May 21, 2020 through December 31, 2020. See Note 7 to the Financial Statements for additional information.
(b)Incremental costs for outside services, personal protective equipment and other safety related actions associated with the COVID-19 pandemic.
The changes in the components of the Pennsylvania Regulated segment's results between these periods were due to the factors set forth below, which reflect amounts classified as Pennsylvania Adjusted Gross Margins and the itemitems that management considers special on separate lines and not in their respective Statement of Income line items.
36
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Pennsylvania Gross Margins | $ | 31 | $ | 177 | |||
| Other operation and maintenance | 42 | — | |||||
| Depreciation | (35 | ) | (39 | ) | |||
| Taxes, other than income | 1 | (14 | ) | ||||
| Other Income (Expense) - net | (1 | ) | 9 | ||||
| Interest Expense | (13 | ) | 1 | ||||
| Income Taxes | (14 | ) | (48 | ) | |||
| Earnings from Ongoing Operations | 11 | 86 | |||||
| Special Item, after-tax | 10 | — | |||||
| Net Income | $ | 21 | $ | 86 | |||
| 2021 vs. 2020 | |||||
| Pennsylvania Adjusted Gross Margins | $ | — | |||
| Other operation and maintenance | (24) | ||||
| Depreciation | (22) | ||||
| Taxes, other than income | (8) | ||||
| Other Income (Expense) - net | 6 | ||||
| Interest Expense | 10 | ||||
| Income Taxes | 5 | ||||
| Earnings from Ongoing Operations | (33) | ||||
| Special Items, after-tax | (19) | ||||
| Net Income | $ | (52) | |||
•See "Margins"Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Pennsylvania Adjusted Gross Margins.
Reconciliation of Earnings from Ongoing Operations
The following tables contain after-tax gains (losses), in total, which management considers special items, that are excluded from Earnings from Ongoing Operations, and a reconciliation to PPL's "Net Income" for the years ended December 31. 31:
| 2021 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| KY Regulated | PA Regulated | Corporate and Other | Discontinued Operations (a) | Total | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Net Income | $ | 468 | $ | 445 | $ | (895) | $ | (1,498) | $ | (1,480) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Less: Special Items (expense) benefit: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Income (loss) from Discontinued Operations (a) | — | — | — | (1,502) | (1,502) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Talen litigation costs, net of tax of $4 (b) | — | — | (16) | — | (16) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Strategic corporate initiatives, net of tax of $0, $0, $2 (c) | (1) | — | (8) | — | (9) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Valuation allowance adjustment (d) | 4 | — | (4) | 4 | 4 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Transmission formula rate return on equity settlement, net of tax of $8 | — | (20) | — | — | (20) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Acquisition integration, net of tax of $6 (e) | — | — | (22) | — | (22) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.K. tax rate change (f) | — | — | (383) | — | (383) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Solar panel impairment, net of tax of $9 (g) | — | — | (26) | — | (26) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Loss on early extinguishment of debt, net of tax of $83 (h) | — | — | (312) | — | (312) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total Special Items | 3 | (20) | (771) | (1,498) | (2,286) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Earnings from Ongoing Operations | $ | 465 | $ | 465 | $ | (124) | $ | — | $ | 806 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2020 | |||||||||||||||||||||||||||||||||||
| KY Regulated | PA Regulated | Corporate and Other (j) | Discontinued Operations (a) | Total | |||||||||||||||||||||||||||||||
| Net Income | $ | 418 | $ | 497 | $ | (275) | 829 | $ | 1,469 | ||||||||||||||||||||||||||
| Less: Special Items (expense) benefit: | |||||||||||||||||||||||||||||||||||
| Income (loss) from Discontinued Operations (a) | — | — | — | 829 | 829 | ||||||||||||||||||||||||||||||
| Talen litigation costs, net of tax of $3 (b) | — | — | (13) | — | (13) | ||||||||||||||||||||||||||||||
| COVID-19 impact, net of tax of $2, $0, $0 | (5) | (1) | (1) | — | (7) | ||||||||||||||||||||||||||||||
| U.K. tax rate change (f) | — | — | (102) | — | (102) | ||||||||||||||||||||||||||||||
| Strategic corporate initiatives, net of tax of $2 (c) | — | — | (6) | — | (6) | ||||||||||||||||||||||||||||||
| Executive retirement benefits, net of tax of $2 (i) | — | — | (6) | — | (6) | ||||||||||||||||||||||||||||||
| Total Special Items | (5) | (1) | (128) | 829 | 695 | ||||||||||||||||||||||||||||||
| Earnings from Ongoing Operations | $ | 423 | $ | 498 | $ | (147) | $ | — | $ | 774 | |||||||||||||||||||||||||
(a)See Note 9 to the Financial Statements for additional information.
(b)PPL incurred legal expenses related to litigation with its former affiliate, Talen Montana. See Note 14 to the Financial Statements for additional information.
(c)Costs incurred for 2021 are related to the sale of the U.K. utility business and PPL’s strategic repositioning. Costs incurred for 2020 are related to the process to sell the U.K. utility business.
(d)Adjustment of valuation allowances related to certain tax credits recorded in 2017 as a result of the TCJA.
| 2017 | |||||||||||||||||||
| U.K. Regulated | KY Regulated | PA Regulated | Corporate and Other | Total | |||||||||||||||
| Net Income | $ | 652 | $ | 286 | $ | 359 | $ | (169 | ) | $ | 1,128 | ||||||||
| Less: Special Items (expense) benefit: | |||||||||||||||||||
| Foreign currency economic hedges, net of tax of $59 | (111 | ) | — | — | — | (111 | ) | ||||||||||||
| Spinoff of the Supply segment, net of tax of ($1) | — | — | — | 4 | 4 | ||||||||||||||
| Other: | |||||||||||||||||||
| U.S. tax reform (a) | (122 | ) | (112 | ) | 10 | (97 | ) | (321 | ) | ||||||||||
| Adjustment to investment, net of tax of $0 | — | (1 | ) | — | — | (1 | ) | ||||||||||||
| Settlement of indemnification agreement, net of tax of ($2) | — | 4 | — | — | 4 | ||||||||||||||
| Total Special Items | (233 | ) | (109 | ) | 10 | (93 | ) | (425 | ) | ||||||||||
| Earnings from Ongoing Operations | $ | 885 | $ | 395 | $ | 349 | $ | (76 | ) | $ | 1,553 | ||||||||
(f)Impact of the U.K. Finance Acts on deferred tax balances. See Note 6 to the Financial Statements for additional information.
| 2016 | |||||||||||||||||||
| U.K. Regulated | KY Regulated | PA Regulated | Corporate and Other | Total | |||||||||||||||
| Net Income | $ | 1,246 | $ | 398 | $ | 338 | $ | (80 | ) | $ | 1,902 | ||||||||
| Less: Special Items (expense) benefit: | |||||||||||||||||||
| Foreign currency economic hedges, net of tax of $4 | (8 | ) | — | — | — | (8 | ) | ||||||||||||
| Spinoff of the Supply segment, net of tax of $2 | — | — | — | (3 | ) | (3 | ) | ||||||||||||
| Other: | |||||||||||||||||||
| Settlement of foreign currency contracts, net of tax of ($108) | 202 | — | — | — | 202 | ||||||||||||||
| Change in U.K. tax rate | 37 | — | — | — | 37 | ||||||||||||||
| Total Special Items | 231 | — | — | (3 | ) | 228 | |||||||||||||
| Earnings from Ongoing Operations | $ | 1,015 | $ | 398 | $ | 338 | $ | (77 | ) | $ | 1,674 | ||||||||
(h)See Note 8 to the Financial Statements for additional information.
| 2015 | |||||||||||||||||||||||
U.K. Regulated | KY Regulated | PA Regulated | Corporate and Other | Discontinued Operations | Total | ||||||||||||||||||
| Net Income | $ | 1,121 | $ | 326 | $ | 252 | $ | (96 | ) | $ | (921 | ) | $ | 682 | |||||||||
| Less: Special Items (expense) benefit: | |||||||||||||||||||||||
| Foreign currency economic hedges, net of tax of ($30) | 55 | — | — | — | — | 55 | |||||||||||||||||
| Spinoff of the Supply segment: | |||||||||||||||||||||||
| Discontinued operations, net of tax of $30 | — | — | — | — | (921 | ) | (921 | ) | |||||||||||||||
| Transition and transaction costs, net of tax of $6 | — | — | — | (12 | ) | — | (12 | ) | |||||||||||||||
| Employee transitional services, net of tax of $2 | — | — | — | (5 | ) | — | (5 | ) | |||||||||||||||
| Separation benefits, net of tax of $3 | — | — | — | (5 | ) | — | (5 | ) | |||||||||||||||
| Other | |||||||||||||||||||||||
| Change in U.K. tax rate | 78 | — | — | — | — | 78 | |||||||||||||||||
| Settlement of certain income tax positions | 18 | — | — | — | — | 18 | |||||||||||||||||
| WPD Midlands acquisition-related adjustment, net of tax of ($1) | 2 | — | — | — | — | 2 | |||||||||||||||||
| Certain income tax valuation allowances | — | (12 | ) | — | — | — | (12 | ) | |||||||||||||||
| LKE acquisition-related adjustment, net of tax of $0 | — | (5 | ) | — | — | — | (5 | ) | |||||||||||||||
| Total Special Items | 153 | (17 | ) | — | (22 | ) | (921 | ) | (807 | ) | |||||||||||||
| Earnings from Ongoing Operations | $ | 968 | $ | 343 | $ | 252 | $ | (74 | ) | $ | — | $ | 1,489 | ||||||||||
(j)The amounts for 2020 have been adjusted for certain costs that were previously included in the U.K. Regulated segment.
Adjusted Gross Margins
Management also utilizes the following non-GAAP financial measures as indicators of performance for its businesses.
•"Kentucky Adjusted Gross Margins" is a single financial performance measure of the electricity generation, transmission and distribution operations of the Kentucky Regulated segment, LKE, LG&E and KU, as well as the Kentucky Regulated segment's LKE's and LG&E's distribution and sale of natural gas. In calculating this measure, fuel, energy purchases and certain variable costs of production (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues. In addition, certain other expenses, recorded in "Other operation and maintenance", "Depreciation" and "Taxes, other than income" on the Statements of Income, associated with approved cost recovery mechanisms are offset against the recovery of those expenses, which are included in revenues. These mechanisms allow for direct recovery of these expenses and, in some cases, returns on capital investments and performance incentives. As a result, this measure represents the net revenues from electricity and gas operations.
•"Pennsylvania Adjusted Gross Margins" is a single financial performance measure of the electricity transmission and distribution operations of the Pennsylvania Regulated segment and PPL Electric.segment. In calculating this measure, utility revenues and expenses associated with approved recovery mechanisms, including energy provided as a PLR, are offset with minimal impact on earnings. Costs associated with these mechanisms are recorded in "Energy purchases," "Other operation and maintenance," (which are primarily Act 129, Storm Damage and Universal Service program costs), "Depreciation" (which is primarily related to the Act 129 Smart Meter program) and "Taxes, other than income," (which is primarily gross receipts tax) on the Statements of Income. This performance measure includes PLR energy purchases by PPL Electric from PPL EnergyPlus, which are reflected in "Energy purchases from affiliate" in the 2015 reconciliation table. As a result of the June 2015 spinoff of PPL Energy Supply and the formation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL Electric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are reflected in "Energy Purchases" in the reconciliation tables. This measure represents the net revenues from the Pennsylvania Regulated segment's and PPL Electric's electricity delivery operations.
These measures are not intended to replace "Operating Income," which is determined in accordance with GAAP, as an indicator of overall operating performance. Other companies may use different measures to analyze and report their results of operations. Management believes these measures provide additional useful criteria to make investment decisions. These performance measures are used, in conjunction with other information, by senior management and PPL's Board of Directors to manage operations and analyze actual results compared with budget.
Changes in Adjusted Gross Margins
The following table shows Adjusted Gross Margins by PPL's reportable segmentssegment and by component, as applicable, for the year ended December 31 as well as the changes between periods. The factors that gave rise to the changes are described following the table.
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| U.K. Regulated | |||||||||||||||||||
| U.K. Gross Margins | $ | 1,952 | $ | 2,067 | $ | 2,243 | $ | (115 | ) | $ | (176 | ) | |||||||
| Impact of changes in foreign currency exchange rates | (145 | ) | (238 | ) | |||||||||||||||
| U.K. Gross Margins excluding impact of foreign currency exchange rates | $ | 30 | $ | 62 | |||||||||||||||
| Kentucky Regulated | |||||||||||||||||||
| Kentucky Gross Margins | |||||||||||||||||||
| LG&E | $ | 910 | $ | 887 | $ | 867 | $ | 23 | $ | 20 | |||||||||
| KU | 1,128 | 1,122 | 1,059 | 6 | 63 | ||||||||||||||
| Total Kentucky Gross Margins | $ | 2,038 | $ | 2,009 | $ | 1,926 | $ | 29 | $ | 83 | |||||||||
| Pennsylvania Regulated | |||||||||||||||||||
| Pennsylvania Gross Margins | |||||||||||||||||||
| Distribution | $ | 958 | $ | 960 | $ | 842 | $ | (2 | ) | $ | 118 | ||||||||
| Transmission | 487 | 454 | 395 | 33 | 59 | ||||||||||||||
| Total Pennsylvania Gross Margins | $ | 1,445 | $ | 1,414 | $ | 1,237 | $ | 31 | $ | 177 | |||||||||
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Kentucky Regulated | |||||||||||||||||
| Kentucky Adjusted Gross Margins | $ | 2,255 | $ | 2,081 | $ | 174 | |||||||||||
| Pennsylvania Regulated | |||||||||||||||||
| Pennsylvania Adjusted Gross Margins | |||||||||||||||||
| Distribution | $ | 915 | $ | 907 | $ | 8 | |||||||||||
| Transmission | 674 | 682 | (8) | ||||||||||||||
| Total Pennsylvania Adjusted Gross Margins | $ | 1,589 | $ | 1,589 | $ | — | |||||||||||
Kentucky Gross Margins
The increasesincrease in base rates werewas the result of new rates approved by the KPSC effective July 1, 2017.2021. The environmental and gas cost recoveries added to base rates were the result of the transfer of certain ECR and GLT expenses into base rates as a result of the 20162020 Kentucky rate case. This transfer results in depreciation and other operation and maintenance expenses associated with the ECR and GLT programprograms being excluded from margins in the second half of 2017,2021, while the recovery of such costs remain in Kentucky Gross Margins through base rates.
Distribution
Distribution Adjusted Gross Margins increased in 20162021 compared with 20152020. Higher sales volumes of $13 million were partially offset by $8 million of lower returns on distribution system improvement capital investments.
Transmission
Transmission Adjusted Gross Margins decreased in 2021 compared with 2020, primarily due to higher base rates of $68a $28 million ($4 million at LG&E and $64 million at KU) and returns on additional environmental capital investments of $13 million at LG&E. The increases in base rates were the result of new rates approved by the KPSC effective July 1, 2015.
Reconciliation of Adjusted Gross Margins
The following tables contain the components from the Statement of Income that are included in the non-GAAP financial measures and a reconciliation to PPL's "Operating Income" for the years ended December 31. 31:
| 2021 | |||||||||||||||||||||||||||||
| Kentucky Adjusted Gross Margins | Pennsylvania Adjusted Gross Margins | Other (a) | Operating Income (b) | ||||||||||||||||||||||||||
| Operating Revenues | $ | 3,348 | $ | 2,430 | $ | 5 | $ | 5,783 | |||||||||||||||||||||
| Operating Expenses | |||||||||||||||||||||||||||||
| Fuel | 710 | — | — | 710 | |||||||||||||||||||||||||
| Energy purchases | 186 | 566 | — | 752 | |||||||||||||||||||||||||
| Other operation and maintenance | 88 | 111 | 1,409 | 1,608 | |||||||||||||||||||||||||
| Depreciation | 105 | 52 | 925 | 1,082 | |||||||||||||||||||||||||
| Taxes, other than income | 4 | 112 | 91 | 207 | |||||||||||||||||||||||||
| Total Operating Expenses | 1,093 | 841 | 2,425 | 4,359 | |||||||||||||||||||||||||
| Total | $ | 2,255 | $ | 1,589 | $ | (2,420) | $ | 1,424 | |||||||||||||||||||||
| 2020 | |||||||||||||||||||||||||||||
| Kentucky Adjusted Gross Margins | Pennsylvania Adjusted Gross Margins | Other (a) | Operating Income (b) | ||||||||||||||||||||||||||
| Operating Revenues | $ | 3,106 | $ | 2,331 | $ | 37 | $ | 5,474 | |||||||||||||||||||||
| Operating Expenses | |||||||||||||||||||||||||||||
| Fuel | 632 | — | — | 632 | |||||||||||||||||||||||||
| Energy purchases | 143 | 491 | — | 634 | |||||||||||||||||||||||||
| Other operation and maintenance | 91 | 91 | 1,238 | 1,420 | |||||||||||||||||||||||||
| Depreciation | 154 | 53 | 815 | 1,022 | |||||||||||||||||||||||||
| Taxes, other than income | 5 | 107 | 68 | 180 | |||||||||||||||||||||||||
| Total Operating Expenses | 1,025 | 742 | 2,121 | 3,888 | |||||||||||||||||||||||||
| Total | $ | 2,081 | $ | 1,589 | $ | (2,084) | $ | 1,586 | |||||||||||||||||||||
| 2017 | |||||||||||||||||||
U.K. Gross Margins | Kentucky Gross Margins | PA Gross Margins | Other (a) | Operating Income (b) | |||||||||||||||
| Operating Revenues | $ | 2,050 | (c) | $ | 3,156 | $ | 2,195 | $ | 46 | $ | 7,447 | ||||||||
| Operating Expenses | |||||||||||||||||||
| Fuel | — | 759 | — | — | 759 | ||||||||||||||
| Energy purchases | — | 178 | 507 | — | 685 | ||||||||||||||
| Other operation and maintenance | 98 | 111 | 120 | 1,306 | 1,635 | ||||||||||||||
| Depreciation | — | 64 | 21 | 923 | 1,008 | ||||||||||||||
| Taxes, other than income | — | 6 | 102 | 184 | 292 | ||||||||||||||
| Total Operating Expenses | 98 | 1,118 | 750 | 2,413 | 4,379 | ||||||||||||||
| Total | $ | 1,952 | $ | 2,038 | $ | 1,445 | $ | (2,367 | ) | $ | 3,068 | ||||||||
| 2016 | |||||||||||||||||||
U.K. Gross Margins | Kentucky Gross Margins | PA Gross Margins | Other (a) | Operating Income (b) | |||||||||||||||
| Operating Revenues | $ | 2,165 | (c) | $ | 3,141 | $ | 2,156 | $ | 55 | $ | 7,517 | ||||||||
| Operating Expenses | |||||||||||||||||||
| Fuel | — | 791 | — | — | 791 | ||||||||||||||
| Energy purchases | — | 171 | 535 | — | 706 | ||||||||||||||
| Other operation and maintenance | 98 | 109 | 108 | 1,430 | 1,745 | ||||||||||||||
| Depreciation | — | 56 | — | 870 | 926 | ||||||||||||||
| Taxes, other than income | — | 5 | 99 | 197 | 301 | ||||||||||||||
| Total Operating Expenses | 98 | 1,132 | 742 | 2,497 | 4,469 | ||||||||||||||
| Total | $ | 2,067 | $ | 2,009 | $ | 1,414 | $ | (2,442 | ) | $ | 3,048 | ||||||||
| 2015 | |||||||||||||||||||
U.K. Gross Margins | Kentucky Gross Margins | PA Gross Margins | Other (a) | Operating Income (b) | |||||||||||||||
| Operating Revenues | $ | 2,364 | (c) | $ | 3,115 | $ | 2,124 | $ | 66 | $ | 7,669 | ||||||||
| Operating Expenses | |||||||||||||||||||
| Fuel | — | 863 | — | — | 863 | ||||||||||||||
| Energy purchases | — | 184 | 657 | 14 | 855 | ||||||||||||||
| Energy purchases from affiliate | — | — | 14 | (14 | ) | — | |||||||||||||
| Other operation and maintenance | 121 | 100 | 114 | 1,603 | 1,938 | ||||||||||||||
| Depreciation | — | 38 | — | 845 | 883 | ||||||||||||||
| Taxes, other than income | — | 4 | 102 | 193 | 299 | ||||||||||||||
| Total Operating Expenses | 121 | 1,189 | 887 | 2,641 | 4,838 | ||||||||||||||
| Total | $ | 2,243 | $ | 1,926 | $ | 1,237 | $ | (2,575 | ) | $ | 2,831 | ||||||||
PPL Electric: Statement of Income Analysis Earnings and Margins
Net income for the years ended December 31 includes the following results.results:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Operating Revenues | $ | 2,402 | $ | 2,331 | $ | 71 | |||||||||||
| Operating Expenses | |||||||||||||||||
| Operation | |||||||||||||||||
| Energy purchases | 566 | 491 | 75 | ||||||||||||||
| Other operation and maintenance | 557 | 513 | 44 | ||||||||||||||
| Depreciation | 424 | 403 | 21 | ||||||||||||||
| Taxes, other than income | 120 | 107 | 13 | ||||||||||||||
| Total Operating Expenses | 1,667 | 1,514 | 153 | ||||||||||||||
| Other Income (Expense) - net | 21 | 18 | 3 | ||||||||||||||
| Interest Income from Affiliate | 5 | 2 | 3 | ||||||||||||||
| Interest Expense | 162 | 173 | (11) | ||||||||||||||
| Income Taxes | 154 | 167 | (13) | ||||||||||||||
| Net Income | $ | 445 | $ | 497 | $ | (52) | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating Revenues | $ | 2,195 | $ | 2,156 | $ | 2,124 | $ | 39 | $ | 32 | |||||||||
| Operating Expenses | |||||||||||||||||||
| Operation | |||||||||||||||||||
| Energy purchases | 507 | 535 | 657 | (28 | ) | (122 | ) | ||||||||||||
| Energy purchases from affiliate | — | — | 14 | — | (14 | ) | |||||||||||||
| Other operation and maintenance | 571 | 599 | 607 | (28 | ) | (8 | ) | ||||||||||||
| Depreciation | 309 | 253 | 214 | 56 | 39 | ||||||||||||||
| Taxes, other than income | 107 | 105 | 94 | 2 | 11 | ||||||||||||||
| Total Operating Expenses | 1,494 | 1,492 | 1,586 | 2 | (94 | ) | |||||||||||||
| Other Income (Expense) - net | 11 | 17 | 8 | (6 | ) | 9 | |||||||||||||
| Interest Income from Affiliate | 5 | — | — | 5 | — | ||||||||||||||
| Interest Expense | 142 | 129 | 130 | 13 | (1 | ) | |||||||||||||
| Income Taxes | 213 | 212 | 164 | 1 | 48 | ||||||||||||||
| Net Income | $ | 362 | $ | 340 | $ | 252 | $ | 22 | $ | 88 | |||||||||
Operating Revenues
The increase (decrease) in operating revenues was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Distribution Price (a) | $ | 53 | $ | 126 | |||
| Distribution volume | (21 | ) | (9 | ) | |||
| PLR (b) | (16 | ) | (135 | ) | |||
| Transmission Formula Rate | 34 | 59 | |||||
| Other | (11 | ) | (9 | ) | |||
| Total | $ | 39 | $ | 32 | |||
| 2021 vs. 2020 | |||||
| Distribution price (a) | $ | 5 | |||
| Distribution volume | 19 | ||||
| PLR (b) | 83 | ||||
| Transmission Formula Rate (c) | (35) | ||||
| (1) | |||||
| 71 | |||||
(a) Distribution price variance was primarily due to reconcilable cost recovery mechanisms approved by the PUC.
(b) The increase was primarily the result of higher energy prices and higher customer usage, partially offset by higher volumes of shopping customers.
(c) The decrease was primarily due to a reduction in the transmission formula rate return on equity and a lower PPL zonal peak load billing factor, partially offset by returns on additional transmission capital investments and return of related depreciation expense. See Note 7 to the Financial Statements for additional information on the transmission formula rate return on equity reduction.
40
Energy Purchases
Energy purchases decreased $28increased $75 million in 20172021 compared with 2016 and $122 million in 2016 compared with 20152020. This increase was primarily due to lowerhigher PLR prices.prices of $40 million and higher PLR volumes of $28 million.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Act 129 | $ | 9 | $ | (15 | ) | ||
| Universal service programs | (3 | ) | 3 | ||||
| Contractor-related expenses | (4 | ) | 7 | ||||
| Vegetation management | (17 | ) | 4 | ||||
| Payroll-related costs | (12 | ) | (26 | ) | |||
| Corporate service costs | 19 | 8 | |||||
| Storm costs | 5 | 9 | |||||
| Bad debts | (17 | ) | (4 | ) | |||
| Environmental costs | — | (6 | ) | ||||
| Other | (8 | ) | 12 | ||||
| Total | $ | (28 | ) | $ | (8 | ) | |
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Change in pre-tax income at current period tax rates | $ | 10 | $ | 58 | |||
| Depreciation not normalized | — | (5 | ) | ||||
| Deferred tax impact of U.S. tax reform (a) | (13 | ) | — | ||||
| Stock-based compensation (b) | 4 | (6 | ) | ||||
| Other | — | 1 | |||||
| Total | $ | 1 | $ | 48 | |||
| 2021 vs. 2020 | |||||
| 20 | |||||
| Support costs | 20 | ||||
| 2017 | 2016 | 2015 | |||||||||
| Net Income | $ | 362 | $ | 340 | $ | 252 | |||||
| Special item, gain (loss), after-tax | 10 | — | — | ||||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Pennsylvania Gross Margins | $ | 31 | $ | 177 | |||
| Other operation and maintenance | 40 | 2 | |||||
| Depreciation | (35 | ) | (39 | ) | |||
| Taxes, other than income | 1 | (14 | ) | ||||
| Other Income (Expense) - net | (1 | ) | 9 | ||||
| Interest Expense | (13 | ) | 1 | ||||
| Income Taxes | (11 | ) | (48 | ) | |||
| Special Item, after-tax | 10 | — | |||||
| Net Income | $ | 22 | $ | 88 | |||
| 2017 | 2016 | ||||||||||||||||||||||
PA Gross Margins | Other (a) | Operating Income (b) | PA Gross Margins | Other (a) | Operating Income (b) | ||||||||||||||||||
| Operating Revenues | $ | 2,195 | $ | — | $ | 2,195 | $ | 2,156 | $ | — | $ | 2,156 | |||||||||||
| Operating Expenses | |||||||||||||||||||||||
| Energy purchases | 507 | — | 507 | 535 | — | 535 | |||||||||||||||||
| Other operation and maintenance | 120 | 451 | 571 | 108 | 491 | 599 | |||||||||||||||||
| Depreciation | 21 | 288 | 309 | — | 253 | 253 | |||||||||||||||||
| Taxes, other than income | 102 | 5 | 107 | 99 | 6 | 105 | |||||||||||||||||
| Total Operating Expenses | 750 | 744 | 1,494 | 742 | 750 | 1,492 | |||||||||||||||||
| Total | $ | 1,445 | $ | (744 | ) | $ | 701 | $ | 1,414 | $ | (750 | ) | $ | 664 | |||||||||
| 2015 | |||||||||||
| PA Gross Margins | Other (a) | Operating Income (b) | |||||||||
| Operating Revenues | $ | 2,124 | $ | — | $ | 2,124 | |||||
| Operating Expenses | |||||||||||
| Energy purchases | 657 | — | 657 | ||||||||
| Energy purchases from affiliate | 14 | — | 14 | ||||||||
| Other operation and maintenance | 114 | 493 | 607 | ||||||||
| Depreciation | — | 214 | 214 | ||||||||
| Taxes, other than income | 102 | (8 | ) | 94 | |||||||
| Total Operating Expenses | 887 | 699 | 1,586 | ||||||||
| Total | $ | 1,237 | $ | (699 | ) | $ | 538 | ||||
| Inventory adjustments | 9 | ||||
| Canceled projects | (10) | ||||
| Other | (2) | ||||
| Total | $ | 44 | |||
LG&E: Statement of Income Analysis
Net income for the years ended December 31 includes the following results.results:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Operating Revenues | |||||||||||||||||
| Retail and wholesale | $ | 1,545 | $ | 1,435 | $ | 110 | |||||||||||
| Electric revenue from affiliate | 24 | 21 | 3 | ||||||||||||||
| Total Operating Revenues | 1,569 | 1,456 | 113 | ||||||||||||||
| Operating Expenses | |||||||||||||||||
| Operation | |||||||||||||||||
| Fuel | 265 | 246 | 19 | ||||||||||||||
| Energy purchases | 167 | 125 | 42 | ||||||||||||||
| Energy purchases from affiliates | 23 | 19 | 4 | ||||||||||||||
| Other operation and maintenance | 400 | 373 | 27 | ||||||||||||||
| Depreciation | 279 | 259 | 20 | ||||||||||||||
| Taxes, other than income | 46 | 40 | 6 | ||||||||||||||
| Total Operating Expenses | 1,180 | 1,062 | 118 | ||||||||||||||
| Other Income (Expense) - net | (5) | (1) | (4) | ||||||||||||||
| Interest Expense | 81 | 87 | (6) | ||||||||||||||
| Income Taxes | 54 | 62 | (8) | ||||||||||||||
| Net Income | $ | 249 | $ | 244 | $ | 5 | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating Revenues | $ | 3,156 | $ | 3,141 | $ | 3,115 | $ | 15 | $ | 26 | |||||||||
| Operating Expenses | |||||||||||||||||||
| Operation | |||||||||||||||||||
| Fuel | 759 | 791 | 863 | (32 | ) | (72 | ) | ||||||||||||
| Energy purchases | 178 | 171 | 184 | 7 | (13 | ) | |||||||||||||
| Other operation and maintenance | 806 | 804 | 837 | 2 | (33 | ) | |||||||||||||
| Depreciation | 439 | 404 | 382 | 35 | 22 | ||||||||||||||
| Taxes, other than income | 65 | 62 | 57 | 3 | 5 | ||||||||||||||
| Total Operating Expenses | 2,247 | 2,232 | 2,323 | 15 | (91 | ) | |||||||||||||
| Other Income (Expense) - net | (3 | ) | (9 | ) | (8 | ) | 6 | (1 | ) | ||||||||||
| Interest Expense | 197 | 197 | 178 | — | 19 | ||||||||||||||
| Interest Expense with Affiliate | 18 | 17 | 3 | 1 | 14 | ||||||||||||||
| Income Taxes | 375 | 257 | 239 | 118 | 18 | ||||||||||||||
| Net Income | $ | 316 | $ | 429 | $ | 364 | $ | (113 | ) | $ | 65 | ||||||||
Operating Revenues
The increase (decrease) in operating revenues was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Base rates | $ | 58 | $ | 68 | |||
| Volumes (a) | (73 | ) | 1 | ||||
| Fuel and other energy prices (b) | 10 | (81 | ) | ||||
| ECR | 10 | 39 | |||||
| Other | 10 | (1 | ) | ||||
| Total | $ | 15 | $ | 26 | |||
| Fuel and other energy prices (a) | $ | 54 | |||
| Retail rates (b) | |||||
| Volumes (c) | 27 | ||||
| Economic relief billing credit, net of | (12) | ||||
| ECR | (6) | ||||
| Other | 4 | ||||
| Total | $ | 113 | |||
(a)The increases were primarily due to higher recoveries of fuel and energy purchases due to higher commodity costs.
41
(b)The increases were due to new base rates approved by the KPSC effective July 1, 2021.
(c)The increases were primarily due to favorable weather.
Fuel
Fuel decreased $32increased $19 million in 20172021 compared with 20162020, primarily due to a decrease$10 million increase in fuel usagevolumes driven by milder weather and an $8 million increase in 2017.commodity costs.
Energy purchases increased $42 million in 20162021 compared with 20152020, primarily due to a decrease$35 million increase in market prices for coalcommodity costs and natural gas.a $6 million increase in gas volumes driven by weather.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Plant operations and maintenance (a) | $ | (2 | ) | $ | (19 | ) | |
| Pension expense | 1 | (12 | ) | ||||
| Timing and scope of scheduled generation maintenance outages | (1 | ) | (5 | ) | |||
| Storm costs | (1 | ) | (3 | ) | |||
| Bad debts | — | (1 | ) | ||||
| Energy efficiency programs | — | 5 | |||||
| Other | 5 | 2 | |||||
| Total | $ | 2 | $ | (33 | ) | ||
| Plant operations and | $ | 10 | ||||||
| Administrative and general | 10 | |||||||
| Other | 7 | |||||||
| Total | $ | 27 | ||||||
Depreciation
Depreciation increased $35$20 million in 20172021 compared with 20162020, primarily due to a $19$13 million increase related to additions to PP&E,additional assets placed into service, net of retirements and a $15$7 million increase related to higher depreciation rates effective July 1, 2017.2021.
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Change in pre-tax income at current period tax rates | $ | 2 | $ | 32 | |||
| Certain income tax valuation allowances | — | (12 | ) | ||||
| U.S. tax reform (a) | 112 | — | |||||
| Other | 4 | (2 | ) | ||||
| Total | $ | 118 | $ | 18 | |||
| 2017 | 2016 | 2015 | |||||||||
| Net Income | $ | 316 | $ | 429 | $ | 364 | |||||
| Special items, gains (losses), after-tax | (109 | ) | — | (12 | ) | ||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Margins | $ | 29 | $ | 83 | |||
| Other operation and maintenance | — | 42 | |||||
| Depreciation | (27 | ) | (4 | ) | |||
| Taxes, Other than income | (2 | ) | (4 | ) | |||
| Other Income (Expense) - net | 1 | (1 | ) | ||||
| Interest Expense | (1 | ) | (33 | ) | |||
| Income Taxes | (4 | ) | (30 | ) | |||
| Special items, gains (losses), after-tax (a) | (109 | ) | 12 | ||||
| Net Income | $ | (113 | ) | $ | 65 | ||
| 2017 | 2016 | ||||||||||||||||||||||
| Margins | Other (a) | Operating Income (b) | Margins | Other (a) | Operating Income (b) | ||||||||||||||||||
| Operating Revenues | $ | 3,156 | $ | — | $ | 3,156 | $ | 3,141 | $ | — | $ | 3,141 | |||||||||||
| Operating Expenses | |||||||||||||||||||||||
| Fuel | 759 | — | 759 | 791 | — | 791 | |||||||||||||||||
| Energy purchases | 178 | — | 178 | 171 | — | 171 | |||||||||||||||||
| Other operation and maintenance | 111 | 695 | 806 | 109 | 695 | 804 | |||||||||||||||||
| Depreciation | 64 | 375 | 439 | 56 | 348 | 404 | |||||||||||||||||
| Taxes, other than income | 6 | 59 | 65 | 5 | 57 | 62 | |||||||||||||||||
| Total Operating Expenses | 1,118 | 1,129 | 2,247 | 1,132 | 1,100 | 2,232 | |||||||||||||||||
| Total | $ | 2,038 | $ | (1,129 | ) | $ | 909 | $ | 2,009 | $ | (1,100 | ) | $ | 909 | |||||||||
| 2015 | |||||||||||
| Margins | Other (a) | Operating Income (b) | |||||||||
| Operating Revenues | $ | 3,115 | $ | — | $ | 3,115 | |||||
| Operating Expenses | |||||||||||
| Fuel | 863 | — | 863 | ||||||||
| Energy purchases | 184 | — | 184 | ||||||||
| Other operation and maintenance | 100 | 737 | 837 | ||||||||
| Depreciation | 38 | 344 | 382 | ||||||||
| Taxes, other than income | 4 | 53 | 57 | ||||||||
| Total Operating Expenses | 1,189 | 1,134 | 2,323 | ||||||||
| Total | $ | 1,926 | $ | (1,134 | ) | $ | 792 | ||||
KU: Statement of Income Analysis
Net income for the years ended December 31 includes the following results.results:
| Change | |||||||||||||||||
| 2021 | 2020 | 2021 vs. 2020 | |||||||||||||||
| Operating Revenues | |||||||||||||||||
| Retail and wholesale | $ | 1,803 | $ | 1,671 | $ | 132 | |||||||||||
| Electric revenue from affiliate | 23 | 19 | 4 | ||||||||||||||
| Total Operating Revenues | 1,826 | 1,690 | 136 | ||||||||||||||
| Operating Expenses | |||||||||||||||||
| Operation | |||||||||||||||||
| Fuel | 445 | 386 | 59 | ||||||||||||||
| Energy purchases | 19 | 18 | 1 | ||||||||||||||
| Energy purchases from affiliates | 24 | 21 | 3 | ||||||||||||||
| Other operation and maintenance | 463 | 429 | 34 | ||||||||||||||
| Depreciation | 366 | 346 | 20 | ||||||||||||||
| Taxes, other than income | 41 | 37 | 4 | ||||||||||||||
| Total Operating Expenses | 1,358 | 1,237 | 121 | ||||||||||||||
| Other Income (Expense) - net | 4 | 3 | 1 | ||||||||||||||
| Interest Expense | 109 | 113 | (4) | ||||||||||||||
| Income Taxes | 67 | 63 | 4 | ||||||||||||||
| Net Income | $ | 296 | $ | 280 | $ | 16 | |||||||||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating Revenues | |||||||||||||||||||
| Retail and wholesale | $ | 1,422 | $ | 1,406 | $ | 1,407 | $ | 16 | $ | (1 | ) | ||||||||
| Electric revenue from affiliate | 31 | 24 | 37 | 7 | (13 | ) | |||||||||||||
| Total Operating Revenues | 1,453 | 1,430 | 1,444 | 23 | (14 | ) | |||||||||||||
| Operating Expenses | |||||||||||||||||||
| Operation | |||||||||||||||||||
| Fuel | 292 | 301 | 329 | (9 | ) | (28 | ) | ||||||||||||
| Energy purchases | 160 | 153 | 166 | 7 | (13 | ) | |||||||||||||
| Energy purchases from affiliates | 10 | 14 | 20 | (4 | ) | (6 | ) | ||||||||||||
| Other operation and maintenance | 355 | 355 | 377 | — | (22 | ) | |||||||||||||
| Depreciation | 183 | 170 | 162 | 13 | 8 | ||||||||||||||
| Taxes, other than income | 33 | 32 | 28 | 1 | 4 | ||||||||||||||
| Total Operating Expenses | 1,033 | 1,025 | 1,082 | 8 | (57 | ) | |||||||||||||
| Other Income (Expense) - net | (5 | ) | (5 | ) | (6 | ) | — | 1 | |||||||||||
| Interest Expense | 71 | 71 | 57 | — | 14 | ||||||||||||||
| Income Taxes | 131 | 126 | 114 | 5 | 12 | ||||||||||||||
| Net Income | $ | 213 | $ | 203 | $ | 185 | $ | 10 | $ | 18 | |||||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Base rates | $ | 32 | $ | 4 | |||
| Volumes (a) | (20 | ) | (8 | ) | |||
| Fuel and other energy prices (b) | — | (36 | ) | ||||
| ECR | 5 | 26 | |||||
| Other | 6 | — | |||||
| Total | $ | 23 | $ | (14 | ) | ||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Plant operations and maintenance (a) | $ | (1 | ) | $ | (21 | ) | |
| Pension expense | 1 | (6 | ) | ||||
| Timing and scope of scheduled generation maintenance outages | — | 3 | |||||
| Storm costs | (1 | ) | (2 | ) | |||
| Energy efficiency programs | — | 2 | |||||
| Other | 1 | 2 | |||||
| Total | $ | — | $ | (22 | ) | ||
| 2017 | 2016 | 2015 | |||||||||
| Net Income | $ | 213 | $ | 203 | $ | 185 | |||||
| Special items, gains (losses), after-tax (a) | — | — | — | ||||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Margins | $ | 23 | $ | 20 | |||
| Other operation and maintenance | 2 | 23 | |||||
| Depreciation | (10 | ) | 3 | ||||
| Taxes, other than income | — | (3 | ) | ||||
| Other Income (Expense) - net | — | 1 | |||||
| Interest Expense | — | (14 | ) | ||||
| Income Taxes | (5 | ) | (12 | ) | |||
| Net Income | $ | 10 | $ | 18 | |||
| 2017 | 2016 | ||||||||||||||||||||||
| Margins | Other (a) | Operating Income (b) | Margins | Other (a) | Operating Income (b) | ||||||||||||||||||
| Operating Revenues | $ | 1,453 | $ | — | $ | 1,453 | $ | 1,430 | $ | — | $ | 1,430 | |||||||||||
| Operating Expenses | |||||||||||||||||||||||
| Fuel | 292 | — | 292 | 301 | — | 301 | |||||||||||||||||
| Energy purchases | 170 | — | 170 | 167 | — | 167 | |||||||||||||||||
| Other operation and maintenance | 45 | 310 | 355 | 43 | 312 | 355 | |||||||||||||||||
| Depreciation | 32 | 151 | 183 | 29 | 141 | 170 | |||||||||||||||||
| Taxes, other than income | 4 | 29 | 33 | 3 | 29 | 32 | |||||||||||||||||
| Total Operating Expenses | 543 | 490 | 1,033 | 543 | 482 | 1,025 | |||||||||||||||||
| Total | $ | 910 | $ | (490 | ) | $ | 420 | $ | 887 | $ | (482 | ) | $ | 405 | |||||||||
| 2015 | |||||||||||
| Margins | Other (a) | Operating Income (b) | |||||||||
| Operating Revenues | $ | 1,444 | $ | — | $ | 1,444 | |||||
| Operating Expenses | |||||||||||
| Fuel | 329 | — | 329 | ||||||||
| Energy purchases | 186 | — | 186 | ||||||||
| Other operation and maintenance | 42 | 335 | 377 | ||||||||
| Depreciation | 18 | 144 | 162 | ||||||||
| Taxes, other than income | 2 | 26 | 28 | ||||||||
| Total Operating Expenses | 577 | 505 | 1,082 | ||||||||
| Total | $ | 867 | $ | (505 | ) | $ | 362 | ||||
| Change | |||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 vs. 2016 | 2016 vs. 2015 | |||||||||||||||
| Operating Revenues | |||||||||||||||||||
| Retail and wholesale | $ | 1,734 | $ | 1,735 | $ | 1,708 | $ | (1 | ) | $ | 27 | ||||||||
| Electric revenue from affiliate | 10 | 14 | 20 | (4 | ) | (6 | ) | ||||||||||||
| Total Operating Revenues | 1,744 | 1,749 | 1,728 | (5 | ) | 21 | |||||||||||||
| Operating Expenses | |||||||||||||||||||
| Operation | |||||||||||||||||||
| Fuel | 467 | 490 | 534 | (23 | ) | (44 | ) | ||||||||||||
| Energy purchases | 18 | 18 | 18 | — | — | ||||||||||||||
| Energy purchases from affiliates | 31 | 24 | 37 | 7 | (13 | ) | |||||||||||||
| Other operation and maintenance | 424 | 424 | 435 | — | (11 | ) | |||||||||||||
| Depreciation | 255 | 234 | 220 | 21 | 14 | ||||||||||||||
| Taxes, other than income | 32 | 30 | 29 | 2 | 1 | ||||||||||||||
| Total Operating Expenses | 1,227 | 1,220 | 1,273 | 7 | (53 | ) | |||||||||||||
| Other Income (Expense) - net | (3 | ) | (5 | ) | 1 | 2 | (6 | ) | |||||||||||
| Interest Expense | 96 | 96 | 82 | — | 14 | ||||||||||||||
| Income Taxes | 159 | 163 | 140 | (4 | ) | 23 | |||||||||||||
| Net Income | $ | 259 | $ | 265 | $ | 234 | $ | (6 | ) | $ | 31 | ||||||||
Operating Revenue
The increase (decrease) in operating revenue was due to:
42
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Base rates | $ | 26 | $ | 64 | |||
| Volumes (a) | (48 | ) | (8 | ) | |||
| Fuel and other energy prices (b) | 8 | (47 | ) | ||||
| ECR | 5 | 13 | |||||
| Other | 4 | (1 | ) | ||||
| Total | $ | (5 | ) | $ | 21 | ||
| 2021 vs. 2020 | |||||
| Retail rates (a) | $ | 53 | |||
| Fuel and other energy prices (b) | 44 | ||||
| Volumes (c) | 29 | ||||
| 7 | |||||
| Economic relief billing credit, net of | (5) | ||||
| Other | 5 | ||||
| Total | $ | 136 | |||
(a)The increases were due to new base rates approved by the KPSC effective July 1, 2021.
(b)The increases were primarily due to higher recoveries of fuel and energy purchases due to higher commodity costs.
(c)The increases were primarily due to favorable weather.
Fuel
Fuel decreased $23increased $59 million in 20172021 compared with 20162020, primarily due to a $31 million decrease in fuel usage driven by milder weather in 2017, partially offset by an $8$39 million increase in market prices for natural gas.commodity costs and a $19 million increase in volumes driven by weather.
The increase in 2016 compared with 2015 primarilyother operation and maintenance was due to a $46 million decrease in market prices for coal and natural gas.to:
| 2021 vs. 2020 | |||||
| Plant outages | $ | 8 | |||
| Plant operations and maintenance | 6 | ||||
| Transmission operations and maintenance | 6 | ||||
| Distribution operations and maintenance | 5 | ||||
| Bad debts | 4 | ||||
| Administrative and general | 2 | ||||
| Other | 3 | ||||
| Total | $ | 34 | |||
Depreciation
Depreciation increased $21$20 million in 20172021 compared with 20162020, primarily due to an $11a $14 million increase related to additional assets placed into service, net of retirements and a $4 million increase related to higher depreciation rates effective July 1, 2017, and a $9 million increase related to additions to PP&E, net of retirements.2021.
| 2017 | 2016 | 2015 | |||||||||
| Net Income | $ | 259 | $ | 265 | $ | 234 | |||||
| Special items, gains (losses), after tax | (1 | ) | — | — | |||||||
| 2017 vs. 2016 | 2016 vs. 2015 | ||||||
| Margins | $ | 6 | $ | 63 | |||
| Other operation and maintenance | — | 19 | |||||
| Depreciation | (16 | ) | (7 | ) | |||
| Taxes, Other than income | (2 | ) | (1 | ) | |||
| Other Income (Expense) - net | 3 | (6 | ) | ||||
| Interest Expense | — | (14 | ) | ||||
| Income Taxes | 4 | (23 | ) | ||||
| Special items, gains (losses), after-tax (a) | (1 | ) | — | ||||
| Net Income | $ | (6 | ) | $ | 31 | ||
| 2017 | 2016 | ||||||||||||||||||||||
| Margins | Other (a) | Operating Income (b) | Margins | Other (a) | Operating Income (b) | ||||||||||||||||||
| Operating Revenues | $ | 1,744 | $ | — | $ | 1,744 | $ | 1,749 | $ | — | $ | 1,749 | |||||||||||
| Operating Expenses | |||||||||||||||||||||||
| Fuel | 467 | — | 467 | 490 | — | 490 | |||||||||||||||||
| Energy purchases | 49 | — | 49 | 42 | — | 42 | |||||||||||||||||
| Other operation and maintenance | 66 | 358 | 424 | 66 | 358 | 424 | |||||||||||||||||
| Depreciation | 32 | 223 | 255 | 27 | 207 | 234 | |||||||||||||||||
| Taxes, other than income | 2 | 30 | 32 | 2 | 28 | 30 | |||||||||||||||||
| Total Operating Expenses | 616 | 611 | 1,227 | 627 | 593 | 1,220 | |||||||||||||||||
| Total | $ | 1,128 | $ | (611 | ) | $ | 517 | $ | 1,122 | $ | (593 | ) | $ | 529 | |||||||||
| 2015 | |||||||||||
| Margins | Other (a) | Operating Income (b) | |||||||||
| Operating Revenues | $ | 1,728 | $ | — | $ | 1,728 | |||||
| Operating Expenses | |||||||||||
| Fuel | 534 | — | 534 | ||||||||
| Energy purchases | 55 | — | 55 | ||||||||
| Other operation and maintenance | 58 | 377 | 435 | ||||||||
| Depreciation | 20 | 200 | 220 | ||||||||
| Taxes, other than income | 2 | 27 | 29 | ||||||||
| Total Operating Expenses | 669 | 604 | 1,273 | ||||||||
| Total | $ | 1,059 | $ | (604 | ) | $ | 455 | ||||
Financial Condition
The remainder of this Item 7 in this Form 10-K is presented on a combined basis, providing information, as applicable, for all Registrants.
Liquidity and Capital Resources
(All Registrants)
The Registrants' cash flows from operations and access to cost effective bank and capital markets are subject to risks and uncertainties. See "Item 1A. Risk Factors" for a discussion of risks and uncertainties that could affect the Registrants' cash flows.
The Registrants had the following at:
| PPL (a) | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| December 31, 2017 | |||||||||||||||||||
| Cash and cash equivalents | $ | 485 | $ | 49 | $ | 30 | $ | 15 | $ | 15 | |||||||||
| Short-term debt | 1,080 | — | 244 | 199 | 45 | ||||||||||||||
| Long-term debt due within one year | 348 | — | 98 | 98 | — | ||||||||||||||
| Notes payable with affiliates | — | 225 | — | — | |||||||||||||||
| December 31, 2016 | |||||||||||||||||||
| Cash and cash equivalents | $ | 341 | $ | 13 | $ | 13 | $ | 5 | $ | 7 | |||||||||
| Short-term debt | 923 | 295 | 185 | 169 | 16 | ||||||||||||||
| Long-term debt due within one year | 518 | 224 | 194 | 194 | — | ||||||||||||||
| Notes payable with affiliates | — | 163 | — | — | |||||||||||||||
| December 31, 2015 | |||||||||||||||||||
| Cash and cash equivalents | $ | 836 | $ | 47 | $ | 30 | $ | 19 | $ | 11 | |||||||||
| Short-term debt | 916 | — | 265 | 142 | 48 | ||||||||||||||
| Long-term debt due within one year | 485 | — | 25 | 25 | — | ||||||||||||||
| Notes payables with affiliates | — | 54 | — | — | |||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| December 31, 2021 | |||||||||||||||||||||||
| Cash and cash equivalents | $ | 3,571 | $ | 21 | $ | 9 | $ | 13 | |||||||||||||||
| Short-term debt | 69 | — | 69 | — | |||||||||||||||||||
| Long-term debt due within one year | 474 | 474 | — | — | |||||||||||||||||||
| Notes payable with affiliates | — | 324 | 294 | ||||||||||||||||||||
| December 31, 2020 | |||||||||||||||||||||||
| Cash and cash equivalents | $ | 442 | $ | 40 | $ | 7 | $ | 22 | |||||||||||||||
| Short-term debt | 1,168 | — | 262 | 203 | |||||||||||||||||||
| Long-term debt due within one year | 1,074 | 400 | 292 | 132 | |||||||||||||||||||
| Notes payable with affiliates | — | — | — | ||||||||||||||||||||
(All Registrants)
Net cash provided by (used in) operating, investing and financing activities for the years ended December 31 and the changes between periods were as follows. follows:
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| 2021 | |||||||||||||||||||||||
| Operating activities | $ | 1,544 | $ | 969 | $ | 458 | $ | 608 | |||||||||||||||
| Investing activities | 8,564 | (1,400) | (466) | (556) | |||||||||||||||||||
| Financing activities | (7,344) | 412 | 10 | (61) | |||||||||||||||||||
| 2020 | |||||||||||||||||||||||
| Operating activities | $ | 1,872 | $ | 884 | $ | 483 | $ | 543 | |||||||||||||||
| Investing activities | (2,266) | (1,151) | (456) | (507) | |||||||||||||||||||
| Financing activities | 99 | 43 | (35) | (26) | |||||||||||||||||||
| 2021 vs. 2020 Change | |||||||||||||||||||||||
| Operating activities | $ | (328) | $ | 85 | $ | (25) | $ | 65 | |||||||||||||||
| Investing activities | 10,830 | (249) | (10) | (49) | |||||||||||||||||||
| Financing activities | (7,443) | 369 | 45 | (35) | |||||||||||||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2017 | |||||||||||||||||||
| Operating activities | $ | 2,461 | $ | 880 | $ | 1,099 | $ | 512 | $ | 634 | |||||||||
| Investing activities | (3,156 | ) | (1,252 | ) | (888 | ) | (458 | ) | (428 | ) | |||||||||
| Financing activities | 824 | 408 | (194 | ) | (44 | ) | (198 | ) | |||||||||||
| 2016 | |||||||||||||||||||
| Operating activities | $ | 2,890 | $ | 872 | $ | 1,027 | $ | 482 | $ | 606 | |||||||||
| Investing activities | (2,918 | ) | (1,130 | ) | (790 | ) | (439 | ) | (349 | ) | |||||||||
| Financing activities | (439 | ) | 224 | (254 | ) | (57 | ) | (261 | ) | ||||||||||
| 2015 | |||||||||||||||||||
| Operating activities | $ | 2,272 | $ | 602 | $ | 1,063 | $ | 554 | $ | 608 | |||||||||
| Investing activities | (3,439 | ) | (1,108 | ) | (1,203 | ) | (689 | ) | (512 | ) | |||||||||
| Financing activities | 482 | 339 | 149 | 144 | (96 | ) | |||||||||||||
| 2017 vs. 2016 Change | |||||||||||||||||||
| Operating activities | $ | (429 | ) | $ | 8 | $ | 72 | $ | 30 | $ | 28 | ||||||||
| Investing activities | (238 | ) | (122 | ) | (98 | ) | (19 | ) | (79 | ) | |||||||||
| Financing activities | 1,263 | 184 | 60 | 13 | 63 | ||||||||||||||
| 2016 vs. 2015 Change | |||||||||||||||||||
| Operating activities | $ | 618 | $ | 270 | $ | (36 | ) | $ | (72 | ) | $ | (2 | ) | ||||||
| Investing activities | 521 | (22 | ) | 413 | 250 | 163 | |||||||||||||
| Financing activities | (921 | ) | (115 | ) | (403 | ) | (201 | ) | (165 | ) | |||||||||
Operating Activities
The components of the change in cash provided by (used in) operating activities were as follows. follows:
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| 2021 vs. 2020 | |||||||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||||||
| Net income | $ | (622) | $ | (52) | $ | 5 | $ | 16 | |||||||||||||||
| Non-cash components | 344 | (13) | 16 | — | |||||||||||||||||||
| Working capital | (93) | 160 | (28) | 20 | |||||||||||||||||||
| Defined benefit plan funding | 66 | — | 8 | 2 | |||||||||||||||||||
| Other operating activities | (23) | (10) | (26) | 27 | |||||||||||||||||||
| Total | $ | (328) | $ | 85 | $ | (25) | $ | 65 | |||||||||||||||
(PPL)
PPL cash provided by operating activities in 2020 decreased $328 million compared with 2019.
•Net income decreased $622 million between periods and included an increase in net non-cash charges of $344 million. The increase in non-cash charges was primarily due to the loss on extinguishment of debt and the impairment of solar panels, partially offset by a decrease in deferred income taxes and investment tax credits.
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2017 vs. 2016 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Net income | $ | (774 | ) | $ | 22 | $ | (113 | ) | $ | 10 | $ | (6 | ) | ||||||
| Non-cash components | 363 | 100 | 31 | (8 | ) | 42 | |||||||||||||
| Working capital | 38 | (87 | ) | 93 | (33 | ) | (14 | ) | |||||||||||
| Defined benefit plan funding | (138 | ) | (24 | ) | 50 | 42 | (3 | ) | |||||||||||
| Other operating activities | 82 | (3 | ) | 11 | 19 | 9 | |||||||||||||
| Total | $ | (429 | ) | $ | 8 | $ | 72 | $ | 30 | $ | 28 | ||||||||
| 2016 vs. 2015 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Net income | $ | 299 | $ | 88 | $ | 65 | $ | 18 | $ | 31 | |||||||||
| Non-cash components | 195 | 40 | 66 | 20 | (20 | ) | |||||||||||||
| Working capital | 47 | 101 | (206 | ) | (100 | ) | (51 | ) | |||||||||||
| Defined benefit plan funding | 72 | 33 | (15 | ) | (20 | ) | 1 | ||||||||||||
| Other operating activities | 5 | 8 | 54 | 10 | 37 | ||||||||||||||
| Total | $ | 618 | $ | 270 | $ | (36 | ) | $ | (72 | ) | $ | (2 | ) | ||||||
•The $93 million decrease in cash from changes in working capital was primarily due to a decrease in taxes payable and a decrease in other current assets and liabilities, partially offset by an increase in regulatory liabilities (primarily due to PPL Electric’s transmission formula rate return on equity reduction and the timing of rate recovery mechanisms).
(PPL Electric)
PPL Electric's cash provided by operating activities in 2021 increased $85 million compared with 2016.2020.
•Net income declined $774decreased $52 million between the periods and included neta decrease in non-cash benefitscomponents of $363$13 million. The decrease in non-cash components was primarily due to a decrease in other expenses (primarily due to a decrease in canceled projects).
•The $160 million increase in net non-cash benefitscash from changes in working capital was primarily due to an increase in unrealized lossesregulatory liabilities (primarily due to a transmission formula rate return on hedgingequity reduction and the timing of rate recovery mechanisms).
•The $10 million decrease in cash provided by other operating activities was driven primarily by a decrease in accrued pension obligations.
(LG&E)
LG&E's cash provided by operating activities in 2021 decreased $25 million compared with 2020.
•Net income increased $5 million between the periods and included an increase in deferred income taxes (primarily due to the impactnon-cash components of the TCJA) and$16 million. The increase in non-cash components was primarily driven by an increase in depreciation expense (primarily due to additional assets placed into service, net of retirements and higher depreciation rates at LG&E and KU effective July 1, 2017, partially offset by the impact of foreign currency at WPD)2021), partially offset by an increasea decrease in the U.K. net periodic defined benefit creditsamortization expense (primarily due to a decrease in the U.K. pension plan discount rates used to calculate the interest cost componentamortization of the net periodic defined benefit costs (credits) and increase in expected returns)economic relief billing credit regulatory liability).
•The decrease in accounts receivablecash provided by other operating activities was driven primarily by a decrease in other liabilities (primarily duerelated to increased volumes and favorable weather in 2016)noncurrent regulatory liabilities).
•Net income improved by $22increased $16 million between the periods. Thisperiods and included an additional $100 million of netno change in non-cash benefitscomponents. Non-cash components were primarily driven by a decrease in deferred income tax expense (primarily due to a $56 millionbook versus tax plant timing differences), offset by an increase in depreciation expense (primarily due to additional assets placed into service, related to the ongoing efforts to ensure the reliability of the delivery system and the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program, net of retirements)retirements and a $37 million increase in deferred income taxes (primarily due to book versus tax plant timing differences)higher depreciation rates effective July 1, 2021).
Investing Activities
(All Registrants)
The components of the change in cash provided by (used in) investing activities were as follows. follows:
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| 2021 vs. 2020 | |||||||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||||||
| Expenditures for PP&E | $ | 297 | $ | 247 | $ | (10) | $ | (50) | |||||||||||||||
| Proceeds from sale of discontinued operations, net of cash divested | 10,560 | — | — | — | |||||||||||||||||||
| Notes receivable from affiliate | (499) | — | — | ||||||||||||||||||||
| Other investing activities | (27) | 3 | — | 1 | |||||||||||||||||||
| Total | $ | 10,830 | $ | (249) | $ | (10) | $ | (49) | |||||||||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2017 vs. 2016 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Expenditures for PP&E | $ | (213 | ) | $ | (119 | ) | $ | (101 | ) | $ | (19 | ) | $ | (82 | ) | ||||
| Investment activity, net | (2 | ) | — | — | — | — | |||||||||||||
| Other investing activities | (23 | ) | (3 | ) | 3 | — | 3 | ||||||||||||
| Total | $ | (238 | ) | $ | (122 | ) | $ | (98 | ) | $ | (19 | ) | $ | (79 | ) | ||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2016 vs. 2015 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Expenditures for PP&E | $ | 613 | $ | (28 | ) | $ | 419 | $ | 250 | $ | 169 | ||||||||
| Investment activity, net | (134 | ) | — | — | — | — | |||||||||||||
| Other investing activities | 42 | 6 | (6 | ) | — | (6 | ) | ||||||||||||
| Total | $ | 521 | $ | (22 | ) | $ | 413 | $ | 250 | $ | 163 | ||||||||
For PPL, in 20172021 compared with 2016, higher project2020, the decrease in expenditures at PPL Electric, LKE, LG&E and KU were partially offset bywas due to lower project expenditures at WPD. The increase in project expenditures forand PPL Electric was primarily due to an increase in capital spending related to the ongoing efforts to improve reliability and replace aging infrastructure, as well as the roll-out of the Act 129 Smart Meter program. The increase in expenditures for LKE, LG&E and KU was primarily due to increased spending for environmental water projects at LG&E’s Mill Creek plant, CCR projects at the Trimble County plant and increased spending on various transmission projects at KU, partially offset by lower spending driven by completion of environmental air projects. The decrease in expenditures at WPD was primarily due to a decrease in foreign currency exchange ratesSafari Energy, partially offset by an increase in expenditures to enhance system reliability.
See "Forecasted Uses of Cash" for detail regarding projected capital expenditures for the years 20182022 through 2022.2024.
For PPL Electric, the changes in "Notes receivable from affiliate" activity resulted from the funding of $499 million to an affiliate for general corporate purposes. See Note 15 to the Financial Statements for further discussion of intercompany borrowings.
Financing Activities
(All Registrants)
The components of the change in cash provided by (used in) financing activities were as follows. follows:
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| 2021 vs. 2020 | |||||||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||||||
| Long-term debt issuance/retirement, net | $ | (4,829) | $ | — | $ | — | $ | 2 | |||||||||||||||
| Long-term debt issuance/retirement, affiliate | — | — | — | ||||||||||||||||||||
| Proceeds from project financing | (154) | — | — | — | |||||||||||||||||||
| Stock issuances/redemptions, net | (25) | — | — | — | |||||||||||||||||||
| Dividends | (4) | 66 | (31) | (50) | |||||||||||||||||||
| Purchase of treasury stock | (1,003) | — | — | — | |||||||||||||||||||
| Capital contributions/distributions, net | — | 306 | (29) | (28) | |||||||||||||||||||
| Issuance of term loan | (300) | — | — | — | |||||||||||||||||||
| Issuance of commercial paper | (73) | — | (41) | (32) | |||||||||||||||||||
| Retirement of term loan | (300) | — | — | — | |||||||||||||||||||
| Retirement of commercial paper | (73) | — | (41) | (32) | |||||||||||||||||||
| Changes in net short-term debt | (683) | — | (135) | (192) | |||||||||||||||||||
| Note payable with affiliate | — | 324 | 294 | ||||||||||||||||||||
| Other financing activities | 1 | (3) | (2) | 3 | |||||||||||||||||||
| Total | $ | (7,443) | $ | 369 | $ | 45 | $ | (35) | |||||||||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2017 vs. 2016 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Debt issuance/retirement, net | $ | 935 | $ | 470 | $ | 115 | $ | 115 | $ | — | |||||||||
| Stock issuances/redemptions, net | 309 | — | — | — | — | ||||||||||||||
| Dividends | (42 | ) | (48 | ) | — | (64 | ) | 22 | |||||||||||
| Capital contributions/distributions, net | 355 | (147 | ) | (41 | ) | (20 | ) | ||||||||||||
| Changes in net short-term debt (a) | 86 | (590 | ) | 92 | 3 | 61 | |||||||||||||
| Other financing activities | (25 | ) | (3 | ) | — | — | — | ||||||||||||
| Total | $ | 1,263 | $ | 184 | $ | 60 | $ | 13 | $ | 63 | |||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2016 vs. 2015 | |||||||||||||||||||
| Change - Cash Provided (Used): | |||||||||||||||||||
| Debt issuance/retirement, net | $ | (824 | ) | $ | (248 | ) | $ | (175 | ) | $ | (325 | ) | $ | (250 | ) | ||||
| Debt issuance/retirement, affiliate | — | (400 | ) | — | — | ||||||||||||||
| Stock issuances/redemptions, net | (59 | ) | — | — | — | — | |||||||||||||
| Dividends | (26 | ) | (107 | ) | — | (9 | ) | (95 | ) | ||||||||||
| Capital contributions/distributions, net | (55 | ) | (161 | ) | (19 | ) | 20 | ||||||||||||
| Changes in net short-term debt (a) | (65 | ) | 295 | 326 | 149 | 156 | |||||||||||||
| Other financing activities | 53 | — | 7 | 3 | 4 | ||||||||||||||
| Total | $ | (921 | ) | $ | (115 | ) | $ | (403 | ) | $ | (201 | ) | $ | (165 | ) | ||||
(All Registrants)
See Note 8 to the Financial Statements in this Form 10-K for information on 2021 activity.
46
See "Long-term Debt and Equity Securities" below for additional information on current year activity. See "Forecasted Sources of Cash" for a discussion of the Registrants' plans to issue debt and equity securities, as well as a discussion of credit facility capacity available to the Registrants. Also see "Forecasted Uses of Cash" for a discussion of PPL's plans to pay dividends on common securities in the future, as well as the Registrants' maturities of long-term debt.
Long-term Debt and Equity Securities
Long-term debt and equity securities activity for 20172021 included:
| Debt | Stock | ||||||||||||||||||||||
| Issuances (a) | Retirements | Issuances | Repurchases | ||||||||||||||||||||
| Cash Flow Impact: | |||||||||||||||||||||||
| PPL | $ | 650 | $ | 4,606 | $ | 9 | $ | 1,003 | |||||||||||||||
| PPL Electric | 650 | 400 | — | — | |||||||||||||||||||
| LG&E | — | — | — | — | |||||||||||||||||||
| KU | — | — | — | — | |||||||||||||||||||
| Debt | Net Stock | ||||||||||
| Issuances (a) | Retirements | Issuances | |||||||||
| Cash Flow Impact: | |||||||||||
| PPL | $ | 1,515 | $ | 168 | $ | 453 | |||||
| PPL Electric | 470 | — | |||||||||
| LKE | 160 | 70 | |||||||||
| LG&E | 160 | 70 | |||||||||
| KU | — | — | |||||||||
(a)Issuances are net of pricing discounts, where applicable, and exclude the impact of debt issuance costs. Includes debt issuances with affiliates.
See Note 78 to the Financial Statements for additional information about long-term debt.debt information.
Equity Securities Activities
Share Repurchase
In August 2021, PPL's Board of Directors authorized share repurchases of up to $3 billion of PPL common shares. The actual amount repurchased will depend on various factors, including PPL’s share price, market conditions, and the determination of other uses for the proceeds from the sale of the U.K. utility business, including for incremental capital expenditures. PPL may purchase shares on each trading day subject to market conditions and principles of best execution.
During 2017,the year ended December 31, 2021, PPL issued 10,373 thousandrepurchased 34.8 million shares at a cost of $1.0 billion. Commission fees incurred, which have been included in the cost of repurchases above, were insignificant through December 31, 2021.
See Note 8 to the Financial Statements for additional information.
ATM Program
In February 2018, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $1.0 billion of its common stock under thethrough an at-the-market offering program, receiving net proceeds of $377 million.including a forward sales component. The compensation paid to the selling agents by PPL may be up to 1%2% of the gross offering proceeds of the shares sold with respect to each equity distribution agreement. See Note 7 to the Financial Statements for additional information aboutshares. There were no issuances under the ATM Program.program for the twelve months ended December 31, 2021 and 2020. The ATM program expired in February 2021.
Forecasted Sources of Cash
(All Registrants)
The Registrants expect to continue to have adequate liquidity available from operating cash flows, cash and cash equivalents, credit facilities and commercial paper issuances.issuances to meet their requirements with respect to their contractual obligations and anticipated capital expenditures. Additionally, subject to market conditions, the Registrants and their subsidiaries may access the capital markets, and PPL Electric, LG&E and KU anticipate receiving equity contributions from their parent or member in 2018.2022.
47
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 except for borrowings under LG&E's term loan agreement which are reflected in "Long-term debt" on the Balance Sheets. At December 31, 2017,2021, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:
External
| Committed Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | Unused Capacity | ||||||||||||||||||||
| PPL Capital Funding Credit Facilities | $ | 1,300 | $ | — | $ | — | $ | 1,300 | |||||||||||||||
| PPL Electric Credit Facility | 650 | — | 1 | 649 | |||||||||||||||||||
| LG&E Credit Facilities | 500 | — | 69 | 431 | |||||||||||||||||||
| KU Credit Facilities | 400 | — | — | 400 | |||||||||||||||||||
| Total Credit Facilities (a) (b) | $ | 2,850 | $ | — | $ | 70 | $ | 2,780 | |||||||||||||||
| Committed Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | Unused Capacity | ||||||||||||
| PPL Capital Funding Credit Facilities | $ | 1,400 | $ | — | $ | 248 | $ | 1,152 | |||||||
| PPL Electric Credit Facility | 650 | — | 1 | 649 | |||||||||||
| LKE Credit Facility | 75 | — | — | 75 | |||||||||||
| LG&E Credit Facilities | 700 | 100 | 199 | 401 | |||||||||||
| KU Credit Facilities | 598 | — | 243 | 355 | |||||||||||
| Total LKE Consolidated | 1,373 | 100 | 442 | 831 | |||||||||||
| Total U.S. Credit Facilities (a) (b) | $ | 3,423 | $ | 100 | $ | 691 | $ | 2,632 | |||||||
| Total U.K. Credit Facilities (b) (c) | £ | 1,055 | £ | 448 | £ | — | £ | 605 | |||||||
(a)The syndicated credit facilities and PPL Capital Funding's bilateral facility, each contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LG&E and KU, as calculated in accordance with the facility, and other customary covenants.
The commitments under the domestic 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 - 10%7%, PPL Electric 7%, LKE - 18%7%, LG&E - 33%7% and KU - 37%7%.
(b)Each company pays customary fees under its respective syndicated credit facility. Borrowings generally bear interest at LIBOR-based rates plus an applicable margin.
In addition to the financial covenants noted in the table above, the credit agreements governing the above credit facilities contain various other covenants. Failure to comply with the covenants after applicable grace periods could result in acceleration of repayment of borrowings and/or termination of the agreements. The Registrants monitor compliance with the covenants on a regular basis. At December 31, 2017,2021, the Registrants were in compliance with these covenants. At this time, the Registrants believe that these covenants and other borrowing conditions will not limit access to these funding sources.
See Note 78 to the Financial Statements for further discussion of the Registrants' credit facilities.
Intercompany (LKE, (LG&E and KU)
| Committed Capacity | Borrowed | Commercial Paper Program Capacity | Unused Capacity | ||||||||||||||||||||
| LG&E Money Pool (a) | $ | 750 | $ | 324 | $ | 425 | $ | 1 | |||||||||||||||
| KU Money Pool (a) | 650 | 294 | 350 | 6 | |||||||||||||||||||
(a)LG&E and KU)KU participate in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E, and LKE and/or LG&E make available to KU funds up to the difference between LG&E's and KU's FERC borrowing limit and LG&E's and KU's commercial paper capacity limit, at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR.
Committed Capacity | Borrowed | Non-affiliate Used Capacity | Unused Capacity | ||||||||||||
| LKE Credit Facility | $ | 275 | $ | 225 | $ | — | $ | 50 | |||||||
| LG&E Money Pool (a) | 500 | — | 199 | 301 | |||||||||||
| KU Money Pool (a) | 500 | — | 45 | 455 | |||||||||||
See Note 1415 to the Financial Statements for further discussion of intercompany credit facilities.
Commercial Paper (All Registrants)
48
| December 31, 2017 | December 31, 2021 | |||||||||||||||||||||||||||
| Capacity | Commercial Paper Issuances | Unused Capacity | Capacity | Commercial Paper Issuances | Unused Capacity | |||||||||||||||||||||||
| PPL Capital Funding | $ | 1,000 | $ | 230 | $ | 770 | PPL Capital Funding | $ | 1,500 | $ | — | $ | 1,500 | |||||||||||||||
| PPL Electric | 650 | — | 650 | PPL Electric | 650 | — | 650 | |||||||||||||||||||||
| LG&E (a) | LG&E (a) | 425 | 69 | 356 | ||||||||||||||||||||||||
| KU | KU | 350 | — | 350 | ||||||||||||||||||||||||
| LG&E | 350 | 199 | 151 | |||||||||||||||||||||||||
| KU | 350 | 45 | 305 | |||||||||||||||||||||||||
| Total LKE | 700 | 244 | 456 | |||||||||||||||||||||||||
| Total PPL | $ | 2,350 | $ | 474 | $ | 1,876 | Total PPL | $ | 2,925 | $ | 69 | $ | 2,856 | |||||||||||||||
(a)In March 2021, the capacity for the LG&E commercial paper program was increased from $350 million to $425 million.
Long-term Debt and Equity Securities
(PPL)
PPL and its subsidiaries are authorized to incur,issue, at the discretion of management and subject to market conditions, up to $3.2$2.45 billion of long-term indebtedness in 2018,debt and equity securities, the proceeds of which would be used to fund capital expenditures and for general corporate purposes.
(PPL Electric)
PPL Electric is authorized to incur,issue, at the discretion of management and subject to market conditions and regulatory approvals, up to $650 million of long-term indebtedness in 2018,debt securities, the proceeds of which would be used to fund capital expenditures and for general corporate purposes.
(LKE, LG&E and KU)
LG&E is authorized to incur,issue, at the discretion of management and subject to market conditions and regulatory approvals, up to $200$400 million of long-term indebtedness in 2018,debt securities, the proceeds of which $100 million was issued in January 2018. The proceeds would be used to repay short-term debt incurred to fund capital expenditures and for general corporate purposes. LG&E currently plans to remarket, subject to market conditions, $98 million of its Pollution Control Bonds with put dates in 2018.
KU is authorized to incur,issue, at the discretion of management and subject to market conditions and regulatory approvals, up to $100$300 million of long-term indebtedness in 2018,debt securities, the proceeds of which would be used to repay short-term debt incurred to fund capital expenditures.expenditures and for general corporate purposes.
Contributions from Parent/Member Parent (PPL Electric, LKE, LG&E and KU)
From time to time, LKE's member or the parents of PPL Electric, LG&E and KU make capital contributions to subsidiaries. The proceeds from these contributions are used to fund capital expenditures and for other general corporate purposes and, in the case of LKE, to make contributions to its subsidiaries.purposes.
Forecasted Uses of Cash
(All Registrants)
In addition to expenditures required for normal operating activities, such as purchased power, payroll, fuel and taxes, the Registrants currently expect to incur future cash outflows for capital expenditures, various contractual obligations, payment of dividends on its common stock, distributions by LKE to its member, and possibly the purchase or redemption of a portion of debt securities.
Capital Expenditures
2024, PPL currently anticipates capital expenditures of approximately $3.7 to $4.2 billion, with approximately $1.7 to $1.9 billion at PPL Electric Utilities, approximately $0.85 to $0.95 billion each at KU and LG&E (including approximately $73 million at KU and $46 million at LG&E expected to be covered by ECR plans), and the remainder in corporate and other, including investments in renewables,
| Projected | |||||||||||||||||||||||
| Total | 2018 (b) | 2019 | 2020 | 2021 | 2022 | ||||||||||||||||||
| PPL | |||||||||||||||||||||||
| Construction expenditures (a) | |||||||||||||||||||||||
| Generating facilities | $ | 892 | $ | 238 | $ | 253 | $ | 124 | $ | 204 | $ | 73 | |||||||||||
| Distribution facilities | 9,244 | 1,875 | 1,819 | 1,851 | 1,863 | 1,836 | |||||||||||||||||
| Transmission facilities | 3,771 | 902 | 854 | 883 | 628 | 504 | |||||||||||||||||
| Environmental | 828 | 429 | 191 | 91 | 62 | 55 | |||||||||||||||||
| Other | 685 | 127 | 201 | 193 | 117 | 47 | |||||||||||||||||
| Total Capital Expenditures | $ | 15,420 | $ | 3,571 | $ | 3,318 | $ | 3,142 | $ | 2,874 | $ | 2,515 | |||||||||||
PPL Electric (a) | |||||||||||||||||||||||
| Distribution facilities | $ | 2,077 | $ | 476 | $ | 404 | $ | 403 | $ | 396 | $ | 398 | |||||||||||
| Transmission facilities | 2,901 | 757 | 686 | 692 | 404 | 362 | |||||||||||||||||
| Total Capital Expenditures | $ | 4,978 | $ | 1,233 | $ | 1,090 | $ | 1,095 | $ | 800 | $ | 760 | |||||||||||
LKE | |||||||||||||||||||||||
| Generating facilities | $ | 892 | $ | 238 | $ | 253 | $ | 124 | $ | 204 | $ | 73 | |||||||||||
| Distribution facilities | 1,699 | 347 | 388 | 360 | 338 | 266 | |||||||||||||||||
| Transmission facilities | 870 | 144 | 169 | 190 | 225 | 142 | |||||||||||||||||
| Environmental | 828 | 429 | 191 | 91 | 62 | 55 | |||||||||||||||||
| Other | 663 | 119 | 196 | 189 | 114 | 45 | |||||||||||||||||
| Total Capital Expenditures | $ | 4,952 | $ | 1,277 | $ | 1,197 | $ | 954 | $ | 943 | $ | 581 | |||||||||||
LG&E | |||||||||||||||||||||||
| Generating facilities | $ | 408 | $ | 127 | $ | 108 | $ | 35 | $ | 94 | $ | 44 | |||||||||||
| Distribution facilities | 1,084 | 223 | 265 | 233 | 210 | 153 | |||||||||||||||||
| Transmission facilities | 161 | 27 | 36 | 36 | 40 | 22 | |||||||||||||||||
| Environmental | 335 | 176 | 83 | 38 | 22 | 16 | |||||||||||||||||
| Other | 331 | 58 | 97 | 94 | 58 | 24 | |||||||||||||||||
| Total Capital Expenditures | $ | 2,319 | $ | 611 | $ | 589 | $ | 436 | $ | 424 | $ | 259 | |||||||||||
subject to market conditions. These later investments are anticipated to be spread approximately evenly over the two years in the period.
| Projected | |||||||||||||||||||||||
| Total | 2018 (b) | 2019 | 2020 | 2021 | 2022 | ||||||||||||||||||
KU | |||||||||||||||||||||||
| Generating facilities | $ | 484 | $ | 111 | $ | 145 | $ | 89 | $ | 110 | $ | 29 | |||||||||||
| Distribution facilities | 615 | 124 | 123 | 127 | 128 | 113 | |||||||||||||||||
| Transmission facilities | 709 | 117 | 133 | 154 | 185 | 120 | |||||||||||||||||
| Environmental | 493 | 253 | 108 | 53 | 40 | 39 | |||||||||||||||||
| Other | 332 | 61 | 99 | 95 | 56 | 21 | |||||||||||||||||
| Total Capital Expenditures | $ | 2,633 | $ | 666 | $ | 608 | $ | 518 | $ | 519 | $ | 322 | |||||||||||
Capital expenditure plans are revised periodically to reflect changes in operational, market and regulatory conditions. For the years presented,The capital expenditure plans discussed in this table includes PPL Electric's asset optimization program to replace aging transmission and distribution assets.
Contractual Obligations
The Registrants have assumed various financial obligations and commitments in the ordinary course of conducting business. At December 31, 2017,2021, estimated contractual cash obligations were as follows:
| Total | 2022 | 2023-2024 | 2025-2026 | After 2026 | |||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||
| Long-term Debt (a) | $ | 11,251 | $ | 474 | $ | 1,003 | $ | 1,454 | $ | 8,320 | |||||||||||||||||||
| Interest on Long-term Debt (b) | 8,322 | 408 | 807 | 771 | 6,336 | ||||||||||||||||||||||||
| Operating Leases (c) | 74 | 23 | 35 | 11 | 5 | ||||||||||||||||||||||||
| Purchase Obligations (d) | 2,711 | 921 | 1,011 | 436 | 343 | ||||||||||||||||||||||||
| Total Contractual Cash Obligations | $ | 22,358 | $ | 1,826 | $ | 2,856 | $ | 2,672 | $ | 15,004 | |||||||||||||||||||
| PPL Electric | |||||||||||||||||||||||||||||
| Long-term Debt (a) | $ | 4,539 | $ | 474 | $ | 990 | $ | — | $ | 3,075 | |||||||||||||||||||
| Interest on Long-term Debt (b) | 3,118 | 154 | 287 | 278 | 2,399 | ||||||||||||||||||||||||
| Unconditional Power Purchase Obligations | 135 | 29 | 57 | 49 | — | ||||||||||||||||||||||||
| Total Contractual Cash Obligations | $ | 7,792 | $ | 657 | $ | 1,334 | $ | 327 | $ | 5,474 | |||||||||||||||||||
| LG&E | |||||||||||||||||||||||||||||
| Long-term Debt (a) | $ | 2,024 | $ | — | $ | — | $ | 390 | $ | 1,634 | |||||||||||||||||||
| Interest on Long-term Debt (b) | 1,413 | 75 | 150 | 141 | 1,047 | ||||||||||||||||||||||||
| Operating Leases (c) | 20 | 6 | 9 | 4 | 1 | ||||||||||||||||||||||||
| Coal and Natural Gas Purchase Obligations (e) | 777 | 317 | 390 | 70 | — | ||||||||||||||||||||||||
| Unconditional Power Purchase Obligations (f) | 330 | 23 | 45 | 44 | 218 | ||||||||||||||||||||||||
| Construction Obligations (g) | 176 | 79 | 66 | 26 | 5 | ||||||||||||||||||||||||
| Other Obligations | 87 | 29 | 6 | 45 | 7 | ||||||||||||||||||||||||
| Total Contractual Cash Obligations | $ | 4,827 | $ | 529 | $ | 666 | $ | 720 | $ | 2,912 | |||||||||||||||||||
| KU | |||||||||||||||||||||||||||||
| Long-term Debt (a) | $ | 2,642 | $ | — | $ | 13 | $ | 414 | $ | 2,215 | |||||||||||||||||||
| Interest on Long-term Debt (b) | 2,117 | 105 | 210 | 201 | 1,601 | ||||||||||||||||||||||||
| Operating Leases (c) | 30 | 10 | 14 | 5 | 1 | ||||||||||||||||||||||||
| Coal and Natural Gas Purchase Obligations (e) | 794 | 323 | 350 | 119 | 2 | ||||||||||||||||||||||||
| Unconditional Power Purchase Obligations (f) | 146 | 10 | 20 | 20 | 96 | ||||||||||||||||||||||||
| Construction Obligations (g) | 156 | 76 | 53 | 22 | 5 | ||||||||||||||||||||||||
| Other Obligations | 103 | 33 | 22 | 40 | 8 | ||||||||||||||||||||||||
| Total Contractual Cash Obligations | $ | 5,988 | $ | 557 | $ | 682 | $ | 821 | $ | 3,928 | |||||||||||||||||||
| Total | 2018 | 2019 - 2020 | 2021 - 2022 | After 2022 | |||||||||||||||
| PPL | |||||||||||||||||||
| Long-term Debt (a) | $ | 20,282 | $ | 348 | $ | 1,708 | $ | 2,424 | $ | 15,802 | |||||||||
| Interest on Long-term Debt (b) | 15,318 | 868 | 1,723 | 1,529 | 11,198 | ||||||||||||||
| Operating Leases (c) | 96 | 28 | 27 | 16 | 25 | ||||||||||||||
| Purchase Obligations (d) | 3,636 | 1,121 | 1,374 | 563 | 578 | ||||||||||||||
| Other Long-term Liabilities Reflected on the Balance Sheet (e) | 565 | 293 | 272 | — | — | ||||||||||||||
| Total Contractual Cash Obligations | $ | 39,897 | $ | 2,658 | $ | 5,104 | $ | 4,532 | $ | 27,603 | |||||||||
| PPL Electric | |||||||||||||||||||
| Long-term Debt (a) | $ | 3,339 | $ | — | $ | 100 | $ | 874 | $ | 2,365 | |||||||||
| Interest on Long-term Debt (b) | 2,894 | 141 | 282 | 260 | 2,211 | ||||||||||||||
| Unconditional Power Purchase Obligations | 77 | 23 | 45 | 9 | — | ||||||||||||||
| Total Contractual Cash Obligations | $ | 6,310 | $ | 164 | $ | 427 | $ | 1,143 | $ | 4,576 | |||||||||
(a)Reflects principal maturities based on stated maturity or earlier put dates. See Note 8 to the Financial Statements for a discussion of variable-rate remarketable bonds issued on behalf of LG&E and KU. The Registrants do not have any significant finance lease obligations.
(b)Assumes interest payments through stated maturity or earlier put dates. The payments herein are subject to change, as payments for debt that is or becomes variable-rate debt have been estimated.
(c)See Note 10 to the Financial Statements for additional information.
(d)The amounts include agreements to purchase goods or services that are enforceable and legally binding and specify all significant terms, including: fixed or minimum quantities to be purchased; fixed, minimum or variable price provisions; and the approximate timing of the transaction. Primarily includes, as applicable, the purchase obligations of electricity, coal, natural gas and limestone, as well as certain construction expenditures, which are also included in the Capital Expenditures discussion above.
(e)Represents contracts to purchase coal, natural gas and natural gas transportation. See Note 14 to the Financial Statements for additional information.
(f)Represents future minimum payments under OVEC power purchase agreements through June 2040. See Note 14 to the Financial Statements for additional information.
(g)Represents construction commitments, which are also reflected in the Capital Expenditures table presented above.
| Total | 2018 | 2019 - 2020 | 2021 - 2022 | After 2022 | |||||||||||||||
| LKE | |||||||||||||||||||
| Long-term Debt (a) | $ | 5,200 | $ | 98 | $ | 1,405 | $ | 250 | $ | 3,447 | |||||||||
| Interest on Long-term Debt (b) | 3,120 | 199 | 388 | 300 | 2,233 | ||||||||||||||
| Operating Leases (c) | 82 | 26 | 27 | 14 | 15 | ||||||||||||||
| Coal and Natural Gas Purchase Obligations (f) | 1,955 | 582 | 930 | 375 | 68 | ||||||||||||||
| Unconditional Power Purchase Obligations (g) | 593 | 29 | 53 | 54 | 457 | ||||||||||||||
| Construction Obligations (h) | 500 | 305 | 147 | 48 | — | ||||||||||||||
| Pension Benefit Plan Obligations (e) | 105 | 105 | — | — | — | ||||||||||||||
| Other Obligations | 417 | 151 | 143 | 70 | 53 | ||||||||||||||
| Total Contractual Cash Obligations | $ | 11,972 | $ | 1,495 | $ | 3,093 | $ | 1,111 | $ | 6,273 | |||||||||
| LG&E | |||||||||||||||||||
| Long-term Debt (a) | $ | 1,724 | $ | 98 | $ | 334 | $ | — | $ | 1,292 | |||||||||
| Interest on Long-term Debt (b) | 1,185 | 63 | 117 | 108 | 897 | ||||||||||||||
| Operating Leases (c) | 39 | 15 | 13 | 5 | 6 | ||||||||||||||
| Coal and Natural Gas Purchase Obligations (f) | 839 | 252 | 403 | 154 | 30 | ||||||||||||||
| Unconditional Power Purchase Obligations (g) | 411 | 20 | 37 | 38 | 316 | ||||||||||||||
| Construction Obligations (h) | 256 | 185 | 62 | 9 | — | ||||||||||||||
| Pension Benefit Plan Obligations (e) | 54 | 54 | — | — | — | ||||||||||||||
| Other Obligations | 149 | 47 | 59 | 26 | 17 | ||||||||||||||
| Total Contractual Cash Obligations | $ | 4,657 | $ | 734 | $ | 1,025 | $ | 340 | $ | 2,558 | |||||||||
| KU | |||||||||||||||||||
| Long-term Debt (a) | $ | 2,351 | $ | — | $ | 596 | $ | — | $ | 1,755 | |||||||||
| Interest on Long-term Debt (b) | 1,719 | 93 | 186 | 153 | 1,287 | ||||||||||||||
| Operating Leases (c) | 41 | 10 | 14 | 9 | 8 | ||||||||||||||
| Coal and Natural Gas Purchase Obligations (f) | 1,115 | 330 | 527 | 221 | 37 | ||||||||||||||
| Unconditional Power Purchase Obligations (g) | 182 | 9 | 16 | 16 | 141 | ||||||||||||||
| Construction Obligations (h) | 218 | 101 | 80 | 37 | — | ||||||||||||||
| Pension Benefit Plan Obligations (e) | 46 | 46 | — | — | — | ||||||||||||||
| Other Obligations | 187 | 49 | 64 | 38 | 36 | ||||||||||||||
| Total Contractual Cash Obligations | $ | 5,859 | $ | 638 | $ | 1,483 | $ | 474 | $ | 3,264 | |||||||||
Dividends/Distributions
(PPL)
PPL views dividends as an integral component of shareowner return and expects to continue to pay dividends in amounts that are within the context of maintainingintended to maintain a capitalization structure that supports investment grade credit ratings. In November 2017,2021, PPL declared its quarterly common stock dividend, payable January 2, 2018,3, 2022, at 39.541.50 cents per share (equivalent to $1.58$1.66 per annum). On February 22, 2018,18, 2022, PPL announced that the company is increasing itsa quarterly common stock dividend to 41.0of 20.00 cents per share, on a quarterly basis (equivalentpayable April 1, 2022, to 1.64 per annum).shareowners of record as of March 10, 2022. Future dividends will be declared at the discretion of the Board of Directors and will depend upon future earnings, cash flows, financial and legal requirements and other relevant factors.
Subject to certain exceptions, PPL may not declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067 or 2013 Series B Junior Subordinated Notes due 2073.2067. At December 31, 2017,2021, no interest payments were deferred.
(PPL Electric, LKE, LG&E and KU)
From time to time, as determined by their respective Board of Directors, the Registrants pay dividends, distributions or distributions,return capital, as applicable, to their respective shareholders or members. Certain of the credit facilities of PPL Electric, LKE, LG&E and KU include minimum debt covenant ratios that could effectively restrict the payment of dividends or distributions.
(All Registrants)
See Note 78 to the Financial Statements for these and other restrictions related to distributions on capital interests for the Registrants and their subsidiaries.
Purchase or Redemption of Debt Securities
The Registrants will continue to evaluate outstanding debt securities and may decide to purchase or redeem these securities in open market or privately negotiated transactions, in exchange transactions or otherwise, depending upon prevailing market conditions, available cash and other factors, and may be commenced or suspended at any time. The amounts involved may be material.
Rating Agency Actions
Moody's and S&P periodically review the credit ratings of the debt of the Registrants and their subsidiaries. Based on their respective independent reviews, the rating agencies may make certain ratings revisions or ratings affirmations.
A credit rating reflects an assessment by the rating agency of the creditworthiness associated with an issuer and particular securities that it issues. The credit ratings of the Registrants and their subsidiaries are based on information provided by the Registrants and other sources. The ratings of Moody's and S&P are not a recommendation to buy, sell or hold any securities of the Registrants or their subsidiaries. Such ratings may be subject to revisions or withdrawal by the agencies at any time and should be evaluated independently of each other and any other rating that may be assigned to the securities.
The credit ratings of the Registrants and their subsidiaries affect their liquidity, access to capital markets and cost of borrowing under their credit facilities. A downgrade in the Registrants' or their subsidiaries' credit ratings could result in higher borrowing costs and reduced access to capital markets. The Registrants and their subsidiaries have no credit rating triggers that would result in the reduction of access to capital markets or the acceleration of maturity dates of outstanding debt.
The following table sets forth the Registrants' and their subsidiaries' credit ratings for outstanding debt securities or commercial paper programs as of December 31, 2017.
2021.
| Senior Unsecured | Senior Secured | Commercial Paper | ||||||||||||||||||||||||||||||||||||
| Issuer | Moody's | S&P | Moody's | S&P | Moody's | S&P | ||||||||||||||||||||||||||||||||
| PPL Capital Funding | Baa2 | BBB+ | P-2 | A-2 | ||||||||||||||||||||||||||||||||||
| PPL and PPL Electric | ||||||||||||||||||||||||||||||||||||||
| PPL Electric | A1 | A | P-2 | A-2 | ||||||||||||||||||||||||||||||||||
| PPL, LG&E and | ||||||||||||||||||||||||||||||||||||||
| A1 | A | P-2 | A-2 | |||||||||||||||||||||||||||||||||||
| A1 | A | P-2 | A-2 | |||||||||||||||||||||||||||||||||||
The rating agencies have taken the following actions related to the Registrants and their subsidiaries.
(PPL)
In March 2017,2021, Moody's and S&P assigned ratings of Baa1 and A-revised its outlook to WPD (South Wales)’s £50 million 0.01% Index-linked Senior Notes due 2029.
(PPL and PPL Electric)
In January 2017, Moody's andMarch 2021, S&P affirmed their commercial paper ratingsrevised its outlook to positive for PPL Electric's $650 million commercial paper program.Electric.
In May 2017, Moody'sJune 2021, Moody’s and S&P assigned ratings of A1 and A to PPL Electric's $475Electric’s $650 million 3.95% First Mortgage Bonds, Floating Rate Series, due 2047.2024. The bonds were issued on June 24, 2021.
(PPL and LG&E)
In August 2017, Moody'sMarch 2021, Moody’s and S&P assigned a ratingratings of A1 and S&P confirmed its rating of A for LCIDA's $116 million 1.80% Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project) Series 2016A due 2029 and LCIDA's $108 million 1.80% Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project) Series 2016B due 2027, each previously issued on behalf of PPL Electric.
In March 2021, Moody’s assigned a rating of A1 and in April 2021, S&P assigned a rating of A to the Louisville/Jefferson County Metro Government, Kentucky’s $35 million 1.35% Pollution Control Revenue Bonds, 2001 Series B, due 2027, previously issued on behalf of LG&E. The bonds were remarketed May 3, 2021.
In March 2021, Moody’s assigned a rating of A1 and in April 2021, S&P assigned a rating of A to the County of Trimble, Kentucky’s $35 million 1.35% Pollution Control Revenue Bonds, 2001 Series B, due 2027, previously issued on behalf of LG&E. The bonds were remarketed May 3, 2021.
In May 2017,2021, Moody’s and S&P assigned ratings of A1/P-2 and A/A-2 to the Louisville/Jefferson County Metro Government, Kentucky’s $31 million Environmental Facilities Revenue Refunding Bonds, 2007 Series A, due 2033, previously issued on behalf of LG&E. The bonds were remarketed June 1, 2021.
In May 2021, Moody’s and S&P assigned ratings of A1/P-2 and A/A-2 to the Louisville/Jefferson County Metro Government, Kentucky’s $35 million Environmental Facilities Revenue Refunding Bonds, 2007 Series B, due 2033, previously issued on behalf of LG&E. The bonds were remarketed June 1, 2021.
In August 2021, Moody's and S&P assigned ratings of A1 and A to the County of Trimble, Kentucky's $60$28 million 3.75% Environmental Facilities0.625% Pollution Control Revenue Bonds, 20172001 Series A, (Louisville Gas and Electric Company Project) due 2033, issued on behalf of LG&E.
(PPL and KU)
In May 2017, Moody’s2021, Moody's and S&P assigned a ratingratings of A1 and in June 2017, S&P confirmed its rating of A for the Louisville/Jefferson Metro Government of Kentucky's $35 million 1.25% Environmental Facilities Revenue Refunding Bonds, 2007 Series B (Louisville Gas and Electric Company Project) due 2033, previously issued on behalf of LG&E.
52
In May 2021, Moody's and S&P assigned ratings of A1 and A to the County of Carroll, Kentucky's $54 million 2.125% Environmental Facilities Revenue Refunding Bonds, 2006 Series B, (Kentucky Utilities Company Project) due 2034, each previously issued on behalf of KU. The bonds were remarketed June 1, 2021.
Ratings Triggers
(PPL, LKE, 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 and foreign currency instruments, (for PPL), contain provisions that require the posting of additional collateral or permit the counterparty to terminate the contract, if PPL's, LKE's, LG&E's or KU's or their subsidiaries' credit rating, as applicable, were to fall below investment grade. See Note 1718 to the Financial Statements for a discussion of "Credit Risk-Related Contingent Features," including a discussion of the potential additional collateral requirements for PPL LKE and LG&E for derivative contracts in a net liability position at December 31, 2017.2021.
Guarantees for Subsidiaries(PPL)
PPL guarantees certain consolidated affiliate financing arrangements. Some of the guarantees contain financial and other covenants that, if not met, would limit or restrict the consolidated affiliates' access to funds under these financing arrangements, accelerate maturity of such arrangements or limit the consolidated affiliates' ability to enter into certain transactions. At this
time, PPL believes that these covenants will not limit access to relevant funding sources. See Note 1314 to the Financial Statements for additional information about guarantees.
The Registrants have entered into certain agreements that may contingently require payment to a guaranteed or indemnified party. See Note 1314 to the Financial Statements for a discussion of these agreements.
Risk Management
Market Risk
(All Registrants)
See Notes 1, 16,17 and 1718 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
53
The following interest rate hedges were outstanding at December 31. 31:
| 2021 | 2020 | ||||||||||||||||||||||||||||||||||||||||
| Exposure Hedged | Fair Value, Net - Asset (Liability) (a) | Effect of a 10% Adverse Movement in Rates (b) | Maturities Ranging Through | Exposure Hedged | Fair Value, Net - Asset (Liability) (a) | Effect of a 10% Adverse Movement in Rates (b) | |||||||||||||||||||||||||||||||||||
| PPL and LG&E | |||||||||||||||||||||||||||||||||||||||||
| Economic hedges | |||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps (c) | $ | 64 | $ | (19) | $ | (1) | 2033 | $ | 64 | $ | (24) | $ | — | ||||||||||||||||||||||||||||
| 2017 | 2016 | ||||||||||||||||||||||||
Exposure Hedged | Fair Value, Net - Asset (Liability) (a) | Effect of a 10% Adverse Movement in Rates (b) | Maturities Ranging Through | Exposure Hedged | Fair Value, Net - Asset (Liability) (a) | Effect of a 10% Adverse Movement in Rates (b) | |||||||||||||||||||
| PPL | |||||||||||||||||||||||||
| Cash flow hedges | |||||||||||||||||||||||||
| Cross-currency swaps (c) | $ | 702 | $ | 103 | $ | (84 | ) | 2028 | $ | 802 | $ | 191 | $ | (90 | ) | ||||||||||
| Economic hedges | |||||||||||||||||||||||||
| Interest rate swaps (d) | 147 | (27 | ) | (1 | ) | 2033 | 147 | (32 | ) | (2 | ) | ||||||||||||||
| LKE | |||||||||||||||||||||||||
| Economic hedges | |||||||||||||||||||||||||
| Interest rate swaps (d) | 147 | (27 | ) | (1 | ) | 2033 | 147 | (32 | ) | (2 | ) | ||||||||||||||
| LG&E | |||||||||||||||||||||||||
| Economic hedges | |||||||||||||||||||||||||
| Interest rate swaps (d) | 147 | (27 | ) | (1 | ) | 2033 | 147 | (32 | ) | (2 | ) | ||||||||||||||
(a)Includes accrued interest, if applicable.
(b)Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability. Sensitivities represent a 10% adverse movement in interest rates.
(c)Realized changes in the fair value of such economic hedges are recoverable through regulated rates and any subsequent changes in the fair value of these derivatives are included in regulatory assets or regulatory liabilities.
The Registrants are exposed to a potential increase in interest expense and to changes in the fair value of their debt portfolios. The estimated impact of a 10% adverse movement in interest rates on interest expense at December 31, 20172021 and 20162020 was insignificant for PPL, PPL Electric, LKE, LG&E and KU. The estimated impact of a 10% adverse movement in interest rates on the fair value of debt at December 31 is shown below.
| 10% Adverse Movement in Rates | |||||||||||
| 2021 | 2020 | ||||||||||
| PPL | $ | 394 | $ | 582 | |||||||
| PPL Electric | 164 | 175 | |||||||||
| LG&E | 74 | 74 | |||||||||
| KU | 115 | 118 | |||||||||
| 10% Adverse Movement in Rates | |||||||
| 2017 | 2016 | ||||||
| PPL | $ | 620 | $ | 590 | |||
| PPL Electric | 162 | 138 | |||||
| LKE | 168 | 182 | |||||
| LG&E | 62 | 66 | |||||
| KU | 92 | 100 | |||||
| 2017 | 2016 | ||||||||||||||||||||||||
Exposure Hedged | Fair Value, Net - Asset (Liability) | Effect of a 10% Adverse Movement in Foreign Currency Exchange Rates (a) | Maturities Ranging Through | Exposure Hedged | Fair Value, Net - Asset (Liability) | Effect of a 10% Adverse Movement in Foreign Currency Exchange Rates (a) | |||||||||||||||||||
| Economic hedges (b) | £ | 2,563 | $ | 15 | $ | (323 | ) | 2020 | £ | 1,909 | $ | 184 | $ | (215 | ) | ||||||||||
(All Registrants)
Commodity Price Risk
PPL is exposed to commodity price risk through its domestic subsidiaries as described below.
•PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is insignificant and mitigated through its PUC-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 expenses. These mechanisms generally provide for timely recovery of market price fluctuations associated with these expenses.
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.
Defined Benefit Plans - Equity Securities Price Risk
See "Application of Critical Accounting Policies - Defined Benefits" for additional information regarding the effect of equity securities price risk on plan assets.
54
Credit Risk
(All Registrants)
Credit risk is the risk that the Registrants would incur a loss as a result of nonperformance by counterparties of their contractual obligations. The Registrants maintain credit policies and procedures with respect to counterparty credit (including requirements that counterparties maintain specified credit ratings) and require other assurances in the form of credit support or collateral in certain circumstances in order to limit counterparty credit risk. However, the Registrants, as applicable, have concentrations of suppliers and customers among electric utilities, financial institutions and energy marketing and trading companies. These concentrations may impact the Registrants' overall exposure to credit risk, positively or negatively, as counterparties may be similarly affected by changes in economic, regulatory or other conditions.
(PPL and PPL Electric)
In January 2017, the PUC issued a Final Order approving PPL Electric's PLR procurementElectric’s default service plan for the period June 2017 through May 2021, which included a total of eight semi-annual solicitations for electricity supply. Additionally, on December 17, 2020, the PUC approved PPL Electric’s default service plan for the period of June 2021 through May 2025, which includes a total of eight solicitations for electricity supply semi-annuallyheld semiannually in April and October. To date, PPL Electric has conducted two of its plannedThe new plan also includes eight competitive solicitations.solicitations for alternative energy credits held semiannually in January and July with the first solicitation being in July 2021 and the final solicitation being in January 2025.
Under the standard Supply Master Agreement (the Agreement) for the competitive solicitation process, PPL Electric requires all suppliers to post collateral if their credit exposure exceeds an established credit limit. In the event a supplier defaults on its obligation, PPL Electric would be required to seek replacement power in the market. All incremental costs incurred by PPL Electric would be recoverable from customers in future rates. At December 31, 2017,2021, most of the successful bidders under all of the solicitations had an investment grade credit rating from S&P and were not required to post collateral under the Agreement. A small portion of bidders were required to post an insignificant amount of collateral under the Agreement. There is no instance under the Agreement in which PPL Electric is required to post collateral to its suppliers.
See Note 1718 to the Financial Statements for additional information on credit risk.
Foreign Currency Translation(PPL)
The value of the British pound sterling fluctuates in relation to the U.S. dollar. In 2017,2021, changes in this exchange rate resulted in a foreign currency translation gain of $537$495 million, which primarily reflected a $935an $856 million increase to PP&E, and $198a $151 million increase to goodwill and a $36 million increase to other net assets, partially offset by a $549$467 million increase to long-term debt, a $61 million increase to deferred income taxes and ana $20 million increase of $47 million to other net liabilities.long-term debt due within one year. In 2016,2020, changes in this exchange rate resulted in a foreign currency translation lossgain of $1.1 billion,$267 million, which primarily reflected a $2.1 billion decrease$433 million increase to PP&E and $490a $76 million decreaseincrease to goodwill partially offset by a $1.3 billion decrease$214 million increase to long-term debt and a decrease of $208$28 million increase to other net liabilities. In 2015,2019, changes in this exchange rate resulted in a foreign currency translation lossgain of $240$106 million, which primarily reflected a $472$181 million increase to PP&E, $34 million increase to goodwill and $12 million decrease to PP&E and $117 million decrease to goodwillother net liabilities partially offset by a $285$121 million decreaseincrease to long-term debtdebt.
As a result of the sale of the U.K. utility business on June 14, 2021, accumulated foreign currency translation losses of $786 million were removed from PPL’s Balance Sheets and realized as a decreasecomponent of $64 million“Income (Loss) from Discontinued Operations (net of income taxes)” on PPL’s Statements of Income (Loss) for the year ended December 31, 2021. See Note 9 to other net liabilities.the Financial Statements for additional information.
(All Registrants)
Related Party Transactions
The Registrants are not aware of any material ownership interests or operating responsibility by senior management in outside partnerships, including leasing transactions with variable interest entities, or other entities doing business with the Registrants. See Note 1415 to the Financial Statements for additional information on related party transactions for PPL Electric, LKE, LG&E and KU.
55
Acquisitions, Development and Divestitures
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 89 to the Financial Statements for additional information on the more significant activities.sale of the U.K. utility business and the share purchase agreement to acquire Narragansett Electric.
(All Registrants)
Environmental Matters
Extensive federal, state and local environmental laws and regulations are applicable to PPL's, PPL Electric's, LKE's, LG&E's and KU'sthe Registrants' air emissions, water discharges and the management of hazardous and solid waste, as well as other aspects of the Registrants' businesses. The costcosts 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 costcosts for their products or their demand for the Registrants' services. Increased capital and operating costs are expected to be subject to rate recovery. PPL, PPL Electric, LKE, LG&E and KUThe Registrants can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.
See "Legal Matters" in Note 1314 to the Financial Statements for a discussion of the more significant environmental matters including: Legal Matters, NAAQS, Climate Change, CCRs, and ELGs.claims. 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" for information on projected environmental capital expenditures for 20182022 through 2022.2024. See Note 1920 to the Financial Statements for information related to the impacts of CCRs on AROs. See "Item 1. Business - Environmental Matters" for additional information.
Sustainability
Increasing attention has been focused on a broad range of corporate activities under the heading of “sustainability”, which has resulted in a significant increase in the number of requests from interested parties for information on sustainability topics. These parties range from investor groups focused on environmental, social, governance and other matters to non-investors concerned with a variety of public policy matters. Often the scope of the information sought is very broad and not necessarily relevant to an issuer’s business or industry. As a result, a number of private groups have proposed to standardize the subject matter constituting sustainability, either generally or by industry. Those efforts remain ongoing. In addition, certain of these private groups have advocated that the SEC promulgate regulations requiring specific sustainability reporting under the Securities Exchange Act of 1934, as amended (the “’34 Act”)’34 Act), or that issuers voluntarily include certain sustainability disclosure in their ’34 Act reports. To date, no new reporting requirements have been adopted or proposed by the SEC.
As has been PPL’s practice, to the extent sustainability issues have or may have a material impact on the Registrants’ financial condition or results of operation, PPL discloses such matters in accordance with applicable securities law and SEC regulations. With respect to other sustainability topics that PPL deems relevant to investors but that are not required to be reported under applicable securities law and SEC regulation, PPL will continue each spring to publish its annual sustainability report including tracking reductions related to the company's goal to reduce carbon emissions and post that report on its corporate website at www.pplweb.com and on www.pplsustainability.com. Neither the information in such annual sustainability report nor the information at such websites is incorporated in this Form 10-K by reference, and it should not be considered a part of this Form 10-K. In preparing its sustainability report, PPL is guided by the framework established by the Global Reporting Initiative, which identifies environmental, social, governance and other subject matter categories, together with recentcategories. PPL also participates in efforts by the Edison Electric Institute to provide guidance as to the appropriate subset of sustainability information that can be applied consistently across the electric utility industry. Additionally, PPL publicly discloses its corporate political contributions and responds to the CDP climate survey.
Cybersecurity
See “Cybersecurity Management” in “Item 1. Business” and “Item 1A. Risk factors” for a discussion of cybersecurity risks affecting the Registrants and the related strategies for managing these risks.
Competition
See "Competition" under each of PPL's reportable segments in "Item 1. Business - General - Segment Information" and "Item 1A. Risk Factors" for a discussion of competitive factors affecting the Registrants.
New Accounting Guidance
Application of Critical Accounting Policies
Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. The following accounting policies are particularly important to an understanding of the reported financial condition or results of operations and require management to make estimates or other judgments of matters that are inherently uncertain. Changes in the estimates or other judgments included within these accounting policies could result in a significant change to the information presented in the Financial Statements (these accounting policies are also discussed in Note 1 to the Financial Statements). Senior management has reviewed with PPL's Audit Committee these critical accounting policies, the following disclosures regarding their application, and the estimates and assumptions regarding them.
Defined Benefits
(All Registrants)
Certain of the Registrants and/or their subsidiaries sponsor or participate in as applicable, certain qualified funded and non-qualified unfunded defined benefit pension plans and both funded and unfunded other postretirement benefit plans. These plans are applicable to the majority of the Registrants' employees (based on eligibility for their applicable plans). The Registrants and certain of their subsidiaries record an asset or liability to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, in the case of PPL Electric, LG&E and KU, regulatory assets and liabilities for amounts that are expected to be recovered through regulated customer rates. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. See Notes 61, 7 and 1112 to the Financial Statements for additional information about the plans and the accounting for defined benefits.
A summary of plan sponsors by Registrant and whether a Registrant or its subsidiaries sponsor (S) or participate in and receives allocations (P) from those plans is shown in the table below.
| Plan Sponsor | PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||||||||||
| PPL Services | S | P | ||||||||||||||||||||||||||||||
| P | ||||||||||||||||||||||||||||||||
| P | ||||||||||||||||||||||||||||||||
Management makes certain assumptions regarding the valuation of benefit obligations and the performance of plan assets. As such, annual net periodic defined benefit costs are recorded in current earnings or regulatory assets and liabilities based on estimated results. Any differences between actual and estimated results are recorded in AOCI or, in the case of PPL Electric, LG&E and KU, regulatory assets and liabilities for amounts that are expected to be recovered through regulated customer rates. These amounts in AOCI or regulatory assets and liabilities are amortized to income over future periods. The delayed recognition allows for a smoothed recognition of costs over the working lives of the employees who benefit under the plans. The primarysignificant assumptions are:
•Discount Rate - The discount rate is used in calculating the present value of benefits, which is based on projections of benefit payments to be made in the future. The objective in selecting the discount rate is to measure the single amount that, if invested at the measurement date in a portfolio of high-quality debt instruments, would provide the necessary future cash flows to pay the accumulated benefits when due.
In selecting the discount rates for U.S. defined benefit plans, the plan sponsors start with a cash flow analysis of the expected benefit payment stream for their plans. The plan-specific cash flows are matched against the coupons and expected maturity values of individually selected bonds. This bond matching process begins with the full universe of Aa-rated non-callable (or callable with make-whole provisions) bonds serving as the base from which those with the lowest and highest yields are eliminated to develop an appropriate subset of bonds. Individual bonds are then selected based on the timing of each plan's cash flows and parameters are established as to the percentage of each individual bond issue that could be hypothetically purchased and the surplus reinvestment rates to be assumed.
•Expected Return on Plan Assets - The expected long-term rates of return for pension and other postretirement benefits are based on plan assetsmanagement's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
•Rate of Compensation Increase - Management projects employees' annual pay increases, which are used to project employees' pension benefits at retirement. In selecting a rate of compensation increase, plan sponsors consider past experience, in lightthe potential impact of movements in inflation rates.rates and expectations of ongoing compensation practices.
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See Note 12 to the weighted-averageFinancial Statements for details of the assumptions selected for discount rate, expected return on planpension and other postretirement benefits. A variance in the assumptions could significantly impact accrued defined benefit liabilities or assets, and rate of compensation increase at December 31 used to measure current year obligations and subsequent yearreported annual net periodic defined benefit costs under GAAP, as applicable. and AOCI or regulatory assets and liabilities.
| Assumption / Registrant | 2017 | 2016 | ||||
| Discount rate | ||||||
| Pension - PPL (U.S.) | 3.70 | % | 4.21 | % | ||
| Pension - PPL (U.K.) Obligations | 2.65 | % | 2.87 | % | ||
| Pension - PPL (U.K.) Service Cost (a) | 2.73 | % | 2.99 | % | ||
| Pension - PPL (U.K.) Interest Cost (a) | 2.31 | % | 2.41 | % | ||
| Pension - LKE | 3.69 | % | 4.19 | % | ||
| Pension - LG&E | 3.65 | % | 4.13 | % | ||
| Other Postretirement - PPL | 3.64 | % | 4.11 | % | ||
| Other Postretirement - LKE | 3.65 | % | 4.12 | % | ||
| Expected return on plan assets | ||||||
| Pension - PPL (U.S.) | 7.25 | % | 7.00 | % | ||
| Pension - PPL (U.K.) | 7.23 | % | 7.22 | % | ||
| Pension - LKE | 7.25 | % | 7.00 | % | ||
| Pension - LG&E | 7.25 | % | 7.00 | % | ||
| Other Postretirement - PPL | 6.40 | % | 6.21 | % | ||
| Other Postretirement - LKE | 7.15 | % | 6.82 | % | ||
| Rate of compensation increase | ||||||
| Pension - PPL (U.S.) | 3.78 | % | 3.95 | % | ||
| Pension - PPL (U.K.) | 3.50 | % | 3.50 | % | ||
| Pension - LKE | 3.50 | % | 3.50 | % | ||
| Other Postretirement - PPL | 3.75 | % | 3.92 | % | ||
| Other Postretirement - LKE | 3.50 | % | 3.50 | % | ||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Balance Sheet: | |||||||||||||||||||
| Regulatory assets (a) | $ | 880 | $ | 504 | $ | 376 | $ | 234 | $ | 142 | |||||||||
| Regulatory liabilities | 27 | 27 | 27 | ||||||||||||||||
| Pension assets | 284 | ||||||||||||||||||
| Pension liabilities | 813 | 246 | 369 | 45 | 36 | ||||||||||||||
Other postretirement and postemployment benefit liabilities | 184 | 62 | 107 | 74 | 32 | ||||||||||||||
| AOCI (pre-tax) | 3,144 | 150 | |||||||||||||||||
| Statement of Income: | |||||||||||||||||||
| Defined benefits expense | $ | (87 | ) | $ | 12 | $ | 33 | $ | 11 | $ | 5 | ||||||||
| Increase (decrease) from prior year | (52 | ) | 1 | 3 | — | (2 | ) | ||||||||||||
| Increase (Decrease) | ||||||
| Discount Rate | (0.25 | %) | ||||
| Expected Return on Plan Assets | (0.25 | %) | ||||
| Rate of Compensation Increase | 0.25 | % | ||||
| Increase (Decrease) | Increase (Decrease) | (Increase) Decrease | Increase (Decrease) | Increase (Decrease) | |||||||||||||||||||||||||
| Actuarial assumption | Defined Benefit Asset | Defined Benefit Liabilities | AOCI (pre-tax) | Net Regulatory Assets | Defined Benefit Costs | ||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||
| Discount rates | $ | (128) | $ | 13 | $ | 52 | $ | 89 | $ | 16 | |||||||||||||||||||
| Expected return on plan assets | n/a | n/a | n/a | n/a | 9 | ||||||||||||||||||||||||
| Rate of compensation increase | (11) | — | 4 | 7 | 3 | ||||||||||||||||||||||||
| PPL Electric | |||||||||||||||||||||||||||||
| Discount rates | (50) | 6 | — | 56 | 5 | ||||||||||||||||||||||||
| Expected return on plan assets | n/a | n/a | — | n/a | 4 | ||||||||||||||||||||||||
| Rate of compensation increase | (4) | — | — | 4 | 1 | ||||||||||||||||||||||||
| LG&E | |||||||||||||||||||||||||||||
| Discount rates | (16) | 2 | n/a | 17 | 3 | ||||||||||||||||||||||||
| Expected return on plan assets | n/a | n/a | n/a | n/a | 1 | ||||||||||||||||||||||||
| Rate of compensation increase | (1) | — | n/a | 1 | 1 | ||||||||||||||||||||||||
| KU | |||||||||||||||||||||||||||||
| Discount rates | (14) | 2 | n/a | 16 | 2 | ||||||||||||||||||||||||
| Expected return on plan assets | n/a | n/a | n/a | n/a | 1 | ||||||||||||||||||||||||
| Rate of compensation increase | (1) | — | n/a | 1 | — | ||||||||||||||||||||||||
| Increase (Decrease) | (Increase) Decrease | Increase (Decrease) | Increase (Decrease) | ||||||||||||
| Actuarial assumption | Defined Benefit Liabilities | AOCI (pre-tax) | Net Regulatory Assets | Defined Benefit Costs | |||||||||||
| PPL | |||||||||||||||
| Discount rates | $ | 520 | $ | 416 | $ | 104 | $ | 43 | |||||||
| Expected return on plan assets | n/a | n/a | n/a | 27 | |||||||||||
| Rate of compensation increase | 72 | 60 | 12 | 9 | |||||||||||
| Health care cost trend rate (a) | 4 | — | 4 | — | |||||||||||
| PPL Electric | |||||||||||||||
| Discount rates | 64 | — | 64 | 4 | |||||||||||
| Expected return on plan assets | n/a | — | n/a | 4 | |||||||||||
| Rate of compensation increase | 8 | — | 8 | 1 | |||||||||||
| Health care cost trend rate (a) | 1 | — | 1 | — | |||||||||||
| LKE | |||||||||||||||
| Discount rates | 68 | 28 | 40 | 8 | |||||||||||
| Expected return on plan assets | n/a | n/a | n/a | 3 | |||||||||||
| Rate of compensation increase | 10 | 5 | 5 | 2 | |||||||||||
| Health care cost trend rate (a) | 3 | — | 3 | — | |||||||||||
| LG&E | |||||||||||||||
| Discount rates | 21 | n/a | 21 | 3 | |||||||||||
| Expected return on plan assets | n/a | n/a | n/a | 1 | |||||||||||
| Rate of compensation increase | 2 | n/a | 2 | — | |||||||||||
| Health care cost trend rate (a) | 1 | n/a | 1 | — | |||||||||||
| KU | |||||||||||||||
| Discount rates | 18 | n/a | 18 | 2 | |||||||||||
| Expected return on plan assets | n/a | n/a | n/a | 1 | |||||||||||
| Rate of compensation increase | 3 | n/a | 3 | — | |||||||||||
| Health care cost trend rate (a) | 2 | n/a | 2 | — | |||||||||||
Income Taxes(All Registrants)
Significant management judgment is also required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken inon tax returns and valuation allowances on deferred tax assets and whether the undistributed earnings of WPD are considered indefinitely reinvested.assets.
On a quarterly basis, uncertain tax positions are reassessed by considering information known as of the reporting date. Based on management's assessment of new information, a tax benefit may subsequently be recognized for a previously unrecognized tax position, a previously recognized tax position may be derecognized, or the benefit of a previously recognized tax position may be remeasured. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements in the future. Unrecognized tax benefits are classified as current to the extent management expects to settle an uncertain tax position by payment or receipt of cash within one year of the reporting date.
The need for valuation allowances to reduce deferred tax assets also requires significant management judgment. Valuation allowances are initially recorded and reevaluated each reporting period by assessing the likelihood of the ultimate realization of a deferred tax asset. Management considers a number ofseveral factors in assessing the expected realization of a deferred tax asset, including the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies. Any tax planning strategy utilized in this assessment must meet the recognition and measurement criteria utilized to account for an uncertain tax position. Management also considersWhen evaluating the need for valuation allowances, the uncertainty posed by political risk and the effecton such
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factors that management takes into account in evaluating the need for valuation allowances.is also considered by management. The amount of deferred tax assets ultimately realized may differ materially from the estimates utilized in the computation of valuation allowances and may materially impact the financial statements in the future.
The TCJA included new provisions requiring that certain income, referred to as global intangible low-taxed income (GILTI), earned by certain foreign subsidiaries be included in the gross income of their U.S. shareholder. The FASB allows an accounting policy election regarding the timing of inclusion of GILTI in an entity’s financial statements. The election may be either to record deferred taxes for expected GILTI in future periods or record such taxes as a current-period expense when incurred. PPL has elected to record the tax effect of expected GILTI inclusions and thus, records deferred taxes relating to such inclusions. PPL does not expect to generate GILTI income following the disposition of U.K. utilities business.
See Note 56 to the Financial Statements for income tax disclosures, including the impact of the TCJA and management's conclusion that the undistributed earnings of WPD are considered indefinitely reinvested. Based on this conclusion, PPL Global does not record U.S. federal income taxes on WPD's undistributed earnings.disclosures.
Regulatory Assets and Liabilities
(All Registrants)
PPL Electric, LG&E and KU are subject to cost-based rate regulation. As a result, the effects of regulatory actions are required to be reflected in the financial statements. Assets and liabilities are recorded that result from the regulated ratemaking process that may not be recorded under GAAP for non-regulated entities. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in regulated customer rates. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose.
Management continually assesses whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders to the Registrants and other regulated entities, and the status of any pending or potential deregulation legislation. Based on this continual assessment, management believes the existing regulatory assets are probable of recovery. This assessment reflects the current political and regulatory climate at the state and federal levels and is subject to change in the future. If future recovery of costs
ceases to be probable, the regulatory asset would be written-off. Additionally, the regulatory agencies can provide flexibility in the manner and timing of recovery of regulatory assets.
See Note 67 to the Financial Statements for regulatory assets and regulatory liabilities recorded at December 31, 20172021 and 2016,2020, as well as additional information on those regulatory assets and liabilities. All regulatory assets are either currently being recovered under specific rate orders, represent amounts that are expected to be recovered in future rates or benefit future periods based upon established regulatory practices.
Goodwill Impairment
(PPL, LKE, LG&E and KU)
Goodwill is tested for impairment at the reporting unit level. PPL has determined itsThe reporting units to be atof PPL include the same level as its reportable segments.Kentucky Regulated segment reporting unit and the LKE reporting unit. LG&E and KU are individually single operating and reportable segments.segments and each are single reporting units. A goodwill impairment test is performed annually or more frequently if events or changes in circumstances indicate that the carrying amount of the reporting unit may be greater than the reporting unit's fair value. Additionally, goodwill is tested for impairment after a portion of goodwill has been allocated to a business to be disposed of.
The fair value of a reporting unit is compared with the carrying value and an impairment charge is recognized if the carrying amount exceeds the fair value of the reporting unit.
PPL, for its Kentucky Regulated segment and LKE reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a two-step quantitative test. IfSee "Long-Lived and Intangible Assets - Asset Impairment (Excluding Investments)" in Note 1 to the qualitative evaluation (referred to as "step zero") is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the two-step quantitative impairment test is not necessary.
In the fourth quarter of $2.6 billion related to the acquisition of WPD and $662 million related to the acquisition of LKE.2021, PPL, (forfor its U.K. Regulated and Kentucky Regulated segments),segment and LKE reporting units, and individually, LKE, LG&E and KU, elected to perform the qualitative step zero evaluation ofevaluations for their annual goodwill impairment tests, as of October 1, 2017. These evaluations considered the excess of fair value over the carrying value of each reporting unit that was calculated during step one of the quantitative impairment tests performed in the fourth quarter of 2015, and the relevant events and circumstances that occurred since those tests were performed including:
2021.
Based on these evaluations, management concluded it was not more"more likely than notnot" that the fair value of these reporting units was less than their carrying values. As such, the two-step quantitative impairment test wastests were not performed.
(PPL)
In the fourth quarter of 2021, PPL elected to perform a quantitative goodwill impairment test in conjunction with the annual goodwill impairment assessment for the Distributed Energy Resources reporting unit, which has a goodwill balance of $53 million at December 31, 2021. The test did not indicate impairment of the reporting unit. See Note 1 to the Financial Statements for additional information.
Management used both discounted cash flows and market multiples, which required significant assumptions, to estimate the fair value of the reporting unit. Significant assumptions used in the discounted cash flows include discount and growth rates and projected operating and capital cash flows. Projected operating and capital cash flows are based on internal business plans, which assume the occurrence of certain future events. Significant assumptions used in the market multiples include sector market performance and comparable transactions. A high degree of judgment is required to develop estimates related to fair value conclusions. A decrease in the forecasted cash flows of 10%, an increase in the discount rate of 10%, or a 10% decrease in the market multiples would not have resulted in an impairment of goodwill for the Distributed Energy Resources reporting unit as of October 1, 2021, however, it is possible that an impairment charge could occur in future periods if any of the assumptions used in determining fair value of the reporting unit are negatively impacted.
Asset Retirement Obligations(PPL, LKE, LG&E and KU)
ARO liabilities are required to be recognized for legal obligations associated with the retirement of long-lived assets. The initial obligation isInitial obligations are measured at its estimated fair value. An ARO must be recognized when incurred if the fair value of the ARO can be reasonably estimated. An equivalent amount is recorded as an increase in the value of the capitalized asset and amortized to expense over the asset's useful life of the asset. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.life.
In determining AROs, management must make significant judgments and estimates to calculate fair value. Fair value is developed using an expected present value technique based on assumptions of market participants that consider estimated retirement costs in current period dollars, that are inflated to the anticipated retirement date and then discounted back to the date the ARO was incurred. Changes in assumptions and estimates included within the calculations of the fair value of AROs could result in significantly different results than those identified and recorded in the financial statements. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO.ARO estimate. Any change to the capitalized asset positive or negative, is generally amortized over the remaining life of the associated long-lived asset.
See “Long-Lived and Intangible Assets - Asset Retirement Obligations” in Note 1, Note 7 and Note 20 to the Financial Statements for additional information on AROs.
At December 31, 2017,2021, the total recorded balances and information on the most significant recorded AROs were as follows.
| Most Significant AROs | |||||||||||||||||||||||||||||||||||
| Most Significant AROs | Total ARO Recorded | Amount Recorded | % of Total | Description | |||||||||||||||||||||||||||||||
Total ARO Recorded | Amount Recorded | % of Total | Description | ||||||||||||||||||||||||||||||||
| PPL | $ | 397 | $ | 284 | 72 | Ponds, landfills and natural gas mains | |||||||||||||||||||||||||||||
| LKE | 356 | 284 | 80 | Ponds, landfills and natural gas mains | |||||||||||||||||||||||||||||||
| LG&E | 121 | 89 | 74 | Ponds, landfills and natural gas mains | LG&E | $ | 84 | $ | 66 | 79 | Ponds, landfills and natural gas mains | ||||||||||||||||||||||||
| KU | 235 | 195 | 83 | Ponds and landfills | KU | 105 | 80 | 76 | Ponds and landfills | ||||||||||||||||||||||||||
The most significant assumptions surrounding AROs are the forecasted retirement costs (including the settlement dates and the timing of cash flows), the discount rates and the inflation rates. At December 31, 2017,2021, a 10% increase to retirement cost would increase these ARO liabilities by $32 million.$13 million at LG&E and $23 million at KU. A 0.25% decrease in the discount rate would increase these ARO liabilities by $4 million at LG&E and $1 million at KU and a 0.25% increase in the inflation rate would increase these ARO liabilities by $2 million.$4 million at LG&E. There would be no significant change to the annual depreciation expense of the ARO asset or the annual accretion expense of the ARO liability as a result of these changes in assumptions.
Revenue Recognition - Unbilled Revenues(LKE, LG&E and KU)
Revenues related to the sale of energy are recorded when service is rendered or when energy is delivered to customers. Because customers are billed on cycles which vary based on the timing of the actual meter reads taken throughout the month, estimates are recorded for unbilled revenues at the end of each reporting period. For LG&E and KU, such unbilled revenue amounts reflect
60
estimates of deliveries to customers since the date of the last reading of their meters. The unbilled revenue estimates reflect consideration of factors including daily load models, estimated usage for each customer class, the effect of current and different rate schedules, the meter read schedule, the billing schedule, actual weather data, and, where applicable, the impact of
weather normalization or other regulatory provisions of rate structures. See "Unbilled revenues" on the Registrants' Balance Sheets for balances at December 31, 20172021 and 2016.2020.
Other Information(All Registrants)
PPL's Audit Committee has approved the independent auditor to provide audit and audit-related services, tax services and other services permitted by Sarbanes-Oxley and SEC rules. The audit and audit-related services include services in connection with statutory and regulatory filings, reviews of offering documents and registration statements, and internal control reviews.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Reference is made to "Risk Management" for the Registrants in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations."
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareowners and the Board of Directors of PPL Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of PPL Corporation and subsidiaries (the "Company") as of December 31, 20172021 and 2016,2020, the related consolidated statements of income, comprehensive income, equity, and cash flows, for each of the three years thenin the period ended December 31, 2021, and the related notes and the schedule listed in the Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 20172021 and 2016,2020, and the results of its operations and its cash flows for each of the three years thenin the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2017,2021, based on criteria established in Internal Control –— Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 22, 2018,18, 2022, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinionopinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities – Impact of Rate Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, PPL Corporation owns and operates three cost-based rate-regulated utilities for which rates are set by the Federal Energy Regulatory Commission (FERC), the Kentucky Public Service Commission (KPSC), the Virginia State Corporation Commission (VSCC), and the Pennsylvania Public Utility Commission (PUC) to enable the regulated utilities to recover the costs of providing electric or gas services, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC, KPSC, VSCC, and PUC. The accounting for the economics of rate-regulation also impacts other financial statement line items,
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including regulated utility plant, operating revenues, depreciation, and income taxes and impacts multiple note disclosures. As of December 31, 2021, PPL Corporation had a recorded regulatory assets balance of $1,300 million and regulatory liabilities balance of $2,604 million.
PPL Corporation’s regulated utilities’ rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the FERC, KPSC, VSCC, and PUC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital, and the timing and amount of assets to be recovered by rates. The FERC, KPSC, VSCC, and PUC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the FERC, KPSC, VSCC, and PUC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While PPL Corporation’s utilities have indicated that they expect to recover costs from customers through regulated rates, there is a risk that the FERC, KPSC, VSCC, or PUC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors, such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the FERC, KPSC, VSCC, and PUC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the FERC, KPSC, VSCC, and PUC for PPL Corporation’s regulated utilities and other public utilities, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders, and other filings with the commissions to identify any evidence that could indicate utility plant may be abandoned.
•We evaluated PPL Corporation’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ Deloitte & Touche LLP
Parsippany, New Jersey
February 22, 2018 18, 2022
We have served as the Company's auditor since 2015.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareowners and the Board of Directors of PPL Corporation
Opinion on Internal Control overthe Financial ReportingStatements
We have audited the internal control over financial reportingaccompanying consolidated balance sheets of PPL Corporation and subsidiaries (the "Company") as of December 31, 2017, based on criteria established in Internal Control – Integrated Framework (2013) issued by2021 and 2020, the Committeerelated consolidated statements of Sponsoring Organizationsincome, comprehensive income, equity, and cash flows, for each of the Treadway Commission (COSO)three years in the period ended December 31, 2021, and the related notes (collectively referred to as the "financial statements"). In our opinion, the Company maintained,financial statements present fairly, in all material respects, effective internal control overthe financial reportingposition of the Company as of December 31, 2017, based on criteria established2021 and 2020, and the results of its operations and its cash flows for each of the three years in Internal Control – Integrated Framework (2013) issued by COSO.the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidatedCompany's internal control over financial statements and financial statement schedulereporting as of and for the year ended December 31, 2017,2021, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the CompanyTreadway Commission and our report dated February 22, 2018,18, 2022, expressed an unqualified opinion on thosethe Company's internal control over financial statements.reporting.
Basis for Opinion
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities – Impact of Rate Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, PPL Corporation owns and operates three cost-based rate-regulated utilities for which rates are set by the Federal Energy Regulatory Commission (FERC), the Kentucky Public Service Commission (KPSC), the Virginia State Corporation Commission (VSCC), and the Pennsylvania Public Utility Commission (PUC) to enable the regulated utilities to recover the costs of providing electric or gas services, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC, KPSC, VSCC, and PUC. The accounting for the economics of rate-regulation also impacts other financial statement line items,
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including regulated utility plant, operating revenues, depreciation, and income taxes and impacts multiple note disclosures. As of December 31, 2021, PPL Corporation had a recorded regulatory assets balance of $1,300 million and regulatory liabilities balance of $2,604 million.
PPL Corporation’s regulated utilities’ rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the FERC, KPSC, VSCC, and PUC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital, and the timing and amount of assets to be recovered by rates. The FERC, KPSC, VSCC, and PUC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the FERC, KPSC, VSCC, and PUC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While PPL Corporation’s utilities have indicated that they expect to recover costs from customers through regulated rates, there is a risk that the FERC, KPSC, VSCC, or PUC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors, such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the FERC, KPSC, VSCC, and PUC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the FERC, KPSC, VSCC, and PUC for PPL Corporation’s regulated utilities and other public utilities, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders, and other filings with the commissions to identify any evidence that could indicate utility plant may be abandoned.
•We evaluated PPL Corporation’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ Deloitte & Touche LLP
Parsippany, New Jersey
February 22, 2018 18, 2022
We have served as the Company's auditor since 2015.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Sole MemberShareowners and the Board of Directors of LG&E and KU Energy LLCPPL Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Kentucky Utilities CompanyPPL Corporation and subsidiaries (the “Company”"Company") as of December 31, 20172021 and 2016,2020, the related consolidated statements of income, comprehensive income, equity, and cash flows, for each of the three years thenin the period ended December 31, 2021, and the related notes (collectively referred to as the “financial statements”"financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 20172021 and 2016,2020, and the results of its operations and its cash flows for each of the three years thenin the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 18, 2022, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities – Impact of Rate Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, PPL Corporation owns and operates three cost-based rate-regulated utilities for which rates are set by the Federal Energy Regulatory Commission (FERC), the Kentucky Public Service Commission (KPSC), the Virginia State Corporation Commission (VSCC), and the Pennsylvania Public Utility Commission (PUC) to enable the regulated utilities to recover the costs of providing electric or gas services, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC, KPSC, VSCC, and PUC. The accounting for the economics of rate-regulation also impacts other financial statement line items,
62
including regulated utility plant, operating revenues, depreciation, and income taxes and impacts multiple note disclosures. As of December 31, 2021, PPL Corporation had a recorded regulatory assets balance of $1,300 million and regulatory liabilities balance of $2,604 million.
PPL Corporation’s regulated utilities’ rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the FERC, KPSC, VSCC, and PUC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital, and the timing and amount of assets to be recovered by rates. The FERC, KPSC, VSCC, and PUC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the FERC, KPSC, VSCC, and PUC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While PPL Corporation’s utilities have indicated that they expect to recover costs from customers through regulated rates, there is a risk that the FERC, KPSC, VSCC, or PUC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors, such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the FERC, KPSC, VSCC, and PUC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the FERC, KPSC, VSCC, and PUC for PPL Corporation’s regulated utilities and other public utilities, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders, and other filings with the commissions to identify any evidence that could indicate utility plant may be abandoned.
•We evaluated PPL Corporation’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ Deloitte & Touche LLP
Parsippany, New Jersey
February 18, 2022
We have served as the Company's auditor since 2015.
63
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareowners and the Board of Directors of PPL Corporation
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of PPL Corporation and subsidiaries (the “Company”) as of December 31, 2021, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control — Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2021, of the Company and our report dated February 18, 2022, expressed an unqualified opinion on those financial statements.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting at Item 9A. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Deloitte & Touche LLP
Parsippany, New Jersey
February 18, 2022
64
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareowner and the Board of Directors of PPL Electric Utilities Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of PPL Electric Utilities Corporation and subsidiaries (the "Company") as of December 31, 2021 and 2020, the related consolidated statements of income, equity, and cash flows, for each of the three years in the period ended December 31, 2021, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities – Impact of Rate Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, PPL Electric Utilities Corporation (PPL Electric) is a cost-based rate-regulated utility for which rates are set by the Federal Energy Regulatory Commission (FERC) and the Pennsylvania Public Utility Commission (PUC) to enable the regulated utility to recover the costs of providing electric service and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC and PUC. The accounting for the economics of rate-regulation also impacts other financial statement line items, including
65
regulated utility plant, operating revenues, depreciation, and income taxes, and impacts multiple note disclosures. As of December 31, 2021, PPL Electric had a recorded regulatory assets balance of $510 million and regulatory liabilities balance of $712 million.
PPL Electric’s regulated utility’s rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the FERC and PUC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital, and the timing and amount of assets to be recovered by rates. The FERC and PUC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the FERC and PUC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While PPL Electric has indicated that it expects to recover costs from customers through regulated rates, there is a risk that the FERC or PUC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the FERC and PUC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the FERC and PUC for PPL Electric and other public utilities in Pennsylvania, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders and other filings with the commissions to identify any evidence that may contradict management’s assertion regarding probability of an abandonment.
•We evaluated PPL Electric’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ Deloitte & Touche LLP
February 22, 201818, 2022
We have served as the Company’sCompany's auditor since 2015.
66
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Opinion on the Financial Statements
We have audited the accompanying balance sheets of Louisville Gas and Electric Company (the “Company”) as of December 31, 2021 and 2020, the related statements of income, equity, and cash flows, for each of Kentucky Utilities Company for the yearthree years in the period ended December 31, 2015. 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on thesethe Company's financial statements based on our audit.audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our auditaudits in accordance with the standards of the Public Company Accounting Oversight Board (United States).PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. Wemisstatement, whether due to error or fraud. The Company is not required to have, nor were notwe engaged to perform, an audit of the Company'sits internal control over financial reporting. Our audit included considerationAs part of our audits, we are required to obtain an understanding of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company'sCompany’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence supportingregarding the amounts and disclosures in the financial statements, assessingstatements. Our audits also included evaluating the accounting principles used and significant estimates made by management, andas well as evaluating the overall presentation of the financial statement presentation.statements. We believe that our audit providesaudits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities– Impact of Rate-Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, Louisville Gas and Electric Company (LG&E) is a cost-based rate-regulated utility for which rates are set by the Kentucky Public Service Commission (KPSC) and the Federal Energy Regulatory Commission (FERC) to enable the regulated utility to recover the costs of providing electric or gas services, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the KPSC and FERC. The accounting for the economics of rate-regulation also impacts other financial statement line items, including regulated utility plant, operating revenues, depreciation, and income taxes, and impacts
67
multiple note disclosures. As of December 31, 2021, LG&E had a recorded regulatory assets balance of $370 million and regulatory liabilities balance of $839 million.
LG&E’s regulated utility’s rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the KPSC and FERC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. The KPSC and FERC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the KPSC and FERC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While LG&E has indicated that it expects to recover costs from customers through regulated rates, there is a risk that the KPSC or FERC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the KPSC and FERC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the KPSC and FERC for LG&E and other public utilities in Kentucky, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders and other filings with the commissions to identify any evidence that could indicate utility plant may be abandoned.
•We evaluated LG&E’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ Deloitte & Touche LLP
Louisville, Kentucky
February 18, 2022
We have served as the Company’s auditor since 2015.
68
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Stockholder and the Board of Directors of Kentucky Utilities Company
Opinion on the Financial Statements
We have audited the accompanying balance sheets of Kentucky Utilities Company (the “Company”) as of December 31, 2021 and 2020, the related statements of income, equity, and cash flows, for each of the three years in the period ended December 31, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities – Impact of Rate-Regulation on Various Account Balances and Disclosures – Refer to Notes 1 and 7 to the financial statements
Critical Audit Matter Description
As discussed in Note 1 to the financial statements, Kentucky Utilities Company (KU) is a cost-based rate-regulated utility for which rates are set by the year ended December 31, 2015, in conformity with U.S.Kentucky Public Service Commission (KPSC), the Virginia State Corporation Commission (VSCC), and the Federal Energy Regulatory Commission (FERC) to enable the regulated utility to recover the costs of providing electric service and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by generally accepted accounting principles.principles and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the KPSC, VSCC, and FERC. The accounting for the economics of rate-regulation also impacts other financial statement line items, including regulated utility plant, operating revenues, depreciation, and income taxes, and
69
impacts multiple note disclosures. As of December 31, 2021, KU had a recorded regulatory assets balance of $420 million and regulatory liabilities balance of $1,053 million.
KU’s regulated utility’s rates are subject to cost-based rate-setting processes and annual earnings oversight. Rates are established based on an analysis of the costs incurred and the regulated utility’s capital structure and must be approved by one or more federal or state regulatory commissions, including the KPSC, VSCC, and FERC. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. The KPSC, VSCC, and FERC regulation of rates is premised on the full recovery of prudently incurred costs and an adequate return on capital investments. Decisions to be made by the KPSC, VSCC, and FERC in the future will impact the accounting for regulated operations, including decisions about the amount of allowable costs and return on invested capital included in rates and any refunds that may be required. While KU has indicated that it expects to recover costs from customers through regulated rates, there is a risk that the KPSC, VSCC, or FERC will not approve full recovery of such costs or approve recovery on a timely basis in future regulatory decisions.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management in continually assessing whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders, and the status of any pending legislation. Auditing these judgments required specialized knowledge of accounting for rate regulation and the rate-setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by the KPSC, VSCC, and FERC included the following, among others:
•We tested the effectiveness of management’s internal controls over evaluating the likelihood of recovery in future rates of costs deferred as regulatory assets. We tested the effectiveness of management’s controls over the recognition of amounts as regulated utility plant, regulatory assets or liabilities, operating revenues, depreciation, income taxes, and note disclosures. We tested the effectiveness of management’s internal controls over the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates or of a future reduction in rates.
•We obtained and read relevant regulatory orders issued by the KPSC, VSCC, and FERC for KU and other public utilities in Kentucky and Virginia, regulatory statutes, interpretations, procedural memorandums, filings made by interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
•We inquired of management about regulated utility plant that may be abandoned. We inspected minutes of the Board of Directors, other public information, regulatory orders and other filings with the commissions to identify any evidence that could indicate utility plant may be abandoned.
•We evaluated KU’s disclosures related to the impacts of rate-regulation, including the balances recorded and regulatory developments, in the financial statements.
/s/ ErnstDeloitte & YoungTouche LLP
Louisville, Kentucky
February 19, 201618, 2022
We have served as the Company’s auditor since 2015.
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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
FOR THE YEARS ENDED DECEMBER 31,
PPL Corporation and Subsidiaries
(Millions of Dollars, except share data)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Operating Revenues | $ | 7,447 | $ | 7,517 | $ | 7,669 | Operating Revenues | $ | 5,783 | $ | 5,474 | $ | 5,602 | |||||||||||||||
| Operating Expenses | Operating Expenses | |||||||||||||||||||||||||||
| Operation | Operation | |||||||||||||||||||||||||||
| Fuel | 759 | 791 | 863 | Fuel | 710 | 632 | 709 | |||||||||||||||||||||
| Energy purchases | 685 | 706 | 855 | Energy purchases | 752 | 634 | 723 | |||||||||||||||||||||
| Other operation and maintenance | 1,635 | 1,745 | 1,938 | Other operation and maintenance | 1,608 | 1,420 | 1,509 | |||||||||||||||||||||
| Depreciation | 1,008 | 926 | 883 | Depreciation | 1,082 | 1,022 | 949 | |||||||||||||||||||||
| Taxes, other than income | 292 | 301 | 299 | Taxes, other than income | 207 | 180 | 186 | |||||||||||||||||||||
| Total Operating Expenses | 4,379 | 4,469 | 4,838 | Total Operating Expenses | 4,359 | 3,888 | 4,076 | |||||||||||||||||||||
| Operating Income | 3,068 | 3,048 | 2,831 | Operating Income | 1,424 | 1,586 | 1,526 | |||||||||||||||||||||
| Other Income (Expense) - net | (255 | ) | 390 | 108 | Other Income (Expense) - net | 15 | 2 | 14 | ||||||||||||||||||||
| Interest Expense | 901 | 888 | 871 | Interest Expense | 918 | 634 | 621 | |||||||||||||||||||||
| Income from Continuing Operations Before Income Taxes | 1,912 | 2,550 | 2,068 | |||||||||||||||||||||||||
| Income (Loss) from Continuing Operations Before Income Taxes | Income (Loss) from Continuing Operations Before Income Taxes | 521 | 954 | 919 | ||||||||||||||||||||||||
| Income Taxes | 784 | 648 | 465 | Income Taxes | 503 | 314 | 183 | |||||||||||||||||||||
| Income from Continuing Operations After Income Taxes | 1,128 | 1,902 | 1,603 | |||||||||||||||||||||||||
| Income (Loss) from Continuing Operations After Income Taxes | Income (Loss) from Continuing Operations After Income Taxes | 18 | 640 | 736 | ||||||||||||||||||||||||
| Loss from Discontinued Operations (net of income taxes) (Note 8) | — | — | (921 | ) | ||||||||||||||||||||||||
| Income (Loss) from Discontinued Operations (net of income taxes) (Note 9) | Income (Loss) from Discontinued Operations (net of income taxes) (Note 9) | (1,498) | 829 | 1,010 | ||||||||||||||||||||||||
| Net Income | $ | 1,128 | $ | 1,902 | $ | 682 | ||||||||||||||||||||||
| Net Income (Loss) | Net Income (Loss) | $ | (1,480) | $ | 1,469 | $ | 1,746 | |||||||||||||||||||||
| Earnings Per Share of Common Stock: | Earnings Per Share of Common Stock: | |||||||||||||||||||||||||||
| Income from Continuing Operations After Income Taxes Available to PPL Common Shareowners: | ||||||||||||||||||||||||||||
| Basic | $ | 1.64 | $ | 2.80 | $ | 2.38 | Basic | |||||||||||||||||||||
| Income (Loss) from Continuing Operations After Income Taxes | Income (Loss) from Continuing Operations After Income Taxes | $ | 0.03 | $ | 0.83 | $ | 1.01 | |||||||||||||||||||||
| Income (Loss) from Discontinued Operations (net of income taxes) | Income (Loss) from Discontinued Operations (net of income taxes) | (1.96) | 1.08 | 1.38 | ||||||||||||||||||||||||
| Net Income (Loss) Available to PPL Common Shareowners | Net Income (Loss) Available to PPL Common Shareowners | $ | (1.93) | $ | 1.91 | $ | 2.39 | |||||||||||||||||||||
| Diluted | $ | 1.64 | $ | 2.79 | $ | 2.37 | Diluted | |||||||||||||||||||||
| Net Income Available to PPL Common Shareowners: | ||||||||||||||||||||||||||||
| Basic | $ | 1.64 | $ | 2.80 | $ | 1.01 | ||||||||||||||||||||||
| Diluted | $ | 1.64 | $ | 2.79 | $ | 1.01 | ||||||||||||||||||||||
| Dividends Declared Per Share of Common Stock | $ | 1.58 | $ | 1.52 | $ | 1.50 | ||||||||||||||||||||||
| Income (Loss) from Continuing Operations After Income Taxes | Income (Loss) from Continuing Operations After Income Taxes | $ | 0.03 | $ | 0.83 | $ | 1.00 | |||||||||||||||||||||
| Income (Loss) from Discontinued Operations (net of income taxes) | Income (Loss) from Discontinued Operations (net of income taxes) | (1.96) | 1.08 | 1.37 | ||||||||||||||||||||||||
| Net Income (Loss) Available to PPL Common Shareowners | Net Income (Loss) Available to PPL Common Shareowners | $ | (1.93) | $ | 1.91 | $ | 2.37 | |||||||||||||||||||||
| Weighted-Average Shares of Common Stock Outstanding (in thousands) | Weighted-Average Shares of Common Stock Outstanding (in thousands) | |||||||||||||||||||||||||||
| Basic | 685,240 | 677,592 | 669,814 | Basic | 762,902 | 768,590 | 728,512 | |||||||||||||||||||||
| Diluted | 687,334 | 680,446 | 672,586 | Diluted | 764,819 | 769,384 | 736,754 | |||||||||||||||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
FOR THE YEARS ENDED DECEMBER 31,
PPL Corporation and Subsidiaries
(Millions of Dollars)
| 2017 | 2016 | 2015 | |||||||||
| Net income | $ | 1,128 | $ | 1,902 | $ | 682 | |||||
| Other comprehensive income (loss): | |||||||||||
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | |||||||||||
| Foreign currency translation adjustments, net of tax of ($1), ($4), $1 | 538 | (1,107 | ) | (234 | ) | ||||||
| Available-for-sale securities, net of tax of $0, $0, ($9) | — | — | 8 | ||||||||
| Qualifying derivatives, net of tax of $19, ($18), $0 | (79 | ) | 91 | 26 | |||||||
| Defined benefit plans: | |||||||||||
| Prior service costs, net of tax of $0, $2, $6 | — | (3 | ) | (9 | ) | ||||||
| Net actuarial gain (loss), net of tax of $72, $40, $67 | (308 | ) | (61 | ) | (366 | ) | |||||
| Reclassifications to net income - (gains) losses, net of tax expense (benefit): | |||||||||||
| Available-for-sale securities, net of tax of $0, $0, $2 | — | — | (2 | ) | |||||||
| Qualifying derivatives, net of tax of ($18), $21, ($15) | 73 | (91 | ) | 2 | |||||||
| Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0 | 1 | (1 | ) | (1 | ) | ||||||
| Defined benefit plans: | |||||||||||
| Prior service costs, net of tax of ($1), ($1), $0 | 1 | 1 | — | ||||||||
| Net actuarial (gain) loss, net of tax of ($37), ($35), ($46) | 130 | 121 | 146 | ||||||||
| Total other comprehensive income (loss) | 356 | (1,050 | ) | (430 | ) | ||||||
| Comprehensive income | $ | 1,484 | $ | 852 | $ | 252 | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Net income (loss) | $ | (1,480) | $ | 1,469 | $ | 1,746 | |||||||||||
| Other comprehensive income (loss): | |||||||||||||||||
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | |||||||||||||||||
| Foreign currency translation adjustments, net of tax of ($123), $0, $0 | 372 | 267 | 108 | ||||||||||||||
| Qualifying derivatives, net of tax of $11, $5, $2 | (39) | (19) | (11) | ||||||||||||||
| Defined benefit plans: | |||||||||||||||||
| Prior service costs, net of tax of $0, $0, $0 | — | (1) | (1) | ||||||||||||||
| Net actuarial gain (loss), net of tax of $1, $74, $119 | (1) | (341) | (592) | ||||||||||||||
| Reclassifications from AOCI - (gains) losses, net of tax expense (benefit): | |||||||||||||||||
| Qualifying derivatives, net of tax of ($5), ($8), ($5) | 25 | 24 | 13 | ||||||||||||||
| Defined benefit plans: | |||||||||||||||||
| Prior service costs, net of tax of ($1), ($1), ($1) | 2 | 3 | 2 | ||||||||||||||
| Net actuarial (gain) loss, net of tax of ($33), ($51), ($22) | 126 | 205 | 87 | ||||||||||||||
| Reclassifications from AOCI due to sale of the U.K. utility business - (gains) losses, net of tax expense (benefit): | |||||||||||||||||
| Foreign currency translation adjustments, net of tax of $140, $0, $0 | 786 | — | — | ||||||||||||||
| Qualifying derivatives, net of tax of $0, $0, $0 | 15 | — | — | ||||||||||||||
| Defined benefit plans: | |||||||||||||||||
| Prior service costs, net of tax of ($2), $0, $0 | 8 | — | — | ||||||||||||||
| Net actuarial (gain) loss, net of tax of ($798), $0, $0 | 2,769 | — | — | ||||||||||||||
| Total other comprehensive income (loss) | 4,063 | 138 | (394) | ||||||||||||||
| Comprehensive income | $ | 2,583 | $ | 1,607 | $ | 1,352 | |||||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31,
PPL Corporation and Subsidiaries
(Millions of Dollars)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | |||||||||||||||||||||||||||
| Net income | $ | 1,128 | $ | 1,902 | $ | 682 | ||||||||||||||||||||||
| Loss from discontinued operations (net of income taxes) | — | — | 921 | |||||||||||||||||||||||||
| Net income (loss) | Net income (loss) | $ | (1,480) | $ | 1,469 | $ | 1,746 | |||||||||||||||||||||
| Loss (income) from discontinued operations (net of income taxes) | Loss (income) from discontinued operations (net of income taxes) | 1,498 | (829) | (1,010) | ||||||||||||||||||||||||
| Income from continuing operations (net of income taxes) | 1,128 | 1,902 | 1,603 | Income from continuing operations (net of income taxes) | 18 | 640 | 736 | |||||||||||||||||||||
| Adjustments to reconcile Income from continuing operations (net of taxes) to net cash provided by (used in) operating activities - continuing operations | ||||||||||||||||||||||||||||
| 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 | 1,008 | 926 | 883 | Depreciation | 1,082 | 1,022 | 949 | |||||||||||||||||||||
| Amortization | 97 | 80 | 59 | Amortization | 39 | 58 | 58 | |||||||||||||||||||||
| Defined benefit plans - expense (income) | (95 | ) | (40 | ) | 56 | |||||||||||||||||||||||
| Deferred income taxes and investment tax credits | 707 | 560 | 428 | Deferred income taxes and investment tax credits | 87 | 169 | 169 | |||||||||||||||||||||
| Unrealized (gains) losses on derivatives, and other hedging activities | 178 | 19 | (77 | ) | ||||||||||||||||||||||||
| Stock compensation expense | 38 | 28 | 31 | |||||||||||||||||||||||||
| Impairment of solar panels | Impairment of solar panels | 37 | — | — | ||||||||||||||||||||||||
| Loss on extinguishment of debt | Loss on extinguishment of debt | 395 | — | — | ||||||||||||||||||||||||
| Other | (9 | ) | (12 | ) | (14 | ) | Other | 20 | 67 | 69 | ||||||||||||||||||
| Change in current assets and current liabilities | Change in current assets and current liabilities | |||||||||||||||||||||||||||
| Accounts receivable | (33 | ) | (15 | ) | 47 | Accounts receivable | (14) | (70) | (3) | |||||||||||||||||||
| Accounts payable | (10 | ) | 57 | (116 | ) | Accounts payable | 24 | (1) | (66) | |||||||||||||||||||
| Unbilled revenues | (48 | ) | (63 | ) | 54 | |||||||||||||||||||||||
| Fuel, materials and supplies | 40 | (3 | ) | 24 | ||||||||||||||||||||||||
| Taxes payable | 3 | 31 | (175 | ) | Taxes payable | 27 | 131 | 9 | ||||||||||||||||||||
| Regulatory assets and liabilities, net | (12 | ) | (59 | ) | 42 | Regulatory assets and liabilities, net | 52 | (63) | (88) | |||||||||||||||||||
| Other | 14 | (32 | ) | (7 | ) | Other | (67) | 118 | (29) | |||||||||||||||||||
| Other operating activities | Other operating activities | |||||||||||||||||||||||||||
| Defined benefit plans - funding | (565 | ) | (427 | ) | (499 | ) | Defined benefit plans - funding | (53) | (119) | (73) | ||||||||||||||||||
| Settlement of interest rate swaps | 2 | (9 | ) | (101 | ) | |||||||||||||||||||||||
| Other assets | 30 | 42 | (19 | ) | Other assets | (111) | (59) | (100) | ||||||||||||||||||||
| Other liabilities | (12 | ) | (95 | ) | 53 | Other liabilities | 8 | (21) | (24) | |||||||||||||||||||
| Net cash provided by operating activities - continuing operations | 2,461 | 2,890 | 2,272 | Net cash provided by operating activities - continuing operations | 1,544 | 1,872 | 1,607 | |||||||||||||||||||||
| Net cash provided by operating activities - discontinued operations | — | — | 343 | Net cash provided by operating activities - discontinued operations | 726 | 874 | 820 | |||||||||||||||||||||
| Net cash provided by operating activities | 2,461 | 2,890 | 2,615 | Net cash provided by operating activities | 2,270 | 2,746 | 2,427 | |||||||||||||||||||||
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | |||||||||||||||||||||||||||
| Expenditures for property, plant and equipment | (3,133 | ) | (2,920 | ) | (3,533 | ) | Expenditures for property, plant and equipment | (1,973) | (2,270) | (2,243) | ||||||||||||||||||
| Expenditures for intangible assets | (38 | ) | (37 | ) | (37 | ) | ||||||||||||||||||||||
| Proceeds from the sale of other investments | — | 2 | 136 | |||||||||||||||||||||||||
| Proceeds from sale of discontinued operations, net of cash divested | Proceeds from sale of discontinued operations, net of cash divested | 10,560 | — | — | ||||||||||||||||||||||||
| Other investing activities | 15 | 37 | (5 | ) | Other investing activities | (23) | 4 | 10 | ||||||||||||||||||||
| Net cash used in investing activities - continuing operations | (3,156 | ) | (2,918 | ) | (3,439 | ) | ||||||||||||||||||||||
| Net cash used in investing activities - discontinued operations | — | — | (149 | ) | ||||||||||||||||||||||||
| Net cash used in investing activities | (3,156 | ) | (2,918 | ) | (3,588 | ) | ||||||||||||||||||||||
| Net cash provided by (used in) investing activities - continuing operations | Net cash provided by (used in) investing activities - continuing operations | 8,564 | (2,266) | (2,233) | ||||||||||||||||||||||||
| Net cash provided by (used in) investing activities - discontinued operations | Net cash provided by (used in) investing activities - discontinued operations | (607) | (992) | (847) | ||||||||||||||||||||||||
| Net cash provided by (used in) investing activities | Net cash provided by (used in) investing activities | 7,957 | (3,258) | (3,080) | ||||||||||||||||||||||||
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | |||||||||||||||||||||||||||
| Issuance of long-term debt | 1,515 | 1,342 | 2,236 | Issuance of long-term debt | 650 | 1,848 | 1,099 | |||||||||||||||||||||
| Retirement of long-term debt | (168 | ) | (930 | ) | (1,000 | ) | Retirement of long-term debt | (4,606) | (975) | (300) | ||||||||||||||||||
| Issuance of common stock | 453 | 144 | 203 | Issuance of common stock | 9 | 34 | 1,167 | |||||||||||||||||||||
| Proceeds from project financing | Proceeds from project financing | 19 | 173 | — | ||||||||||||||||||||||||
| Payment of common stock dividends | (1,072 | ) | (1,030 | ) | (1,004 | ) | Payment of common stock dividends | (1,279) | (1,275) | (1,192) | ||||||||||||||||||
| Net increase in short-term debt | 115 | 29 | 94 | |||||||||||||||||||||||||
| Purchase of treasury stock | Purchase of treasury stock | (1,003) | — | — | ||||||||||||||||||||||||
| Issuance of term loan | Issuance of term loan | — | 300 | — | ||||||||||||||||||||||||
| Issuance of commercial paper | Issuance of commercial paper | — | 73 | — | ||||||||||||||||||||||||
| Retirement of term loan | Retirement of term loan | (300) | — | — | ||||||||||||||||||||||||
| Retirement of commercial paper | Retirement of commercial paper | (73) | — | — | ||||||||||||||||||||||||
| Net increase (decrease) in short-term debt | Net increase (decrease) in short-term debt | (726) | (43) | (341) | ||||||||||||||||||||||||
| Other financing activities | (19 | ) | 6 | (47 | ) | Other financing activities | (35) | (36) | (25) | |||||||||||||||||||
| Net cash provided by (used in) financing activities - continuing operations | 824 | (439 | ) | 482 | Net cash provided by (used in) financing activities - continuing operations | (7,344) | 99 | 408 | ||||||||||||||||||||
| Net cash used in financing activities - discontinued operations | — | — | (546 | ) | ||||||||||||||||||||||||
| Net cash distributions to parent from discontinued operations | — | — | 132 | |||||||||||||||||||||||||
| Net cash provided by (used in) financing activities - discontinued operations | Net cash provided by (used in) financing activities - discontinued operations | (411) | 209 | 171 | ||||||||||||||||||||||||
| Contributions from discontinued operations | Contributions from discontinued operations | 365 | 78 | 257 | ||||||||||||||||||||||||
| Net cash provided by (used in) financing activities | 824 | (439 | ) | 68 | Net cash provided by (used in) financing activities | (7,390) | 386 | 836 | ||||||||||||||||||||
| Effect of Exchange Rates on Cash and Cash Equivalents | 15 | (28 | ) | (10 | ) | |||||||||||||||||||||||
| Net (Increase) Decrease in Cash and Cash Equivalents included in Discontinued Operations | — | — | 352 | |||||||||||||||||||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 144 | (495 | ) | (563 | ) | |||||||||||||||||||||||
| Cash and Cash Equivalents at Beginning of Period | 341 | 836 | 1,399 | |||||||||||||||||||||||||
| Cash and Cash Equivalents at End of Period | $ | 485 | $ | 341 | $ | 836 | ||||||||||||||||||||||
| Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations | Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations | 8 | 17 | 10 | ||||||||||||||||||||||||
| Net (Increase) Decrease in Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations | Net (Increase) Decrease in Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations | 284 | (108) | (154) | ||||||||||||||||||||||||
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | 3,129 | (217) | 39 | ||||||||||||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 443 | 660 | 621 | ||||||||||||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at End of Period | Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 3,572 | $ | 443 | $ | 660 | |||||||||||||||||||||
| Supplemental Disclosures of Cash Flow Information | Supplemental Disclosures of Cash Flow Information | |||||||||||||||||||||||||||
| Cash paid (received) during the period for: | Cash paid (received) during the period for: | |||||||||||||||||||||||||||
| Interest - net of amount capitalized | $ | 845 | $ | 854 | $ | 822 | Interest - net of amount capitalized | $ | 191 | $ | 586 | $ | 552 | |||||||||||||||
| Income taxes - net | $ | 65 | $ | 70 | $ | 179 | Income taxes - net | $ | 284 | $ | 4 | $ | (12) | |||||||||||||||
| Significant non-cash transactions: | Significant non-cash transactions: | |||||||||||||||||||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 360 | $ | 281 | $ | 310 | Accrued expenditures for property, plant and equipment at December 31, | $ | 245 | $ | 257 | $ | 292 | |||||||||||||||
| Accrued expenditures for intangible assets at December 31, | $ | 68 | $ | 117 | $ | 55 | ||||||||||||||||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED BALANCE SHEETS AT DECEMBER 31,
PPL Corporation and Subsidiaries
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Assets | Assets | |||||||||||||||||
| Current Assets | Current Assets | |||||||||||||||||
| Cash and cash equivalents | $ | 485 | $ | 341 | Cash and cash equivalents | $ | 3,571 | $ | 442 | |||||||||
| Accounts receivable (less reserve: 2017, $51; 2016, $54) | ||||||||||||||||||
| Accounts receivable (less reserve: 2021, $65; 2020, $71) | Accounts receivable (less reserve: 2021, $65; 2020, $71) | |||||||||||||||||
| Customer | 681 | 666 | Customer | 583 | 603 | |||||||||||||
| Other | 100 | 46 | Other | 58 | 86 | |||||||||||||
| Unbilled revenues | 543 | 480 | ||||||||||||||||
| Unbilled revenues (less reserve: 2021, $2; 2020, $4) | Unbilled revenues (less reserve: 2021, $2; 2020, $4) | 307 | 301 | |||||||||||||||
| Fuel, materials and supplies | 320 | 356 | Fuel, materials and supplies | 322 | 302 | |||||||||||||
| Prepayments | 66 | 63 | Prepayments | 60 | 53 | |||||||||||||
| Price risk management assets | 49 | 63 | ||||||||||||||||
| Other current assets | 50 | 52 | Other current assets | 106 | 130 | |||||||||||||
| Current assets held for sale (Note 9) | Current assets held for sale (Note 9) | — | 18,983 | |||||||||||||||
| Total Current Assets | 2,294 | 2,067 | Total Current Assets | 5,007 | 20,900 | |||||||||||||
| Property, Plant and Equipment | Property, Plant and Equipment | |||||||||||||||||
| Regulated utility plant | 38,228 | 34,674 | Regulated utility plant | 30,477 | 29,040 | |||||||||||||
| Less: accumulated depreciation - regulated utility plant | 6,785 | 6,013 | Less: accumulated depreciation - regulated utility plant | 6,488 | 6,008 | |||||||||||||
| Regulated utility plant, net | 31,443 | 28,661 | Regulated utility plant, net | 23,989 | 23,032 | |||||||||||||
| Non-regulated property, plant and equipment | 384 | 413 | Non-regulated property, plant and equipment | 266 | 237 | |||||||||||||
| Less: accumulated depreciation - non-regulated property, plant and equipment | 110 | 134 | Less: accumulated depreciation - non-regulated property, plant and equipment | 41 | 37 | |||||||||||||
| Non-regulated property, plant and equipment, net | 274 | 279 | Non-regulated property, plant and equipment, net | 225 | 200 | |||||||||||||
| Construction work in progress | 1,375 | 1,134 | Construction work in progress | 1,256 | 1,268 | |||||||||||||
| Property, Plant and Equipment, net | 33,092 | 30,074 | Property, Plant and Equipment, net | 25,470 | 24,500 | |||||||||||||
| Other Noncurrent Assets | Other Noncurrent Assets | |||||||||||||||||
| Regulatory assets | 1,504 | 1,918 | Regulatory assets | 1,236 | 1,262 | |||||||||||||
| Goodwill | 3,258 | 3,060 | Goodwill | 716 | 716 | |||||||||||||
| Other intangibles | 697 | 700 | Other intangibles | 343 | 351 | |||||||||||||
| Pension benefit asset | 284 | 9 | ||||||||||||||||
| Price risk management assets | 215 | 336 | ||||||||||||||||
| Other noncurrent assets | 135 | 151 | ||||||||||||||||
| Other noncurrent assets (less reserve for accounts receivable: 2021, $2; 2020, $0) | Other noncurrent assets (less reserve for accounts receivable: 2021, $2; 2020, $0) | 451 | 387 | |||||||||||||||
| Total Other Noncurrent Assets | 6,093 | 6,174 | Total Other Noncurrent Assets | 2,746 | 2,716 | |||||||||||||
| Total Assets | $ | 41,479 | $ | 38,315 | Total Assets | $ | 33,223 | $ | 48,116 | |||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
75
CONSOLIDATED BALANCE SHEETS AT DECEMBER 31,
PPL Corporation and Subsidiaries
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Liabilities and Equity | Liabilities and Equity | |||||||||||||||||
| Current Liabilities | Current Liabilities | |||||||||||||||||
| Short-term debt | $ | 1,080 | $ | 923 | Short-term debt | $ | 69 | $ | 1,168 | |||||||||
| Long-term debt due within one year | 348 | 518 | Long-term debt due within one year | 474 | 1,074 | |||||||||||||
| Accounts payable | 924 | 820 | Accounts payable | 679 | 745 | |||||||||||||
| Taxes | 105 | 101 | Taxes | 96 | 69 | |||||||||||||
| Interest | 282 | 270 | Interest | 81 | 113 | |||||||||||||
| Dividends | 273 | 259 | Dividends | 305 | 319 | |||||||||||||
| Customer deposits | 292 | 276 | ||||||||||||||||
| Regulatory liabilities | 95 | 101 | Regulatory liabilities | 182 | 79 | |||||||||||||
| Other current liabilities | 624 | 569 | Other current liabilities | 437 | 465 | |||||||||||||
| Current liabilities held for sale (Note 9) | Current liabilities held for sale (Note 9) | — | 11,023 | |||||||||||||||
| Total Current Liabilities | 4,023 | 3,837 | Total Current Liabilities | 2,323 | 15,055 | |||||||||||||
| Long-term Debt | 19,847 | 17,808 | Long-term Debt | 10,666 | 13,615 | |||||||||||||
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | |||||||||||||||||
| Deferred income taxes | 2,462 | 3,889 | Deferred income taxes | 3,151 | 2,536 | |||||||||||||
| Investment tax credits | 129 | 132 | Investment tax credits | 119 | 122 | |||||||||||||
| Accrued pension obligations | 800 | 1,001 | Accrued pension obligations | 183 | 189 | |||||||||||||
| Asset retirement obligations | 312 | 428 | Asset retirement obligations | 157 | 132 | |||||||||||||
| Regulatory liabilities | 2,704 | 899 | Regulatory liabilities | 2,422 | 2,530 | |||||||||||||
| Other deferred credits and noncurrent liabilities | 441 | 422 | Other deferred credits and noncurrent liabilities | 479 | 564 | |||||||||||||
| Total Deferred Credits and Other Noncurrent Liabilities | 6,848 | 6,771 | Total Deferred Credits and Other Noncurrent Liabilities | 6,511 | 6,073 | |||||||||||||
| Commitments and Contingent Liabilities (Notes 6 and 13) | ||||||||||||||||||
| Commitments and Contingent Liabilities (Notes 7 and 14) | Commitments and Contingent Liabilities (Notes 7 and 14) | 0 | 0 | |||||||||||||||
| Equity | Equity | |||||||||||||||||
| Common stock - $0.01 par value (a) | 7 | 7 | Common stock - $0.01 par value (a) | 8 | 8 | |||||||||||||
| Additional paid-in capital | 10,305 | 9,841 | Additional paid-in capital | 12,303 | 12,270 | |||||||||||||
| Treasury stock | Treasury stock | (1,003) | — | |||||||||||||||
| Earnings reinvested | 3,871 | 3,829 | Earnings reinvested | 2,572 | 5,315 | |||||||||||||
| Accumulated other comprehensive loss | (3,422 | ) | (3,778 | ) | Accumulated other comprehensive loss | (157) | (4,220) | |||||||||||
| Total Equity | 10,761 | 9,899 | Total Equity | 13,723 | 13,373 | |||||||||||||
| Total Liabilities and Equity | $ | 41,479 | $ | 38,315 | Total Liabilities and Equity | $ | 33,223 | $ | 48,116 | |||||||||
(a)1,560,000 shares authorized; 769,890 shares issued and 735,112 shares outstanding at December 31, 2021. 1,560,000 shares authorized; 768,907 shares issued and outstanding at December 31, 2020.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED STATEMENTS OF EQUITY
PPL Corporation and Subsidiaries
(Millions of Dollars)
| PPL Shareowners | ||||||||||||||||||||||
Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Earnings reinvested | Accumulated other comprehensive loss | Total | |||||||||||||||||
| December 31, 2014 | 665,849 | $ | 7 | $ | 9,433 | $ | 6,462 | $ | (2,274 | ) | $ | 13,628 | ||||||||||
| Common stock issued | 8,008 | 249 | 249 | |||||||||||||||||||
| Stock-based compensation | 5 | 5 | ||||||||||||||||||||
| Net income | 682 | 682 | ||||||||||||||||||||
| Dividends and dividend equivalents | (1,010 | ) | (1,010 | ) | ||||||||||||||||||
| Distribution of PPL Energy Supply (Note 8) | (3,181 | ) | (24 | ) | (3,205 | ) | ||||||||||||||||
| Other comprehensive income (loss) | (430 | ) | (430 | ) | ||||||||||||||||||
| December 31, 2015 | 673,857 | $ | 7 | $ | 9,687 | $ | 2,953 | $ | (2,728 | ) | $ | 9,919 | ||||||||||
| Common stock issued | 5,874 | 185 | 185 | |||||||||||||||||||
| Stock-based compensation | (31 | ) | (31 | ) | ||||||||||||||||||
| Net income | 1,902 | 1,902 | ||||||||||||||||||||
| Dividends and dividend equivalents | (1,033 | ) | (1,033 | ) | ||||||||||||||||||
| Other comprehensive income (loss) | (1,050 | ) | (1,050 | ) | ||||||||||||||||||
| Adoption of stock-based compensation guidance cumulative effect adjustment (Note 1) | 7 | 7 | ||||||||||||||||||||
| December 31, 2016 | 679,731 | $ | 7 | $ | 9,841 | $ | 3,829 | $ | (3,778 | ) | $ | 9,899 | ||||||||||
| Common stock issued | 13,667 | 482 | 482 | |||||||||||||||||||
| Stock-based compensation | (18 | ) | (18 | ) | ||||||||||||||||||
| Net income | 1,128 | 1,128 | ||||||||||||||||||||
| Dividends and dividend equivalents | (1,086 | ) | (1,086 | ) | ||||||||||||||||||
| Other comprehensive income (loss) | 356 | 356 | ||||||||||||||||||||
| December 31, 2017 | 693,398 | $ | 7 | $ | 10,305 | $ | 3,871 | $ | (3,422 | ) | $ | 10,761 | ||||||||||
| PPL Shareowners | |||||||||||||||||||||||||||||||||||||||||||||||
| Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Treasury Stock | Earnings reinvested | Accumulated other comprehensive loss | Total | |||||||||||||||||||||||||||||||||||||||||
| December 31, 2018 | 720,323 | $ | 7 | $ | 11,021 | $ | — | $ | 4,593 | $ | (3,964) | $ | 11,657 | ||||||||||||||||||||||||||||||||||
| Common stock issued | 46,910 | 1 | 1,184 | 1,185 | |||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation | 9 | 9 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income (loss) | 1,746 | 1,746 | |||||||||||||||||||||||||||||||||||||||||||||
| Dividends and dividend equivalents (b) | (1,212) | (1,212) | |||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | (394) | (394) | |||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2019 | 767,233 | $ | 8 | $ | 12,214 | $ | — | $ | 5,127 | $ | (4,358) | $ | 12,991 | ||||||||||||||||||||||||||||||||||
| Common stock issued | 1,674 | 51 | 51 | ||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation | 5 | 5 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income (loss) | 1,469 | 1,469 | |||||||||||||||||||||||||||||||||||||||||||||
| Dividends and dividend equivalents (b) | (1,279) | (1,279) | |||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | 138 | 138 | |||||||||||||||||||||||||||||||||||||||||||||
| Adoption of financial instrument credit losses guidance cumulative effect adjustment (Note 1) | (2) | (2) | |||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2020 | 768,907 | $ | 8 | $ | 12,270 | $ | — | $ | 5,315 | $ | (4,220) | $ | 13,373 | ||||||||||||||||||||||||||||||||||
| Common stock issued | 983 | 29 | 29 | ||||||||||||||||||||||||||||||||||||||||||||
| Treasury stock | (34,778) | (1,003) | (1,003) | ||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation | 4 | 4 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income (loss) | (1,480) | (1,480) | |||||||||||||||||||||||||||||||||||||||||||||
| Dividends and dividend equivalents (b) | (1,263) | (1,263) | |||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | 4,063 | 4,063 | |||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2021 | 735,112 | $ | 8 | $ | 12,303 | $ | (1,003) | $ | 2,572 | $ | (157) | $ | 13,723 | ||||||||||||||||||||||||||||||||||
(a)Shares in thousands. Each share entitles the holder to 1 vote on any question presented at any shareowners' meeting.
(b)Dividends declared per share of common stock at December 31, 2021, 2020 and 2019 were: $1.66, $1.66 and $1.65.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
77
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CONSOLIDATED STATEMENTS OF INCOME FOR THE YEARS ENDED DECEMBER 31,
PPL Electric Utilities Corporation and Subsidiaries
(Millions of Dollars)
| 2021 | 2020 | 2019 | |||||||||||||||
| Operating Revenues | $ | 2,402 | $ | 2,331 | $ | 2,358 | |||||||||||
| Operating Expenses | |||||||||||||||||
| Operation | |||||||||||||||||
| Energy purchases | 566 | 491 | 549 | ||||||||||||||
| Other operation and maintenance | 557 | 513 | 566 | ||||||||||||||
| Depreciation | 424 | 403 | 386 | ||||||||||||||
| Taxes, other than income | 120 | 107 | 112 | ||||||||||||||
| Total Operating Expenses | 1,667 | 1,514 | 1,613 | ||||||||||||||
| Operating Income | 735 | 817 | 745 | ||||||||||||||
| Other Income (Expense) - net | 21 | 18 | 25 | ||||||||||||||
| Interest Income from Affiliate | 5 | 2 | 6 | ||||||||||||||
| Interest Expense | 162 | 173 | 170 | ||||||||||||||
| Income Before Income Taxes | 599 | 664 | 606 | ||||||||||||||
| Income Taxes | 154 | 167 | 149 | ||||||||||||||
| Net Income (a) | $ | 445 | $ | 497 | $ | 457 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Operating Revenues | $ | 2,195 | $ | 2,156 | $ | 2,124 | |||||
| Operating Expenses | |||||||||||
| Operation | |||||||||||
| Energy purchases | 507 | 535 | 657 | ||||||||
| Energy purchases from affiliate | — | — | 14 | ||||||||
| Other operation and maintenance | 571 | 599 | 607 | ||||||||
| Depreciation | 309 | 253 | 214 | ||||||||
| Taxes, other than income | 107 | 105 | 94 | ||||||||
| Total Operating Expenses | 1,494 | 1,492 | 1,586 | ||||||||
| Operating Income | 701 | 664 | 538 | ||||||||
| Other Income (Expense) - net | 11 | 17 | 8 | ||||||||
| Interest Income from Affiliate | 5 | — | — | ||||||||
| Interest Expense | 142 | 129 | 130 | ||||||||
| Income Before Income Taxes | 575 | 552 | 416 | ||||||||
| Income Taxes | 213 | 212 | 164 | ||||||||
| Net Income (a) | $ | 362 | $ | 340 | $ | 252 | |||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31,
PPL Electric Utilities Corporation and Subsidiaries
(Millions of Dollars)
| 2021 | 2020 | 2019 | |||||||||||||||
| Cash Flows from Operating Activities | |||||||||||||||||
| Net income | $ | 445 | $ | 497 | $ | 457 | |||||||||||
| Adjustments to reconcile net income to net cash provided by (used in) operating activities | |||||||||||||||||
| Depreciation | 424 | 403 | 386 | ||||||||||||||
| Amortization | 19 | 26 | 24 | ||||||||||||||
| Defined benefit plans expense (income) | (10) | (1) | — | ||||||||||||||
| Deferred income taxes and investment tax credits | 79 | 83 | 90 | ||||||||||||||
| Other | (19) | (5) | (19) | ||||||||||||||
| Change in current assets and current liabilities | |||||||||||||||||
| Accounts receivable | (9) | (47) | 33 | ||||||||||||||
| Accounts payable | (3) | 21 | 5 | ||||||||||||||
| Unbilled revenues | (8) | 13 | (14) | ||||||||||||||
| Materials and supplies | (5) | (18) | (8) | ||||||||||||||
| Prepayments | (4) | (3) | (1) | ||||||||||||||
| Regulatory assets and liabilities, net | 96 | (40) | (43) | ||||||||||||||
| Taxes payable | 14 | 4 | 1 | ||||||||||||||
| Other | (1) | (10) | (3) | ||||||||||||||
| Other operating activities | |||||||||||||||||
| Defined benefit plans - funding | (21) | (21) | (21) | ||||||||||||||
| Other assets | (12) | (28) | 15 | ||||||||||||||
| Other liabilities | (16) | 10 | 11 | ||||||||||||||
| Net cash provided by operating activities | 969 | 884 | 913 | ||||||||||||||
| Cash Flows from Investing Activities | |||||||||||||||||
| Expenditures for property, plant and equipment | (898) | (1,145) | (1,114) | ||||||||||||||
| Expenditures for intangible assets | (6) | (9) | (7) | ||||||||||||||
| Increase in notes receivable from affiliate | (499) | — | — | ||||||||||||||
| Other investing activities | 3 | 3 | 4 | ||||||||||||||
| Net cash used in investing activities | (1,400) | (1,151) | (1,117) | ||||||||||||||
| Cash Flows from Financing Activities | |||||||||||||||||
| Issuance of long-term debt | 650 | 250 | 393 | ||||||||||||||
| Retirement of long-term debt | (400) | — | (100) | ||||||||||||||
| Contributions from parent | 1,075 | 940 | 400 | ||||||||||||||
| Payment of common stock dividends to parent | (334) | (400) | (486) | ||||||||||||||
| Return of capital to parent | (574) | (745) | — | ||||||||||||||
| Other financing activities | (5) | (2) | (8) | ||||||||||||||
| Net cash provided by financing activities | 412 | 43 | 199 | ||||||||||||||
| Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash | (19) | (224) | (5) | ||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at Beginning of Period | 40 | 264 | 269 | ||||||||||||||
| Cash, Cash Equivalents and Restricted Cash at End of Period | $ | 21 | $ | 40 | $ | 264 | |||||||||||
| Supplemental Disclosures of Cash Flow Information | |||||||||||||||||
| Cash paid during the period for: | |||||||||||||||||
| Interest - net of amount capitalized | $ | 156 | $ | 158 | $ | 154 | |||||||||||
| Income taxes - net | $ | 64 | $ | 67 | $ | 32 | |||||||||||
| Significant non-cash transactions: | |||||||||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 118 | $ | 156 | $ | 180 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Cash Flows from Operating Activities | |||||||||||
| Net income | $ | 362 | $ | 340 | $ | 252 | |||||
| Adjustments to reconcile net income to net cash provided by (used in) operating activities | |||||||||||
| Depreciation | 309 | 253 | 214 | ||||||||
| Amortization | 33 | 32 | 26 | ||||||||
| Defined benefit plans - expense | 12 | 11 | 16 | ||||||||
| Deferred income taxes and investment tax credits | 258 | 221 | 220 | ||||||||
| Other | (8 | ) | (13 | ) | (12 | ) | |||||
| Change in current assets and current liabilities | |||||||||||
| Accounts receivable | (57 | ) | 16 | 50 | |||||||
| Accounts payable | 3 | 58 | (107 | ) | |||||||
| Unbilled revenues | (13 | ) | (23 | ) | 22 | ||||||
| Prepayments | 3 | 43 | (1 | ) | |||||||
| Regulatory assets and liabilities | (5 | ) | (62 | ) | 35 | ||||||
| Taxes payable | (4 | ) | (12 | ) | (108 | ) | |||||
| Other | (1 | ) | (7 | ) | 21 | ||||||
| Other operating activities | |||||||||||
| Defined benefit plans - funding | (24 | ) | — | (33 | ) | ||||||
| Other assets | 15 | 19 | (10 | ) | |||||||
| Other liabilities | (3 | ) | (4 | ) | 17 | ||||||
| Net cash provided by operating activities | 880 | 872 | 602 | ||||||||
| Cash Flows from Investing Activities | |||||||||||
| Expenditures for property, plant and equipment | (1,244 | ) | (1,125 | ) | (1,097 | ) | |||||
| Expenditures for intangible assets | (10 | ) | (9 | ) | (10 | ) | |||||
| Other investing activities | 2 | 4 | (1 | ) | |||||||
| Net cash used in investing activities | (1,252 | ) | (1,130 | ) | (1,108 | ) | |||||
| Cash Flows from Financing Activities | |||||||||||
| Issuance of long-term debt | 470 | 224 | 348 | ||||||||
| Retirement of long-term debt | — | (224 | ) | (100 | ) | ||||||
| Contributions from PPL | 575 | 220 | 275 | ||||||||
| Payment of common stock dividends to parent | (336 | ) | (288 | ) | (181 | ) | |||||
| Net increase (decrease) in short-term debt | (295 | ) | 295 | — | |||||||
| Other financing activities | (6 | ) | (3 | ) | (3 | ) | |||||
| Net cash provided by financing activities | 408 | 224 | 339 | ||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 36 | (34 | ) | (167 | ) | ||||||
| Cash and Cash Equivalents at Beginning of Period | 13 | 47 | 214 | ||||||||
| Cash and Cash Equivalents at End of Period | $ | 49 | $ | 13 | $ | 47 | |||||
| Supplemental Disclosures of Cash Flow Information | |||||||||||
| Cash paid (received) during the period for: | |||||||||||
| Interest - net of amount capitalized | $ | 128 | $ | 115 | $ | 117 | |||||
| Income taxes - net | $ | 4 | $ | (48 | ) | $ | 38 | ||||
| Significant non-cash transactions: | |||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 133 | $ | 126 | $ | 98 | |||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED BALANCE SHEETS AT DECEMBER 31,
PPL Electric Utilities Corporation and Subsidiaries
(Millions of Dollars, shares in thousands)
| 2021 | 2020 | ||||||||||
| Assets | |||||||||||
| Current Assets | |||||||||||
| Cash and cash equivalents | $ | 21 | $ | 40 | |||||||
| Accounts receivable (less reserve: 2021, $31; 2020, $41) | |||||||||||
| Customer | 305 | 311 | |||||||||
| Other | 22 | 17 | |||||||||
| Accounts receivable from affiliates | 11 | 10 | |||||||||
| Notes receivable from affiliate | 499 | — | |||||||||
| Unbilled revenues (less reserve: 2021, $2; 2020, $2) | 129 | 121 | |||||||||
| Materials and supplies | 61 | 59 | |||||||||
| Prepayments | 13 | 9 | |||||||||
| Regulatory assets | 22 | 40 | |||||||||
| Other current assets | 21 | 13 | |||||||||
| Total Current Assets | 1,104 | 620 | |||||||||
| Property, Plant and Equipment | |||||||||||
| Regulated utility plant | 14,082 | 13,514 | |||||||||
| Less: accumulated depreciation - regulated utility plant | 3,386 | 3,297 | |||||||||
| Regulated utility plant, net | 10,696 | 10,217 | |||||||||
| Construction work in progress | 581 | 592 | |||||||||
| Property, Plant and Equipment, net | 11,277 | 10,809 | |||||||||
| Other Noncurrent Assets | |||||||||||
| Regulatory assets | 488 | 541 | |||||||||
| Intangibles | 270 | 268 | |||||||||
| Pension benefit asset | 50 | 12 | |||||||||
| Other noncurrent assets (less reserve for accounts receivable: 2021, $2; 2020, $0) | 113 | 74 | |||||||||
| Total Other Noncurrent Assets | 921 | 895 | |||||||||
| Total Assets | $ | 13,302 | $ | 12,324 | |||||||
| 2017 | 2016 | ||||||
| Assets | |||||||
| Current Assets | |||||||
| Cash and cash equivalents | $ | 49 | $ | 13 | |||
| Accounts receivable (less reserve: 2017, $24; 2016, $28) | |||||||
| Customer | 279 | 272 | |||||
| Other | 71 | 21 | |||||
| Unbilled revenues | 127 | 114 | |||||
| Materials and supplies | 34 | 32 | |||||
| Prepayments | 6 | 9 | |||||
| Regulatory assets | 16 | 19 | |||||
| Other current assets | 6 | 8 | |||||
| Total Current Assets | 588 | 488 | |||||
| Property, Plant and Equipment | |||||||
| Regulated utility plant | 10,785 | 9,654 | |||||
| Less: accumulated depreciation - regulated utility plant | 2,778 | 2,714 | |||||
| Regulated utility plant, net | 8,007 | 6,940 | |||||
| Construction work in progress | 508 | 641 | |||||
| Property, Plant and Equipment, net | 8,515 | 7,581 | |||||
| Other Noncurrent Assets | |||||||
| Regulatory assets | 709 | 1,094 | |||||
| Intangibles | 259 | 251 | |||||
| Other noncurrent assets | 11 | 12 | |||||
| Total Other Noncurrent Assets | 979 | 1,357 | |||||
| Total Assets | $ | 10,082 | $ | 9,426 | |||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED BALANCE SHEETS AT DECEMBER 31,
PPL Electric Utilities Corporation and Subsidiaries
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Liabilities and Equity | Liabilities and Equity | |||||||||||||||||
| Current Liabilities | Current Liabilities | |||||||||||||||||
| Short-term debt | $ | — | $ | 295 | ||||||||||||||
| Long-term debt due within one year | — | 224 | Long-term debt due within one year | $ | 474 | $ | 400 | |||||||||||
| Accounts payable | 386 | 367 | Accounts payable | 367 | 428 | |||||||||||||
| Accounts payable to affiliates | 31 | 42 | Accounts payable to affiliates | 56 | 39 | |||||||||||||
| Taxes | 8 | 12 | Taxes | 31 | 17 | |||||||||||||
| Interest | 36 | 34 | Interest | 35 | 39 | |||||||||||||
| Regulatory liabilities | 86 | 83 | Regulatory liabilities | 153 | 68 | |||||||||||||
| Other current liabilities | 98 | 101 | Other current liabilities | 108 | 105 | |||||||||||||
| Total Current Liabilities | 645 | 1,158 | Total Current Liabilities | 1,224 | 1,096 | |||||||||||||
| Long-term Debt | 3,298 | 2,607 | Long-term Debt | 4,010 | 3,836 | |||||||||||||
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | |||||||||||||||||
| Deferred income taxes | 1,154 | 1,899 | Deferred income taxes | 1,668 | 1,559 | |||||||||||||
| Accrued pension obligations | 246 | 281 | Accrued pension obligations | 8 | 8 | |||||||||||||
| Regulatory liabilities | 668 | — | Regulatory liabilities | 559 | 578 | |||||||||||||
| Other deferred credits and noncurrent liabilities | 79 | 90 | Other deferred credits and noncurrent liabilities | 97 | 123 | |||||||||||||
| Total Deferred Credits and Other Noncurrent Liabilities | 2,147 | 2,270 | Total Deferred Credits and Other Noncurrent Liabilities | 2,332 | 2,268 | |||||||||||||
| Commitments and Contingent Liabilities (Notes 6 and 13) | ||||||||||||||||||
| Commitments and Contingent Liabilities (Notes 7 and 14) | Commitments and Contingent Liabilities (Notes 7 and 14) | 0 | 0 | |||||||||||||||
| Equity | Equity | |||||||||||||||||
| Common stock - no par value (a) | 364 | 364 | Common stock - no par value (a) | 364 | 364 | |||||||||||||
| Additional paid-in capital | 2,729 | 2,154 | Additional paid-in capital | 4,254 | 3,753 | |||||||||||||
| Earnings reinvested | 899 | 873 | Earnings reinvested | 1,118 | 1,007 | |||||||||||||
| Total Equity | 3,992 | 3,391 | Total Equity | 5,736 | 5,124 | |||||||||||||
| Total Liabilities and Equity | $ | 10,082 | $ | 9,426 | Total Liabilities and Equity | $ | 13,302 | $ | 12,324 | |||||||||
(a)170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2021 and December 31, 2020.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
CONSOLIDATED STATEMENTS OF EQUITY
PPL Electric Utilities Corporation and Subsidiaries
(Millions of Dollars)
Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Earnings reinvested | Total | ||||||||||||||
| December 31, 2014 | 66,368 | $ | 364 | $ | 1,603 | $ | 750 | $ | 2,717 | |||||||||
| Net income | 252 | 252 | ||||||||||||||||
| Capital contributions from PPL (b) | 331 | 331 | ||||||||||||||||
| Dividends declared on common stock | (181 | ) | (181 | ) | ||||||||||||||
| December 31, 2015 | 66,368 | $ | 364 | $ | 1,934 | $ | 821 | $ | 3,119 | |||||||||
| Net income | 340 | 340 | ||||||||||||||||
| Capital contributions from PPL | 220 | 220 | ||||||||||||||||
| Dividends declared on common stock | (288 | ) | (288 | ) | ||||||||||||||
| December 31, 2016 | 66,368 | $ | 364 | $ | 2,154 | $ | 873 | $ | 3,391 | |||||||||
| Net income | 362 | 362 | ||||||||||||||||
| Capital contributions from PPL | 575 | 575 | ||||||||||||||||
| Dividends declared on common stock | (336 | ) | (336 | ) | ||||||||||||||
| December 31, 2017 | 66,368 | $ | 364 | $ | 2,729 | $ | 899 | $ | 3,992 | |||||||||
| Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Earnings reinvested | Total | |||||||||||||||||||||||||
| December 31, 2018 | 66,368 | $ | 364 | $ | 3,158 | $ | 939 | $ | 4,461 | ||||||||||||||||||||
| Net income | 457 | 457 | |||||||||||||||||||||||||||
| Capital contributions from parent | 400 | 400 | |||||||||||||||||||||||||||
| Dividends declared on common stock | (486) | (486) | |||||||||||||||||||||||||||
| December 31, 2019 | 66,368 | $ | 364 | $ | 3,558 | $ | 910 | $ | 4,832 | ||||||||||||||||||||
| Net income | 497 | 497 | |||||||||||||||||||||||||||
| Capital contributions from parent | 940 | 940 | |||||||||||||||||||||||||||
| Return of capital to parent | (745) | (745) | |||||||||||||||||||||||||||
| Dividends declared on common stock | (400) | (400) | |||||||||||||||||||||||||||
| December 31, 2020 | 66,368 | $ | 364 | $ | 3,753 | $ | 1,007 | $ | 5,124 | ||||||||||||||||||||
| Net income | 445 | 445 | |||||||||||||||||||||||||||
| Capital contributions from parent | 1,075 | 1,075 | |||||||||||||||||||||||||||
| Return of capital to parent | (574) | (574) | |||||||||||||||||||||||||||
| Dividends declared on common stock | (334) | (334) | |||||||||||||||||||||||||||
| December 31, 2021 | 66,368 | $ | 364 | $ | 4,254 | $ | 1,118 | $ | 5,736 | ||||||||||||||||||||
(a)Shares in thousands. All common shares of PPL Electric stock are owned by PPL.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
83
| 2017 | 2016 | 2015 | |||||||||
| Operating Revenues | $ | 3,156 | $ | 3,141 | $ | 3,115 | |||||
| Operating Expenses | |||||||||||
| Operation | |||||||||||
| Fuel | 759 | 791 | 863 | ||||||||
| Energy purchases | 178 | 171 | 184 | ||||||||
| Other operation and maintenance | 806 | 804 | 837 | ||||||||
| Depreciation | 439 | 404 | 382 | ||||||||
| Taxes, other than income | 65 | 62 | 57 | ||||||||
| Total Operating Expenses | 2,247 | 2,232 | 2,323 | ||||||||
| Operating Income | 909 | 909 | 792 | ||||||||
| Other Income (Expense) - net | (3 | ) | (9 | ) | (8 | ) | |||||
| Interest Expense | 197 | 197 | 178 | ||||||||
| Interest Expense with Affiliate | 18 | 17 | 3 | ||||||||
| Income Before Income Taxes | 691 | 686 | 603 | ||||||||
| Income Taxes | 375 | 257 | 239 | ||||||||
| Net Income | $ | 316 | $ | 429 | $ | 364 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Net income | $ | 316 | $ | 429 | $ | 364 | |||||
| Other comprehensive income (loss): | |||||||||||
| Amounts arising during the period - gains (losses), net of tax (expense) benefit: | |||||||||||
| Defined benefit plans: | |||||||||||
| Prior service costs, net of tax of $1, $0, $2 | (2 | ) | — | (3 | ) | ||||||
| Net actuarial gain (loss), net of tax of $13, $18, $2 | (23 | ) | (27 | ) | (4 | ) | |||||
| Reclassifications to net income - (gains) losses, net of tax expense (benefit): | |||||||||||
| Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0 | 1 | (1 | ) | — | |||||||
| Defined benefit plans: | |||||||||||
| Prior service costs, net of tax of ($1), ($1), ($1) | 1 | 2 | 1 | ||||||||
| Net actuarial (gain) loss, net of tax of ($2), ($1), ($3) | 5 | 2 | 5 | ||||||||
| Total other comprehensive income (loss) | (18 | ) | (24 | ) | (1 | ) | |||||
| Comprehensive income | $ | 298 | $ | 405 | $ | 363 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Cash Flows from Operating Activities | |||||||||||
| Net income | $ | 316 | $ | 429 | $ | 364 | |||||
| Adjustments to reconcile net income to net cash provided by (used in) operating activities | |||||||||||
| Depreciation | 439 | 404 | 382 | ||||||||
| Amortization | 24 | 29 | 27 | ||||||||
| Defined benefit plans - expense | 25 | 27 | 38 | ||||||||
| Deferred income taxes and investment tax credits | 294 | 291 | 236 | ||||||||
| Other | — | — | 2 | ||||||||
| Change in current assets and current liabilities | |||||||||||
| Accounts receivable | (12 | ) | (31 | ) | 24 | ||||||
| Accounts payable | (9 | ) | 24 | (58 | ) | ||||||
| Accounts payable to affiliates | 2 | 1 | (2 | ) | |||||||
| Unbilled revenues | (33 | ) | (23 | ) | 20 | ||||||
| Fuel, materials and supplies | 45 | 2 | 6 | ||||||||
| Income tax receivable | — | 1 | 135 | ||||||||
| Taxes payable | 27 | (7 | ) | 10 | |||||||
| Accrued interest | — | — | 9 | ||||||||
| Other | 34 | (6 | ) | 23 | |||||||
| Other operating activities | |||||||||||
| Defined benefit plans - funding | (35 | ) | (85 | ) | (70 | ) | |||||
| Settlement of interest rate swaps | — | (9 | ) | (88 | ) | ||||||
| Expenditures for asset retirement obligations | (34 | ) | (26 | ) | (7 | ) | |||||
| Other assets | 8 | 2 | (7 | ) | |||||||
| Other liabilities | 8 | 4 | 19 | ||||||||
| Net cash provided by operating activities | 1,099 | 1,027 | 1,063 | ||||||||
| Cash Flows from Investing Activities | |||||||||||
| Expenditures for property, plant and equipment | (892 | ) | (791 | ) | (1,210 | ) | |||||
| Other investing activities | 4 | 1 | 7 | ||||||||
| Net cash used in investing activities | (888 | ) | (790 | ) | (1,203 | ) | |||||
| Cash Flows from Financing Activities | |||||||||||
| Net increase in notes payable with affiliates | 62 | 109 | 13 | ||||||||
| Issuance of long-term note with affiliate | — | — | 400 | ||||||||
| Issuance of long-term debt | 160 | 221 | 1,050 | ||||||||
| Retirement of long-term debt | (70 | ) | (246 | ) | (900 | ) | |||||
| Distributions to member | (402 | ) | (316 | ) | (219 | ) | |||||
| Contributions from member | — | 61 | 125 | ||||||||
| Net increase (decrease) in short-term debt | 59 | (80 | ) | (310 | ) | ||||||
Other financing activities | (3 | ) | (3 | ) | (10 | ) | |||||
| Net cash provided by (used in) financing activities | (194 | ) | (254 | ) | 149 | ||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 17 | (17 | ) | 9 | |||||||
| Cash and Cash Equivalents at Beginning of Period | 13 | 30 | 21 | ||||||||
| Cash and Cash Equivalents at End of Period | $ | 30 | $ | 13 | $ | 30 | |||||
| Supplemental Disclosures of Cash Flow Information | |||||||||||
| Cash paid (received) during the period for: | |||||||||||
| Interest - net of amount capitalized | $ | 204 | $ | 198 | $ | 163 | |||||
| Income taxes - net | $ | 48 | $ | (24 | ) | $ | (139 | ) | |||
| Significant non-cash transactions: | |||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 174 | $ | 104 | $ | 150 | |||||
| 2017 | 2016 | ||||||
| Assets | |||||||
| Current Assets | |||||||
| Cash and cash equivalents | $ | 30 | $ | 13 | |||
| Accounts receivable (less reserve: 2017, $25; 2016, $24) | |||||||
| Customer | 246 | 235 | |||||
| Other | 44 | 17 | |||||
| Unbilled revenues | 203 | 170 | |||||
| Fuel, materials and supplies | 254 | 297 | |||||
| Prepayments | 25 | 24 | |||||
| Regulatory assets | 18 | 20 | |||||
| Other current assets | 8 | 4 | |||||
| Total Current Assets | 828 | 780 | |||||
| Property, Plant and Equipment | |||||||
| Regulated utility plant | 13,187 | 12,746 | |||||
| Less: accumulated depreciation - regulated utility plant | 1,785 | 1,465 | |||||
| Regulated utility plant, net | 11,402 | 11,281 | |||||
| Construction work in progress | 627 | 317 | |||||
| Property, Plant and Equipment, net | 12,029 | 11,598 | |||||
| Other Noncurrent Assets | |||||||
| Regulatory assets | 795 | 824 | |||||
| Goodwill | 996 | 996 | |||||
| Other intangibles | 86 | 95 | |||||
| Other noncurrent assets | 68 | 78 | |||||
| Total Other Noncurrent Assets | 1,945 | 1,993 | |||||
| Total Assets | $ | 14,802 | $ | 14,371 | |||
| 2017 | 2016 | ||||||
| Liabilities and Equity | |||||||
| Current Liabilities | |||||||
| Short-term debt | $ | 244 | $ | 185 | |||
| Long-term debt due within one year | 98 | 194 | |||||
| Notes payable with affiliates | 225 | 163 | |||||
| Accounts payable | 338 | 251 | |||||
| Accounts payable to affiliates | 7 | 6 | |||||
| Customer deposits | 58 | 56 | |||||
| Taxes | 66 | 39 | |||||
| Price risk management liabilities | 4 | 4 | |||||
| Regulatory liabilities | 9 | 18 | |||||
| Interest | 32 | 32 | |||||
| Asset retirement obligations | 85 | 60 | |||||
| Other current liabilities | 161 | 119 | |||||
| Total Current Liabilities | 1,327 | 1,127 | |||||
| Long-term Debt | |||||||
| Long-term debt | 4,661 | 4,471 | |||||
| Long-term debt to affiliate | 400 | 400 | |||||
| Total Long-term Debt | 5,061 | 4,871 | |||||
| Deferred Credits and Other Noncurrent Liabilities | |||||||
| Deferred income taxes | 866 | 1,735 | |||||
| Investment tax credits | 129 | 132 | |||||
| Price risk management liabilities | 22 | 27 | |||||
| Accrued pension obligations | 365 | 350 | |||||
| Asset retirement obligations | 271 | 373 | |||||
| Regulatory liabilities | 2,036 | 899 | |||||
| Other deferred credits and noncurrent liabilities | 162 | 190 | |||||
| Total Deferred Credits and Other Noncurrent Liabilities | 3,851 | 3,706 | |||||
| Commitments and Contingent Liabilities (Notes 6 and 13) | |||||||
| Member's equity | 4,563 | 4,667 | |||||
| Total Liabilities and Equity | $ | 14,802 | $ | 14,371 | |||
Member's Equity | |||
| December 31, 2014 | $ | 4,248 | |
| Net income | 364 | ||
| Contributions from member | 125 | ||
| Distributions to member | (219 | ) | |
| Other comprehensive income (loss) | (1 | ) | |
| December 31, 2015 | $ | 4,517 | |
| Net income | $ | 429 | |
| Contributions from member | 61 | ||
| Distributions to member | (316 | ) | |
| Other comprehensive income (loss) | (24 | ) | |
| December 31, 2016 | $ | 4,667 | |
| Net income | $ | 316 | |
| Distributions to member | (402 | ) | |
| Other comprehensive income (loss) | (18 | ) | |
| December 31, 2017 | $ | 4,563 | |
(THIS PAGE LEFT BLANK INTENTIONALLY.)
84
STATEMENTS OF INCOME FOR THE YEARS ENDED DECEMBER 31,
Louisville Gas and Electric Company
(Millions of Dollars)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Operating Revenues | Operating Revenues | |||||||||||||||||||||||||||
| Retail and wholesale | $ | 1,422 | $ | 1,406 | $ | 1,407 | Retail and wholesale | $ | 1,545 | $ | 1,435 | $ | 1,473 | |||||||||||||||
| Electric revenue from affiliate | 31 | 24 | 37 | Electric revenue from affiliate | 24 | 21 | 27 | |||||||||||||||||||||
| Total Operating Revenues | 1,453 | 1,430 | 1,444 | Total Operating Revenues | 1,569 | 1,456 | 1,500 | |||||||||||||||||||||
| Operating Expenses | Operating Expenses | |||||||||||||||||||||||||||
| Operation | Operation | |||||||||||||||||||||||||||
| Fuel | 292 | 301 | 329 | Fuel | 265 | 246 | 289 | |||||||||||||||||||||
| Energy purchases | 160 | 153 | 166 | Energy purchases | 167 | 125 | 154 | |||||||||||||||||||||
| Energy purchases from affiliate | 10 | 14 | 20 | Energy purchases from affiliate | 23 | 19 | 7 | |||||||||||||||||||||
| Other operation and maintenance | 355 | 355 | 377 | Other operation and maintenance | 400 | 373 | 387 | |||||||||||||||||||||
| Depreciation | 183 | 170 | 162 | Depreciation | 279 | 259 | 231 | |||||||||||||||||||||
| Taxes, other than income | 33 | 32 | 28 | Taxes, other than income | 46 | 40 | 39 | |||||||||||||||||||||
| Total Operating Expenses | 1,033 | 1,025 | 1,082 | Total Operating Expenses | 1,180 | 1,062 | 1,107 | |||||||||||||||||||||
| Operating Income | 420 | 405 | 362 | Operating Income | 389 | 394 | 393 | |||||||||||||||||||||
| Other Income (Expense) – net | (5 | ) | (5 | ) | (6 | ) | Other Income (Expense) – net | (5) | (1) | (11) | ||||||||||||||||||
| Interest Expense | 71 | 71 | 57 | Interest Expense | 81 | 87 | 87 | |||||||||||||||||||||
| Income Before Income Taxes | 344 | 329 | 299 | Income Before Income Taxes | 303 | 306 | 295 | |||||||||||||||||||||
| Income Taxes | 131 | 126 | 114 | Income Taxes | 54 | 62 | 63 | |||||||||||||||||||||
| Net Income (a) | $ | 213 | $ | 203 | $ | 185 | Net Income (a) | $ | 249 | $ | 244 | $ | 232 | |||||||||||||||
(a)Net income equals comprehensive income.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31,
Louisville Gas and Electric Company
(Millions of Dollars)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | |||||||||||||||||||||||||||
| Net income | $ | 213 | $ | 203 | $ | 185 | Net income | $ | 249 | $ | 244 | $ | 232 | |||||||||||||||
| Adjustments to reconcile net income to net cash provided by (used in) operating activities | Adjustments to reconcile net income to net cash provided by (used in) operating activities | |||||||||||||||||||||||||||
| Depreciation | 183 | 170 | 162 | Depreciation | 279 | 259 | 231 | |||||||||||||||||||||
| Amortization | 14 | 14 | 11 | Amortization | 2 | 9 | 15 | |||||||||||||||||||||
| Defined benefit plans - expense | 7 | 8 | 12 | Defined benefit plans - expense | 1 | 3 | 3 | |||||||||||||||||||||
| Deferred income taxes and investment tax credits | 126 | 147 | 126 | Deferred income taxes and investment tax credits | 8 | 3 | 56 | |||||||||||||||||||||
| Other | 1 | — | 8 | |||||||||||||||||||||||||
| Change in current assets and current liabilities | Change in current assets and current liabilities | |||||||||||||||||||||||||||
| Accounts receivable | (7 | ) | (22 | ) | 19 | Accounts receivable | (11) | (3) | (9) | |||||||||||||||||||
| Accounts receivable from affiliates | 4 | (16 | ) | 11 | Accounts receivable from affiliates | (13) | 4 | 6 | ||||||||||||||||||||
| Accounts payable | (7 | ) | 31 | (29 | ) | Accounts payable | 32 | (18) | (10) | |||||||||||||||||||
| Accounts payable to affiliates | (4 | ) | 1 | 5 | Accounts payable to affiliates | (4) | (5) | 5 | ||||||||||||||||||||
| Unbilled revenues | (16 | ) | (8 | ) | 9 | Unbilled revenues | (1) | (3) | 1 | |||||||||||||||||||
| Fuel, materials and supplies | 12 | 8 | 3 | Fuel, materials and supplies | (17) | 4 | 5 | |||||||||||||||||||||
| Income tax receivable | — | 4 | 70 | |||||||||||||||||||||||||
| Regulatory assets and liabilities, net | Regulatory assets and liabilities, net | (23) | — | (19) | ||||||||||||||||||||||||
| Taxes payable | (15 | ) | 20 | 1 | Taxes payable | 2 | (1) | 7 | ||||||||||||||||||||
| Accrued interest | — | — | 5 | |||||||||||||||||||||||||
| Other | 11 | (7 | ) | 17 | Other | (18) | (3) | (5) | ||||||||||||||||||||
| Other operating activities | Other operating activities | |||||||||||||||||||||||||||
| Defined benefit plans - funding | (4 | ) | (46 | ) | (26 | ) | Defined benefit plans - funding | (3) | (11) | (6) | ||||||||||||||||||
| Settlement of interest rate swaps | — | (9 | ) | (44 | ) | |||||||||||||||||||||||
| Expenditures for asset retirement obligations | (15 | ) | (18 | ) | (6 | ) | Expenditures for asset retirement obligations | (27) | (20) | (30) | ||||||||||||||||||
| Other assets | 5 | — | 11 | Other assets | 2 | (2) | (1) | |||||||||||||||||||||
| Other liabilities | 4 | 2 | 4 | Other liabilities | — | 23 | 11 | |||||||||||||||||||||
| Net cash provided by operating activities | 512 | 482 | 554 | Net cash provided by operating activities | 458 | 483 | 492 | |||||||||||||||||||||
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | |||||||||||||||||||||||||||
| Expenditures for property, plant and equipment | (458 | ) | (439 | ) | (689 | ) | Expenditures for property, plant and equipment | (466) | (456) | (482) | ||||||||||||||||||
| Net cash used in investing activities | (458 | ) | (439 | ) | (689 | ) | Net cash used in investing activities | (466) | (456) | (482) | ||||||||||||||||||
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | |||||||||||||||||||||||||||
| Net increase in notes payable with affiliates | Net increase in notes payable with affiliates | 324 | — | — | ||||||||||||||||||||||||
| Issuance of long-term debt | 160 | 125 | 550 | Issuance of long-term debt | — | — | 399 | |||||||||||||||||||||
| Retirement of long-term debt | (70 | ) | (150 | ) | (250 | ) | Retirement of long-term debt | — | — | (200) | ||||||||||||||||||
| Acquisition of outstanding bonds | Acquisition of outstanding bonds | — | — | (40) | ||||||||||||||||||||||||
| Remarketing of reacquired bonds | Remarketing of reacquired bonds | — | — | 40 | ||||||||||||||||||||||||
| Payment of common stock dividends to parent | (192 | ) | (128 | ) | (119 | ) | Payment of common stock dividends to parent | (192) | (161) | (182) | ||||||||||||||||||
| Contributions from parent | 30 | 71 | 90 | Contributions from parent | 74 | 103 | 25 | |||||||||||||||||||||
| Net increase (decrease) in short-term debt | 30 | 27 | (122 | ) | ||||||||||||||||||||||||
| Issuance of commercial paper | Issuance of commercial paper | — | 41 | — | ||||||||||||||||||||||||
| Retirement of commercial paper | Retirement of commercial paper | (41) | — | — | ||||||||||||||||||||||||
| Net decrease in short-term debt | Net decrease in short-term debt | (152) | (17) | (41) | ||||||||||||||||||||||||
| Other financing activities | (2 | ) | (2 | ) | (5 | ) | Other financing activities | (3) | (1) | (6) | ||||||||||||||||||
| Net cash provided by (used in) financing activities | (44 | ) | (57 | ) | 144 | Net cash provided by (used in) financing activities | 10 | (35) | (5) | |||||||||||||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 10 | (14 | ) | 9 | Net Increase (Decrease) in Cash and Cash Equivalents | 2 | (8) | 5 | ||||||||||||||||||||
| Cash and Cash Equivalents at Beginning of Period | 5 | 19 | 10 | Cash and Cash Equivalents at Beginning of Period | 7 | 15 | 10 | |||||||||||||||||||||
| Cash and Cash Equivalents at End of Period | $ | 15 | $ | 5 | $ | 19 | Cash and Cash Equivalents at End of Period | $ | 9 | $ | 7 | $ | 15 | |||||||||||||||
| Supplemental Disclosures of Cash Flow Information | Supplemental Disclosures of Cash Flow Information | |||||||||||||||||||||||||||
| Cash paid (received) during the period for: | ||||||||||||||||||||||||||||
| Cash paid during the period for: | Cash paid during the period for: | |||||||||||||||||||||||||||
| Interest - net of amount capitalized | $ | 65 | $ | 65 | $ | 48 | Interest - net of amount capitalized | $ | 77 | $ | 82 | $ | 77 | |||||||||||||||
| Income taxes - net | $ | 22 | $ | (43 | ) | $ | (81 | ) | Income taxes - net | $ | 52 | $ | 63 | $ | 2 | |||||||||||||
| Significant non-cash transactions: | Significant non-cash transactions: | |||||||||||||||||||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 92 | $ | 56 | $ | 97 | Accrued expenditures for property, plant and equipment at December 31, | $ | 60 | $ | 60 | $ | 59 | |||||||||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
86
BALANCE SHEETS AT DECEMBER 31,
Louisville Gas and Electric Company
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Assets | Assets | |||||||||||||||||
| Current Assets | Current Assets | |||||||||||||||||
| Cash and cash equivalents | $ | 15 | $ | 5 | Cash and cash equivalents | $ | 9 | $ | 7 | |||||||||
| Accounts receivable (less reserve: 2017, $1; 2016, $2) | ||||||||||||||||||
| Accounts receivable (less reserve: 2021, $3; 2020, $2) | Accounts receivable (less reserve: 2021, $3; 2020, $2) | |||||||||||||||||
| Customer | 116 | 109 | Customer | 130 | 127 | |||||||||||||
| Other | 13 | 11 | Other | 25 | 35 | |||||||||||||
| Unbilled revenues | 91 | 75 | ||||||||||||||||
| Unbilled revenues (less reserve: 2021, $0; 2020, $1) | Unbilled revenues (less reserve: 2021, $0; 2020, $1) | 80 | 79 | |||||||||||||||
| Accounts receivable from affiliates | 24 | 28 | Accounts receivable from affiliates | 31 | 16 | |||||||||||||
| Fuel, materials and supplies | 131 | 143 | Fuel, materials and supplies | 137 | 119 | |||||||||||||
| Prepayments | 11 | 12 | Prepayments | 14 | 14 | |||||||||||||
| Regulatory assets | 12 | 9 | Regulatory assets | 33 | 23 | |||||||||||||
| Other current assets | 3 | 1 | Other current assets | 2 | 1 | |||||||||||||
| Total Current Assets | 416 | 393 | Total Current Assets | 461 | 421 | |||||||||||||
| Property, Plant and Equipment | Property, Plant and Equipment | |||||||||||||||||
| Regulated utility plant | 5,587 | 5,357 | Regulated utility plant | 7,192 | 6,735 | |||||||||||||
| Less: accumulated depreciation - regulated utility plant | 614 | 498 | Less: accumulated depreciation - regulated utility plant | 1,172 | 1,020 | |||||||||||||
| Regulated utility plant, net | 4,973 | 4,859 | Regulated utility plant, net | 6,020 | 5,715 | |||||||||||||
| Construction work in progress | 305 | 133 | Construction work in progress | 242 | 320 | |||||||||||||
| Property, Plant and Equipment, net | 5,278 | 4,992 | Property, Plant and Equipment, net | 6,262 | 6,035 | |||||||||||||
| Other Noncurrent Assets | Other Noncurrent Assets | |||||||||||||||||
| Regulatory assets | 411 | 450 | Regulatory assets | 337 | 351 | |||||||||||||
| Goodwill | 389 | 389 | Goodwill | 389 | 389 | |||||||||||||
| Other intangibles | 53 | 59 | Other intangibles | 30 | 35 | |||||||||||||
| Other noncurrent assets | 12 | 17 | Other noncurrent assets | 113 | 114 | |||||||||||||
| Total Other Noncurrent Assets | 865 | 915 | Total Other Noncurrent Assets | 869 | 889 | |||||||||||||
| Total Assets | $ | 6,559 | $ | 6,300 | Total Assets | $ | 7,592 | $ | 7,345 | |||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
87
BALANCE SHEETS AT DECEMBER 31,
Louisville Gas and Electric Company
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Liabilities and Equity | Liabilities and Equity | |||||||||||||||||
| Current Liabilities | Current Liabilities | |||||||||||||||||
| Short-term debt | $ | 199 | $ | 169 | Short-term debt | $ | 69 | $ | 262 | |||||||||
| Notes payable with affiliates | Notes payable with affiliates | 324 | — | |||||||||||||||
| Long-term debt due within one year | 98 | 194 | Long-term debt due within one year | — | 292 | |||||||||||||
| Accounts payable | 179 | 148 | Accounts payable | 163 | 153 | |||||||||||||
| Accounts payable to affiliates | 23 | 26 | Accounts payable to affiliates | 31 | 31 | |||||||||||||
| Customer deposits | 27 | 27 | Customer deposits | 32 | 32 | |||||||||||||
| Taxes | 25 | 40 | Taxes | 34 | 32 | |||||||||||||
| Price risk management liabilities | 4 | 4 | Price risk management liabilities | 1 | 2 | |||||||||||||
| Regulatory liabilities | 3 | 5 | Regulatory liabilities | 21 | — | |||||||||||||
| Interest | 11 | 11 | Interest | 15 | 15 | |||||||||||||
| Asset retirement obligations | 24 | 41 | Asset retirement obligations | 10 | 10 | |||||||||||||
| Other current liabilities | 52 | 36 | Other current liabilities | 37 | 50 | |||||||||||||
| Total Current Liabilities | 645 | 701 | Total Current Liabilities | 737 | 879 | |||||||||||||
| Long-term Debt | 1,611 | 1,423 | Long-term Debt | 2,006 | 1,715 | |||||||||||||
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | |||||||||||||||||
| Deferred income taxes | 572 | 974 | Deferred income taxes | 751 | 716 | |||||||||||||
| Investment tax credits | 35 | 36 | Investment tax credits | 32 | 33 | |||||||||||||
| Price risk management liabilities | 22 | 27 | Price risk management liabilities | 17 | 21 | |||||||||||||
| Accrued pension obligations | 45 | 53 | ||||||||||||||||
| Asset retirement obligations | 97 | 104 | Asset retirement obligations | 74 | 57 | |||||||||||||
| Regulatory liabilities | 919 | 419 | Regulatory liabilities | 818 | 882 | |||||||||||||
| Other deferred credits and noncurrent liabilities | 86 | 87 | Other deferred credits and noncurrent liabilities | 78 | 94 | |||||||||||||
| Total Deferred Credits and Other Noncurrent Liabilities | 1,776 | 1,700 | Total Deferred Credits and Other Noncurrent Liabilities | 1,770 | 1,803 | |||||||||||||
| Commitments and Contingent Liabilities (Notes 6 and 13) | ||||||||||||||||||
| Commitments and Contingent Liabilities (Notes 7 and 14) | Commitments and Contingent Liabilities (Notes 7 and 14) | 0 | 0 | |||||||||||||||
| Stockholder's Equity | ||||||||||||||||||
| Equity | Equity | |||||||||||||||||
| Common stock - no par value (a) | 424 | 424 | Common stock - no par value (a) | 424 | 424 | |||||||||||||
| Additional paid-in capital | 1,712 | 1,682 | Additional paid-in capital | 1,997 | 1,923 | |||||||||||||
| Earnings reinvested | 391 | 370 | Earnings reinvested | 658 | 601 | |||||||||||||
| Total Equity | 2,527 | 2,476 | Total Equity | 3,079 | 2,948 | |||||||||||||
| Total Liabilities and Equity | $ | 6,559 | $ | 6,300 | Total Liabilities and Equity | $ | 7,592 | $ | 7,345 | |||||||||
(a)75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2021 and December 31, 2020.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
STATEMENTS OF EQUITY
Louisville Gas and Electric Company
(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 | |||||||||||||||||||||||||||||||||||||||||||
| December 31, 2014 | 21,294 | $ | 424 | $ | 1,521 | $ | 229 | $ | 2,174 | ||||||||||||||||||||||||||||||||||||||
| December 31, 2018 | December 31, 2018 | 21,294 | $ | 424 | $ | 1,795 | $ | 468 | $ | 2,687 | |||||||||||||||||||||||||||||||||||||
| Net income | 185 | 185 | Net income | 232 | 232 | ||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | 90 | 90 | Capital contributions from LKE | 25 | 25 | ||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (119 | ) | (119 | ) | Cash dividends declared on common stock | (182) | (182) | ||||||||||||||||||||||||||||||||||||||||
| December 31, 2015 | 21,294 | $ | 424 | $ | 1,611 | $ | 295 | $ | 2,330 | ||||||||||||||||||||||||||||||||||||||
| December 31, 2019 | December 31, 2019 | 21,294 | $ | 424 | $ | 1,820 | $ | 518 | $ | 2,762 | |||||||||||||||||||||||||||||||||||||
| Net income | 203 | 203 | Net income | 244 | 244 | ||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | 71 | 71 | Capital contributions from LKE | 103 | 103 | ||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (128 | ) | (128 | ) | Cash dividends declared on common stock | (161) | (161) | ||||||||||||||||||||||||||||||||||||||||
| December 31, 2016 | 21,294 | $ | 424 | $ | 1,682 | $ | 370 | $ | 2,476 | ||||||||||||||||||||||||||||||||||||||
| December 31, 2020 | December 31, 2020 | 21,294 | $ | 424 | $ | 1,923 | $ | 601 | $ | 2,948 | |||||||||||||||||||||||||||||||||||||
| Net income | 213 | 213 | Net income | 249 | 249 | ||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | 30 | 30 | Capital contributions from LKE | 74 | 74 | ||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (192 | ) | (192 | ) | Cash dividends declared on common stock | (192) | (192) | ||||||||||||||||||||||||||||||||||||||||
| December 31, 2017 | 21,294 | $ | 424 | $ | 1,712 | $ | 391 | $ | 2,527 | ||||||||||||||||||||||||||||||||||||||
| December 31, 2021 | December 31, 2021 | 21,294 | $ | 424 | $ | 1,997 | $ | 658 | $ | 3,079 | |||||||||||||||||||||||||||||||||||||
(a) Shares in thousands. All common shares of LG&E stock are owned by LKE.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
(THIS PAGE LEFT BLANK INTENTIONALLY.)
STATEMENTS OF INCOME FOR THE YEARS ENDED DECEMBER 31,
Kentucky Utilities Company
(Millions of Dollars)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Operating Revenues | Operating Revenues | |||||||||||||||||||||||||||
| Retail and wholesale | $ | 1,734 | $ | 1,735 | $ | 1,708 | Retail and wholesale | $ | 1,803 | $ | 1,671 | $ | 1,733 | |||||||||||||||
| Electric revenue from affiliate | 10 | 14 | 20 | Electric revenue from affiliate | 23 | 19 | 7 | |||||||||||||||||||||
| Total Operating Revenues | 1,744 | 1,749 | 1,728 | Total Operating Revenues | 1,826 | 1,690 | 1,740 | |||||||||||||||||||||
| Operating Expenses | Operating Expenses | |||||||||||||||||||||||||||
| Operation | Operation | |||||||||||||||||||||||||||
| Fuel | 467 | 490 | 534 | Fuel | 445 | 386 | 420 | |||||||||||||||||||||
| Energy purchases | 18 | 18 | 18 | Energy purchases | 19 | 18 | 20 | |||||||||||||||||||||
| Energy purchases from affiliate | 31 | 24 | 37 | Energy purchases from affiliate | 24 | 21 | 27 | |||||||||||||||||||||
| Other operation and maintenance | 424 | 424 | 435 | Other operation and maintenance | 463 | 429 | 438 | |||||||||||||||||||||
| Depreciation | 255 | 234 | 220 | Depreciation | 366 | 346 | 315 | |||||||||||||||||||||
| Taxes, other than income | 32 | 30 | 29 | Taxes, other than income | 41 | 37 | 35 | |||||||||||||||||||||
| Total Operating Expenses | 1,227 | 1,220 | 1,273 | Total Operating Expenses | 1,358 | 1,237 | 1,255 | |||||||||||||||||||||
| Operating Income | 517 | 529 | 455 | Operating Income | 468 | 453 | 485 | |||||||||||||||||||||
| Other Income (Expense) – net | (3 | ) | (5 | ) | 1 | Other Income (Expense) – net | 4 | 3 | (4) | |||||||||||||||||||
| Interest Expense | 96 | 96 | 82 | Interest Expense | 109 | 113 | 109 | |||||||||||||||||||||
| Income Before Income Taxes | 418 | 428 | 374 | Income Before Income Taxes | 363 | 343 | 372 | |||||||||||||||||||||
| Income Taxes | 159 | 163 | 140 | Income Taxes | 67 | 63 | 79 | |||||||||||||||||||||
| Net Income (a) | $ | 259 | $ | 265 | $ | 234 | Net Income (a) | $ | 296 | $ | 280 | $ | 293 | |||||||||||||||
(a)Net income equals comprehensive income.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31,
Kentucky Utilities Company
(Millions of Dollars)
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Cash Flows from Operating Activities | Cash Flows from Operating Activities | |||||||||||||||||||||||||||
| Net income | $ | 259 | $ | 265 | $ | 234 | Net income | $ | 296 | $ | 280 | $ | 293 | |||||||||||||||
| Adjustments to reconcile net income to net cash provided by (used in) operating activities | Adjustments to reconcile net income to net cash provided by (used in) operating activities | |||||||||||||||||||||||||||
| Depreciation | 255 | 234 | 220 | Depreciation | 366 | 346 | 315 | |||||||||||||||||||||
| Amortization | 9 | 14 | 13 | Amortization | 12 | 8 | 10 | |||||||||||||||||||||
| Defined benefit plans - expense | 4 | 5 | 10 | |||||||||||||||||||||||||
| Defined benefit plans - expense (credit) | Defined benefit plans - expense (credit) | (3) | — | (1) | ||||||||||||||||||||||||
| Deferred income taxes and investment tax credits | 152 | 126 | 160 | Deferred income taxes and investment tax credits | 1 | 20 | 39 | |||||||||||||||||||||
| Other | — | (1 | ) | (5 | ) | Other | (3) | (1) | (3) | |||||||||||||||||||
| Change in current assets and current liabilities | Change in current assets and current liabilities | |||||||||||||||||||||||||||
| Accounts receivable | (5 | ) | (8 | ) | 5 | Accounts receivable | 6 | (13) | (3) | |||||||||||||||||||
| Accounts receivable from affiliates | — | 1 | (1 | ) | Accounts receivable from affiliates | 1 | (1) | — | ||||||||||||||||||||
| Accounts payable | — | (10 | ) | (32 | ) | Accounts payable | (12) | 9 | (15) | |||||||||||||||||||
| Accounts payable to affiliates | (6 | ) | 15 | (10 | ) | Accounts payable to affiliates | 15 | (16) | (2) | |||||||||||||||||||
| Unbilled revenues | (17 | ) | (15 | ) | 11 | Unbilled revenues | 6 | (9) | 4 | |||||||||||||||||||
| Fuel, materials and supplies | 32 | (6 | ) | 3 | Fuel, materials and supplies | 1 | 6 | (6) | ||||||||||||||||||||
| Income tax receivable | — | — | 59 | |||||||||||||||||||||||||
| Regulatory assets and liabilities, net | Regulatory assets and liabilities, net | (22) | (26) | (26) | ||||||||||||||||||||||||
| Taxes payable | (26 | ) | 25 | 6 | Taxes payable | (10) | 2 | 2 | ||||||||||||||||||||
| Accrued interest | — | — | 5 | |||||||||||||||||||||||||
| Other | 7 | (3 | ) | 4 | Other | (18) | (5) | (6) | ||||||||||||||||||||
| Other operating activities | Other operating activities | |||||||||||||||||||||||||||
| Defined benefit plans - funding | (23 | ) | (20 | ) | (21 | ) | Defined benefit plans - funding | (1) | (3) | (3) | ||||||||||||||||||
| Settlement of interest rate swaps | — | — | (44 | ) | ||||||||||||||||||||||||
| Expenditures for asset retirement obligations | (19 | ) | (8 | ) | (1 | ) | Expenditures for asset retirement obligations | (36) | (64) | (59) | ||||||||||||||||||
| Other assets | 3 | (6 | ) | (11 | ) | Other assets | 9 | (2) | (2) | |||||||||||||||||||
| Other liabilities | 9 | (2 | ) | 3 | Other liabilities | — | 12 | 16 | ||||||||||||||||||||
| Net cash provided by operating activities | 634 | 606 | 608 | Net cash provided by operating activities | 608 | 543 | 553 | |||||||||||||||||||||
| Cash Flows from Investing Activities | Cash Flows from Investing Activities | |||||||||||||||||||||||||||
| Expenditures for property, plant and equipment | (432 | ) | (350 | ) | (519 | ) | Expenditures for property, plant and equipment | (560) | (510) | (610) | ||||||||||||||||||
| Other investing activities | 4 | 1 | 7 | Other investing activities | 4 | 3 | — | |||||||||||||||||||||
| Net cash used in investing activities | (428 | ) | (349 | ) | (512 | ) | Net cash used in investing activities | (556) | (507) | (610) | ||||||||||||||||||
| Cash Flows from Financing Activities | Cash Flows from Financing Activities | |||||||||||||||||||||||||||
| Net increase in notes payable with affiliates | Net increase in notes payable with affiliates | 294 | — | — | ||||||||||||||||||||||||
| Issuance of long-term debt | — | 96 | 500 | Issuance of long-term debt | — | 498 | 306 | |||||||||||||||||||||
| Retirement of long-term debt | — | (96 | ) | (250 | ) | Retirement of long-term debt | — | (500) | — | |||||||||||||||||||
| Payment of common stock dividends to parent | (226 | ) | (248 | ) | (153 | ) | Payment of common stock dividends to parent | (250) | (200) | (229) | ||||||||||||||||||
| Contributions from parent | — | 20 | — | Contributions from parent | 100 | 128 | 68 | |||||||||||||||||||||
| Issuance of commercial paper | Issuance of commercial paper | — | 32 | — | ||||||||||||||||||||||||
| Retirement of commercial paper | Retirement of commercial paper | (32) | — | — | ||||||||||||||||||||||||
| Net increase (decrease) in short-term debt | 29 | (32 | ) | (188 | ) | Net increase (decrease) in short-term debt | (171) | 21 | (85) | |||||||||||||||||||
| Other financing activities | (1 | ) | (1 | ) | (5 | ) | Other financing activities | (2) | (5) | (5) | ||||||||||||||||||
| Net cash used in financing activities | (198 | ) | (261 | ) | (96 | ) | ||||||||||||||||||||||
| Net cash provided by (used in) financing activities | Net cash provided by (used in) financing activities | (61) | (26) | 55 | ||||||||||||||||||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | 8 | (4 | ) | — | Net Increase (Decrease) in Cash and Cash Equivalents | (9) | 10 | (2) | ||||||||||||||||||||
| Cash and Cash Equivalents at Beginning of Period | 7 | 11 | 11 | Cash and Cash Equivalents at Beginning of Period | 22 | 12 | 14 | |||||||||||||||||||||
| Cash and Cash Equivalents at End of Period | $ | 15 | $ | 7 | $ | 11 | Cash and Cash Equivalents at End of Period | $ | 13 | $ | 22 | $ | 12 | |||||||||||||||
| Supplemental Disclosures of Cash Flow Information | Supplemental Disclosures of Cash Flow Information | |||||||||||||||||||||||||||
| Cash paid (received) during the period for: | ||||||||||||||||||||||||||||
| Cash paid during the period for: | Cash paid during the period for: | |||||||||||||||||||||||||||
| Interest - net of amount capitalized | $ | 92 | $ | 89 | $ | 75 | Interest - net of amount capitalized | $ | 105 | $ | 109 | $ | 101 | |||||||||||||||
| Income taxes - net | $ | 34 | $ | 13 | $ | (84 | ) | Income taxes - net | $ | 72 | $ | 44 | $ | 39 | ||||||||||||||
| Significant non-cash transactions: | Significant non-cash transactions: | |||||||||||||||||||||||||||
| Accrued expenditures for property, plant and equipment at December 31, | $ | 82 | $ | 47 | $ | 53 | Accrued expenditures for property, plant and equipment at December 31, | $ | 67 | $ | 40 | $ | 54 | |||||||||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
92
BALANCE SHEETS AT DECEMBER 31,
Kentucky Utilities Company
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Assets | Assets | |||||||||||||||||
| Current Assets | Current Assets | |||||||||||||||||
| Cash and cash equivalents | $ | 15 | $ | 7 | Cash and cash equivalents | $ | 13 | $ | 22 | |||||||||
| Accounts receivable (less reserve: 2017, $1; 2016, $2) | ||||||||||||||||||
| Accounts receivable (less reserve: 2021, $3; 2020, $1) | Accounts receivable (less reserve: 2021, $3; 2020, $1) | |||||||||||||||||
| Customer | 130 | 126 | Customer | 144 | 156 | |||||||||||||
| Other | 30 | 5 | Other | 12 | 30 | |||||||||||||
| Unbilled revenues | 112 | 95 | ||||||||||||||||
| Unbilled revenues (less reserve: 2021, $0; 2020, $1) | Unbilled revenues (less reserve: 2021, $0; 2020, $1) | 91 | 97 | |||||||||||||||
| Accounts receivable from affiliates | Accounts receivable from affiliates | — | 1 | |||||||||||||||
| Fuel, materials and supplies | 123 | 154 | Fuel, materials and supplies | 124 | 123 | |||||||||||||
| Prepayments | 14 | 12 | Prepayments | 15 | 15 | |||||||||||||
| Regulatory assets | 6 | 11 | Regulatory assets | 9 | 36 | |||||||||||||
| Other current assets | 5 | 3 | Other current assets | 2 | 1 | |||||||||||||
| Total Current Assets | 435 | 413 | Total Current Assets | 410 | 481 | |||||||||||||
| Property, Plant and Equipment | Property, Plant and Equipment | |||||||||||||||||
| Regulated utility plant | 7,592 | 7,382 | Regulated utility plant | 9,219 | 8,808 | |||||||||||||
| Less: accumulated depreciation - regulated utility plant | 1,170 | 965 | Less: accumulated depreciation - regulated utility plant | 1,929 | 1,690 | |||||||||||||
| Regulated utility plant, net | 6,422 | 6,417 | Regulated utility plant, net | 7,290 | 7,118 | |||||||||||||
| Construction work in progress | 321 | 181 | Construction work in progress | 378 | 321 | |||||||||||||
| Property, Plant and Equipment, net | 6,743 | 6,598 | Property, Plant and Equipment, net | 7,668 | 7,439 | |||||||||||||
| Other Noncurrent Assets | Other Noncurrent Assets | |||||||||||||||||
| Regulatory assets | 384 | 374 | Regulatory assets | 411 | 370 | |||||||||||||
| Goodwill | 607 | 607 | Goodwill | 607 | 607 | |||||||||||||
| Other intangibles | 33 | 36 | Other intangibles | 23 | 26 | |||||||||||||
| Other noncurrent assets | 52 | 57 | Other noncurrent assets | 153 | 149 | |||||||||||||
| Total Other Noncurrent Assets | 1,076 | 1,074 | Total Other Noncurrent Assets | 1,194 | 1,152 | |||||||||||||
| Total Assets | $ | 8,254 | $ | 8,085 | Total Assets | $ | 9,272 | $ | 9,072 | |||||||||
The accompanying Notes to Financial Statements are an integral part of the financial statements.
BALANCE SHEETS AT DECEMBER 31,
Kentucky Utilities Company
(Millions of Dollars, shares in thousands)
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Liabilities and Equity | Liabilities and Equity | |||||||||||||||||
| Current Liabilities | Current Liabilities | |||||||||||||||||
| Short-term debt | $ | 45 | $ | 16 | Short-term debt | $ | — | $ | 203 | |||||||||
| Notes payable with affiliates | Notes payable with affiliates | 294 | — | |||||||||||||||
| Long-term debt due within one year | Long-term debt due within one year | — | 132 | |||||||||||||||
| Accounts payable | 137 | 78 | Accounts payable | 108 | 121 | |||||||||||||
| Accounts payable to affiliates | 53 | 56 | Accounts payable to affiliates | 64 | 43 | |||||||||||||
| Customer deposits | 31 | 29 | Customer deposits | 32 | 32 | |||||||||||||
| Taxes | 19 | 45 | Taxes | 19 | 29 | |||||||||||||
| Regulatory liabilities | 6 | 13 | Regulatory liabilities | 8 | 11 | |||||||||||||
| Interest | 16 | 16 | Interest | 18 | 19 | |||||||||||||
| Asset retirement obligations | 61 | 19 | Asset retirement obligations | 22 | 40 | |||||||||||||
| Other current liabilities | 46 | 36 | Other current liabilities | 47 | 59 | |||||||||||||
| Total Current Liabilities | 414 | 308 | Total Current Liabilities | 612 | 689 | |||||||||||||
| Long-term Debt | 2,328 | 2,327 | Long-term Debt | 2,618 | 2,486 | |||||||||||||
| Deferred Credits and Other Noncurrent Liabilities | Deferred Credits and Other Noncurrent Liabilities | |||||||||||||||||
| Deferred income taxes | 691 | 1,170 | Deferred income taxes | 865 | 835 | |||||||||||||
| Investment tax credits | 94 | 96 | Investment tax credits | 87 | 88 | |||||||||||||
| Accrued pension obligations | 36 | 62 | ||||||||||||||||
| Asset retirement obligations | 174 | 269 | Asset retirement obligations | 83 | 75 | |||||||||||||
| Regulatory liabilities | 1,117 | 480 | Regulatory liabilities | 1,045 | 1,070 | |||||||||||||
| Other deferred credits and noncurrent liabilities | 43 | 50 | Other deferred credits and noncurrent liabilities | 34 | 47 | |||||||||||||
| Total Deferred Credits and Other Noncurrent Liabilities | 2,155 | 2,127 | Total Deferred Credits and Other Noncurrent Liabilities | 2,114 | 2,115 | |||||||||||||
| Commitments and Contingent Liabilities (Notes 6 and 13) | ||||||||||||||||||
| Commitments and Contingent Liabilities (Notes 7 and 14) | Commitments and Contingent Liabilities (Notes 7 and 14) | 0 | 0 | |||||||||||||||
| Stockholder's Equity | ||||||||||||||||||
| Equity | Equity | |||||||||||||||||
| Common stock - no par value (a) | 308 | 308 | Common stock - no par value (a) | 308 | 308 | |||||||||||||
| Additional paid-in capital | 2,616 | 2,616 | Additional paid-in capital | 2,957 | 2,857 | |||||||||||||
| Accumulated other comprehensive loss | — | (1 | ) | |||||||||||||||
| Earnings reinvested | 433 | 400 | Earnings reinvested | 663 | 617 | |||||||||||||
| Total Equity | 3,357 | 3,323 | Total Equity | 3,928 | 3,782 | |||||||||||||
| Total Liabilities and Equity | $ | 8,254 | $ | 8,085 | Total Liabilities and Equity | $ | 9,272 | $ | 9,072 | |||||||||
(a) 80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2021 and December 31, 2020.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
STATEMENTS OF EQUITY
Kentucky Utilities Company
(Millions of Dollars)
| Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Earnings reinvested | Accumulated other comprehensive income (loss) | Total | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2018 | December 31, 2018 | 37,818 | $ | 308 | $ | 2,661 | $ | 473 | $ | — | $ | 3,442 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income | Net income | 293 | 293 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | Capital contributions from LKE | 68 | 68 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | Cash dividends declared on common stock | (229) | (229) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock shares outstanding (a) | Common stock | Additional paid-in capital | Earnings reinvested | Accumulated other comprehensive income (loss) | Total | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2014 | 37,818 | $ | 308 | $ | 2,596 | $ | 302 | $ | — | $ | 3,206 | ||||||||||||||||||||||||||||||||||||||||||||||
| Net income | 234 | 234 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (153 | ) | (153 | ) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2015 | 37,818 | $ | 308 | $ | 2,596 | $ | 383 | $ | — | $ | 3,287 | ||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2019 | December 31, 2019 | 37,818 | $ | 308 | $ | 2,729 | $ | 537 | $ | — | $ | 3,574 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income | 265 | 265 | Net income | 280 | 280 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | 20 | 20 | Capital contributions from LKE | 128 | 128 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (248 | ) | (248 | ) | Cash dividends declared on common stock | (200) | (200) | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | (1 | ) | (1 | ) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2016 | 37,818 | $ | 308 | $ | 2,616 | $ | 400 | $ | (1 | ) | $ | 3,323 | |||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2020 | December 31, 2020 | 37,818 | $ | 308 | $ | 2,857 | $ | 617 | $ | — | $ | 3,782 | |||||||||||||||||||||||||||||||||||||||||||||
| Net income | 259 | 259 | Net income | 296 | 296 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Capital contributions from LKE | Capital contributions from LKE | 100 | 100 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash dividends declared on common stock | (226 | ) | (226 | ) | Cash dividends declared on common stock | (250) | (250) | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | 1 | 1 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2017 | 37,818 | $ | 308 | $ | 2,616 | $ | 433 | $ | — | $ | 3,357 | ||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2021 | December 31, 2021 | 37,818 | $ | 308 | $ | 2,957 | $ | 663 | $ | — | $ | 3,928 | |||||||||||||||||||||||||||||||||||||||||||||
(a)Shares in thousands. All common shares of KU stock are owned by LKE.
The accompanying Notes to Financial Statements are an integral part of the financial statements.
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COMBINED NOTES TO FINANCIAL STATEMENTS
The notes to the consolidated financial statements that follow are a combined presentation. The following list indicates the Registrants to which the footnotes apply:
| Registrant | ||||||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | |||||||||||||||||||||||
| 1. Summary of Significant Accounting Policies | x | x | x | x | ||||||||||||||||||||||
| 2. Segment and Related Information | x | x | x | x | ||||||||||||||||||||||
| 3. Revenue from Contracts with Customers | x | x | x | x | ||||||||||||||||||||||
| 4. Preferred Securities | x | x | x | x | ||||||||||||||||||||||
| 5. Earnings Per Share | x | |||||||||||||||||||||||||
| 6. Income and Other Taxes | x | x | x | x | ||||||||||||||||||||||
| 7. Utility Rate Regulation | x | x | x | x | ||||||||||||||||||||||
| 8. Financing Activities | x | x | x | x | ||||||||||||||||||||||
| 9. Acquisitions, Development and Divestitures | x | |||||||||||||||||||||||||
| 10. Leases | x | x | x | x | ||||||||||||||||||||||
| 11. Stock-Based Compensation | x | x | ||||||||||||||||||||||||
| 12. Retirement and Postemployment Benefits | x | x | x | x | ||||||||||||||||||||||
| 13. Jointly Owned Facilities | x | x | x | |||||||||||||||||||||||
| 14. Commitments and Contingencies | x | x | x | x | ||||||||||||||||||||||
| 15. Related Party Transactions | x | x | x | |||||||||||||||||||||||
| 16. Other Income (Expense) - net | x | x | ||||||||||||||||||||||||
| 17. Fair Value Measurements | x | x | x | x | ||||||||||||||||||||||
| 18. Derivative Instruments and Hedging Activities | x | x | x | x | ||||||||||||||||||||||
| 19. Goodwill and Other Intangible Assets | x | x | x | x | ||||||||||||||||||||||
| 20. Asset Retirement Obligations | x | x | x | x | ||||||||||||||||||||||
| 21. Accumulated Other Comprehensive Income (Loss) | x | |||||||||||||||||||||||||
1. Summary of Significant Accounting Policies
(All Registrants)
General
Capitalized terms and abbreviations appearing in the combined notes to 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 Registrants' related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant.
Business and Consolidation
(PPL)
PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the distribution of electricity in the U.K.; 2) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 3)2) the transmission, distribution and sale of electricity in Pennsylvania. Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global, LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding.
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On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which substantially represented PPL's U.K. Regulated segment, to a subsidiary of PPL Global, through indirect, wholly owned subsidiaries, operates distribution networks providing electricity service inNational Grid plc. The sale was completed on June 14, 2021. The results of operations of the U.K. WPD serves end-users in South Walesutility business are classified as Discontinued Operations on PPL's Statements of Income. The assets and southwestliabilities of the U.K. utility business as of December 31, 2020 are classified as assets and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands)liabilities held for sale on PPL's Balance Sheets. PPL has elected to separately report the cash flows of continuing and WPD (West Midlands).discontinued operations on the Statements of Cash Flows. Unless otherwise noted, the notes to these financial statements exclude amounts related to discontinued operations and assets and liabilities held for sale for all periods presented. See Note 9 for additional information.
(PPL and PPL Electric)
PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR.
(PPL, LKE, LG&E and KU)
(All Registrants)
The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Variable Interest Entities (VIEs). The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE and, as a result, are the primary beneficiary of the entity. The RegistrantsAmounts consolidated under the VIE guidance are not material to the primary beneficiary in any VIEs. Investments in entities in which a company has the ability toRegistrants.
The financial statements of PPL, LKE, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 1213 for additional information.
Regulation
(PPL Electric, LG&E and KU)All Registrants)
PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future costs, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 67 for additional details regarding regulatory matters.
Accounting Records
The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions.
Use of Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Loss Accruals
Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of the uncertain future events and (2) the amount of the loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate.
The accrual of contingencies that might result in gains is not recorded, unless realization is assured.
Earnings Per Share(PPL)
EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-
Price Risk Management
(All Registrants)
Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures, primarily associated with PPL's investments in U.K. subsidiaries.exposures. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation.
Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved that wouldto facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because the NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities."
Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items.
PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
(PPL)
Processes exist that allow for subsequent review and validation of the contract information as it relates to interest rate derivatives and foreign currency derivatives. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to:
•Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.
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•Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.
•Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges.
•Transactions to hedge the value of a net investment of foreign operations can be designated as net investment hedges.
•Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. These transactions generally include foreign currency forwards and options to hedge GBP-denominated earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously completed sale of its U.K utility business and net investments.
(All Registrants)
Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are included in customer rates.
(PPL and PPL Electric)
To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts.
See Notes 1617 and 1718 for additional information on derivatives.
| 2017 | 2016 | 2015 | |||||||||
| Domestic electric and gas revenues (a) | $ | 5,351 | $ | 5,297 | $ | 5,239 | |||||
| U.K. operating revenues (b) | 2,091 | 2,207 | 2,410 | ||||||||
| Domestic - other | 5 | 13 | 20 | ||||||||
| Total | $ | 7,447 | $ | 7,517 | $ | 7,669 | |||||
Revenue Recognition
(All Registrants)
Operating revenues are primarily recorded based on energy deliveries through the end of theeach calendar month. Unbilled retail revenues result because customers' bills are rendered throughout the month, rather than bills being rendered at the end of the month. For LKE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf by the estimated average cents per kWh.kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled kWhvolumes by an average ratethe price per customer class.tariff.
Financing and under-recovered amounts arising for the periods beginning with the 2014/15 regulatory year and refunded/recovered under RIIO-ED1 will be refunded/recovered on a two year lag (previously one year). Therefore the 2014/15 over/under-recovery adjustment occurred in the 2016/17 regulatory year.Other Receivables
(All Registrants)
Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Financing receivables include accounts receivable, with the exception of those items within accounts receivable that are not subject to the credit loss model.
The Registrants periodically evaluate the impact of observable external factors on the collectibility of the financing receivables to determine if adjustments to the allowance for doubtful accounts should be made based on current conditions or reasonable and supportable forecasts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible.
99
(PPL and PPL Electric)
PPL Electric has identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with residential and non-residential customers. All other financing receivables are classified as other. Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation.
(PPL, LG&E and KU)
LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other.
(All Registrants)
The changes in the allowance for doubtful accounts were: are included in the following table. Amounts relate to financing receivables, except as noted.
| Additions | ||||||||||||||||||||||||||||||||
| Balance at Beginning of Period | Charged to Income | Charged to Other Accounts | Deductions (b) | Balance at End of Period | ||||||||||||||||||||||||||||
| PPL | ||||||||||||||||||||||||||||||||
2021 | $ | 73 | $ | 26 | $ | — | $ | 30 | $ | 69 | (d) | |||||||||||||||||||||
| 2020 (a) | 58 | (a) | 28 | — | 13 | 73 | (d) | |||||||||||||||||||||||||
| 2019 | 54 | 34 | 3 | 35 | 56 | |||||||||||||||||||||||||||
PPL Electric | ||||||||||||||||||||||||||||||||
| 2021 | $ | 41 | $ | 13 | $ | — | $ | 19 | $ | 35 | (c) | |||||||||||||||||||||
| 2020 | 30 | (a) | 19 | — | 8 | 41 | (c) | |||||||||||||||||||||||||
| 2019 | 27 | 26 | — | 25 | 28 | |||||||||||||||||||||||||||
| LG&E | ||||||||||||||||||||||||||||||||
| 2021 | $ | 3 | $ | 4 | $ | — | $ | 4 | $ | 3 | ||||||||||||||||||||||
| 2020 | 1 | 4 | — | 2 | 3 | |||||||||||||||||||||||||||
| 2019 | 1 | 2 | 2 | 4 | 1 | |||||||||||||||||||||||||||
| KU | ||||||||||||||||||||||||||||||||
| 2021 | $ | 2 | $ | 8 | $ | — | $ | 7 | $ | 3 | ||||||||||||||||||||||
| 2020 | 1 | 4 | — | 3 | 2 | |||||||||||||||||||||||||||
| 2019 | 2 | 4 | 1 | 6 | 1 | |||||||||||||||||||||||||||
| Additions | |||||||||||||||||||
Balance at Beginning of Period | Charged to Income | Charged to Other Accounts | Deductions (a) | Balance at End of Period | |||||||||||||||
| PPL | |||||||||||||||||||
| 2017 | $ | 54 | $ | 28 | $ | (1 | ) | $ | 30 | $ | 51 | ||||||||
| 2016 | 41 | 44 | — | 31 | 54 | ||||||||||||||
| 2015 | 44 | 49 | (2 | ) | 50 | 41 | |||||||||||||
| PPL Electric | |||||||||||||||||||
| 2017 | $ | 28 | $ | 18 | $ | — | $ | 22 | $ | 24 | |||||||||
| 2016 | 16 | 35 | — | 23 | 28 | ||||||||||||||
| 2015 | 17 | 39 | — | 40 | 16 | ||||||||||||||
(a)Adjusted for $2 million cumulative-effect adjustment upon adoption of current expected credit loss guidance.
(b)Primarily related to uncollectible accounts written off.
(c)Includes $3 million related to other accounts receivables at December 31, 2021 and 2020.
| Additions | |||||||||||||||||||
Balance at Beginning of Period | Charged to Income | Charged to Other Accounts | Deductions (a) | Balance at End of Period | |||||||||||||||
| LKE | |||||||||||||||||||
| 2017 | $ | 24 | $ | 8 | $ | (1 | ) | $ | 6 | $ | 25 | ||||||||
| 2016 | 23 | 8 | — | 7 | 24 | ||||||||||||||
| 2015 | 25 | 9 | (2 | ) | 9 | 23 | |||||||||||||
| LG&E | |||||||||||||||||||
| 2017 | $ | 2 | $ | 2 | $ | (1 | ) | $ | 2 | $ | 1 | ||||||||
| 2016 | 1 | 2 | 1 | 2 | 2 | ||||||||||||||
| 2015 | 2 | 2 | — | 3 | 1 | ||||||||||||||
| KU | |||||||||||||||||||
| 2017 | $ | 2 | $ | 4 | $ | (1 | ) | $ | 4 | $ | 1 | ||||||||
| 2016 | 2 | 4 | — | 4 | 2 | ||||||||||||||
| 2015 | 2 | 5 | — | 5 | 2 | ||||||||||||||
Cash
(All Registrants)
Cash Equivalents
All highly liquid investments with original maturities of three months or less are considered to be cash equivalents.
100
(PPL)
Restricted Cash and Cash Equivalents
Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. The change in restricted cash and cash equivalents is reported as an investing activity on the Statements of Cash Flows. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."
The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balancesBalance Sheets to the amounts shown on the Statements of restricted cash and cash equivalents included the following: Cash Flows:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||
| Cash and cash equivalents | $ | 3,571 | $ | 442 | |||||||||||||||||||
| Restricted cash - current | 1 | 1 | |||||||||||||||||||||
| Total Cash, Cash Equivalents and Restricted Cash | $ | 3,572 | $ | 443 | |||||||||||||||||||
| PPL | PPL Electric | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| Low carbon network fund (a) | $ | 17 | $ | 17 | $ | — | $ | — | |||||||
| Other | 9 | 9 | 2 | 2 | |||||||||||
| Total | $ | 26 | $ | 26 | $ | 2 | $ | 2 | |||||||
(All Registrants)
Fair Value Measurements
The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securities in defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, 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) to measure the fair value of an asset or liability. 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 Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows:
•Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.
•Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.
•Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value.
Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments
Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly
101
designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term.
Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets.
Long-Lived and Intangible Assets
Property, Plant and Equipment
(All Registrants)
PP&E is recorded at original cost, unless impaired. PP&E acquired in business combinations is recorded at fair value at the time of acquisition. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. Included in PP&E are capitalized costs of software projects that were developed or obtained for internal use. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which thework is performed and costs are incurred. No costs associated with planned major maintenance projects are accrued to PP&E in advance of the period in which the work is performed. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LKE, LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset. See "Asset Retirement Obligations" below and Note 6 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices.
AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC except for certain instances in KU's FERC approved rates charged to its municipal customers, as a return is provided on construction work in progress.
PPL capitalizesand PPL Electric capitalize interest costs as part of construction costs. Capitalized interest, including the debt component of AFUDC, for PPL, was $11 million in 2017, 2016 and 2015.the years ended December 31 is as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 6 | $ | 7 | $ | 9 | |||||||||||
| PPL Electric | 6 | 7 | 8 | ||||||||||||||
Depreciation(All Registrants)
Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that
was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset or regulatory liability. See "Asset Retirement Obligations" below and Note 7 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices.
Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31:
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| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | ||||||||||||||||||||
| PPL | 2.65 | % | 2.73 | % | 2.57 | % | PPL | 3.61 | % | 3.53 | % | 3.54 | % | ||||||||||||
| PPL Electric | 2.86 | % | 2.63 | % | 2.46 | % | PPL Electric | 3.05 | % | 2.99 | % | 3.05 | % | ||||||||||||
| LKE | 3.64 | % | 3.69 | % | 3.69 | % | |||||||||||||||||||
| LG&E | 3.63 | % | 3.58 | % | 3.65 | % | LG&E | 3.99 | % | 4.00 | % | 3.87 | % | ||||||||||||
| KU | 3.66 | % | 3.77 | % | 3.71 | % | KU | 4.17 | % | 4.00 | % | 4.02 | % | ||||||||||||
Goodwill and Other Intangible Assets (All Registrants)
Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination.
Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed
or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets.
When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider:
•the expected use of the asset;
•the expected useful life of other assets to which the useful life of the intangible asset may relate;
•legal, regulatory, or contractual provisions that may limit the useful life;
•the company's historical experience as evidence of its ability to support renewal or extension;
•the effects of obsolescence, demand, competition, and other economic factors; and,
•the level of maintenance expenditures required to obtain the expected future cash flows from the asset.
Asset Impairment (Excluding Investments)
(All Registrants)
The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable.
A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value.
A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell.
PPL, LKE, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LKE's, LG&E's and KU's reporting units are primarily at the operating segment level.
PPL, for its Kentucky Regulated segment and LKE reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a two-step quantitative test. If the qualitative evaluation (referred to as "step zero")step zero) is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the two-step quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment.
If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the implied fair valuetotal amount of goodwill must be calculated in the same manner as goodwill in a business combination. The fair value of a reporting unit is allocated to all assets and liabilitiesthat reporting unit.
In the fourth quarter of that unit as if the reporting unit had been acquired in a business combination. The excess of the fair value of the reporting unit over the amounts assigned to2021, PPL, for its assets and liabilities is the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, goodwill is written down to its implied fair value.
2021. Based on these evaluations, management concluded it was not more"more likely than notnot" that the fair value of these reporting units was less than their carrying value.values. As such, quantitative impairment tests were not performed.
103
(PPL)
During the two-stepthree month-period ended June 30, 2021, Safari Energy determined that the carrying value of its solar panel inventory would not be fully recoverable due to a decrease in the net realizable value of the modules. The decrease was due primarily to the combination of the three following factors: (1) a continued decrease in the fair value of the modules on hand due to more efficient modules being available on the market, (2) the federal government's extension of certain investment tax credits which make modules on the open market eligible for those credits at higher levels of credits and (3) an increase in commodity prices for materials used in various types of solar projects, all of which place pressure on the economics of those projects, making the cost of Safari's solar panels uncompetitive. As a result, Safari Energy recorded a loss of $37 million ($28 million after-tax) in June 2021 to record the solar panels at fair value. The loss was recorded to "Other operation and maintenance" expense on the Statement of Income. Solar panel inventories of $32 million are included in "Other noncurrent assets" on PPL's Balance Sheet at December 31, 2021.
PPL considered whether the events and circumstances that led to the impairment of Safari Energy's solar panels would more likely than not reduce the fair value of PPL's Distributed Energy Resources reporting unit below its carrying amount. Based on PPL's assessment, a quantitative impairment test was not performed and norequired as of June 30, 2021.
In the fourth quarter of 2021, PPL elected to perform a quantitative goodwill impairment was recognized.test in conjunction with the annual goodwill impairment assessment for the Distributed Energy Resources reporting unit. The test did not indicate impairment of the reporting unit , however, it is possible that an impairment charge could occur in future periods if any of the assumptions used in determining fair value of the reporting unit are negatively impacted.
(PPL, LKE, LG&E and KU)
Asset Retirement Obligations
PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Incometo reflect changes in the obligation due to the passage of time. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset.asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory assetdeferred accretion and depreciation expense is offset against the associatedrecovered through cost of removal regulatory liability, PP&E and ARO liability.removal.
Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 67 and Note 1920 for additional information on AROs.
Compensation and Benefits
Defined Benefits(All Registrants)
Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets.
The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value.
PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the expected average remaining service of active plan participants.required amortization period. Actuarial gains and losses in excess of 10% of the greater
104
of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the expected average remaining service period of active plan participants.full required amortization period.
See Note 67 for a discussion of the regulatory treatment of defined benefit costs and Note 1112 for a discussion of defined benefits.
Stock-Based Compensation(PPL and PPL Electric and LKE)Electric)
PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-
Taxes
Income Taxes
(All Registrants)
PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return.
Significant management judgment is also required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken inon tax returns and valuation allowances on deferred tax assets and whether the undistributed earnings of WPD are considered indefinitely reinvested.assets.
Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards.
The Registrants record valuation allowances to reduce deferred income tax assets to the amounts that are more likely than notmore-likely-than-not to be realized. The Registrants consider the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies in initially recording and subsequently reevaluating the need for valuation allowances.allowances requires significant management judgment. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determination is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such determination is made. The amount of deferred tax assets ultimately realized may differ materially from the estimates utilized in the computation of valuation allowances and may materially impact the financial statements in the future.
The Registrants defer investment tax credits when the credits are utilizedgenerated and amortize the deferred amounts over the average lives of the related assets.
The Registrants recognize tax-related interest and penalties in "Income Taxes" on their Statements of Income.
The Registrants use the portfolio approach method of accounting for deferred taxes related to pre-tax OCI transactions. The portfolio approach involves a strict period-by-period cumulative incremental allocation of income taxes to the change in income and losses reflected in OCI. Under this approach, the net cumulative tax effect is ignored. The net change in unrealized gains and losses recorded in AOCI under this approach would be eliminated only on the date the investment portfolio is classified as held for sale or is liquidated.
See Note 56 to the Financial Statements for additional discussion regarding income taxes, including the impact of the TCJA and management's conclusion that the undistributed earnings of WPD are considered indefinitely reinvested.tax disclosures.
The provision for PPL's, PPL Electric's, LKE's, LG&E's and KU'sthe Registrants' deferred income taxes forrelated to regulatory assets and liabilities is based upon the ratemaking principles reflected in rates established by therelevant regulators. The difference in the provision for deferred income taxes for regulatory assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included on the Balance Sheets in noncurrent "Regulatory assets" or "Regulatory liabilities."
(PPL Electric, LKE, LG&E and KU)
The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
At December 31, the following intercompany tax receivables (payables) were recorded:
| 2021 | 2020 | ||||||||||
| PPL Electric | $ | (4) | $ | (9) | |||||||
| LG&E | 4 | (1) | |||||||||
| KU | 1 | (5) | |||||||||
| 2017 | 2016 | ||||||
| PPL Electric | $ | 61 | $ | 13 | |||
| LKE | (23 | ) | 1 | ||||
| LG&E | — | (18 | ) | ||||
| KU | — | (29 | ) | ||||
Taxes, Other Than Income(All Registrants)
The Registrants present sales taxes in "Other current liabilities" and PPL presents value-added taxes in "Taxes" on the Balance Sheets. These taxes are not reflected on the Statements of Income. See Note 56 for details onof taxes included in "Taxes, other than income" on the Statements of Income.
Other
(All Registrants)
Leases
The Registrants evaluate whether arrangements entered into contain leases for accounting purposes. See Note 910 for additional information.
Fuel, Materials and Supplies
Fuel, natural gas stored underground and materials and supplies are valued using the average cost method. Fuel costs for electricelectricity generation are charged to expense as used. For LG&E, natural gas supply costs are charged to expense as delivered to the distribution system. See Note 67 for further discussion of the fuel adjustment clauseclauses and gas supply clause.
"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31:
| 2021 | |||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| Fuel | $ | 90 | $ | — | $ | 32 | $ | 58 | |||||||||||||||
| Natural gas stored underground | 54 | — | 54 | — | |||||||||||||||||||
| Materials and supplies | 178 | 61 | 51 | 66 | |||||||||||||||||||
| Total | $ | 322 | $ | 61 | $ | 137 | $ | 124 | |||||||||||||||
| PPL | LKE | LG&E | KU | ||||||||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||||||||
| Fuel | $ | 107 | $ | 158 | $ | 107 | $ | 158 | $ | 45 | $ | 60 | $ | 62 | $ | 98 | |||||||||||||||
| Natural gas stored underground | 43 | 42 | 43 | 42 | 43 | 42 | — | — | |||||||||||||||||||||||
| Materials and supplies | 170 | 156 | 104 | 97 | 43 | 41 | 61 | 56 | |||||||||||||||||||||||
| Total | $ | 320 | $ | 356 | $ | 254 | $ | 297 | $ | 131 | $ | 143 | $ | 123 | $ | 154 | |||||||||||||||
| 2020 | |||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| Fuel | $ | 95 | $ | — | $ | 38 | $ | 57 | |||||||||||||||
| Natural gas stored underground | 30 | — | 30 | — | |||||||||||||||||||
| Materials and supplies | 177 | 59 | 51 | 66 | |||||||||||||||||||
| Total | $ | 302 | $ | 59 | $ | 119 | $ | 123 | |||||||||||||||
Guarantees(All Registrants)
Generally, the initial measurement of a guarantee liability is the fair value of the guarantee at its inception. However, there are certain guarantees excluded from the scope of accounting guidance and other guarantees that are not subject to the initial recognition and measurement provisions of accounting guidance that only require disclosure. See Note 1314 for further discussion of recorded and unrecorded guarantees.
(PPL)
Treasury Stock(PPL)
PPL generally restores all shares of common stock acquired to authorized but unissued shares of common stock upon or soon after acquisition. In connection with its recent share repurchases in the third and fourth quarter of 2021, PPL has not yet returned these shares to authorized but unissued shares, as it is determining if it will retain some portion of these shares as Treasury stock to use in connection with certain compensation plans.
Foreign Currency Translation and Transactions(PPL)
2. Segment and Related Information
(PPL)
PPL is organized into three2 segments: U.K. Regulated, Kentucky Regulated and Pennsylvania Regulated. PPL's segments are segmented by geographic location.
The Kentucky Regulated segment consists primarily of LKE'sLG&E's and KU's regulated electricity generation, transmission and distribution operations, of LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. In addition, certain acquisition-related financing costs are allocated to the Kentucky Regulated segment.
The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. In addition, certain costs are allocated to the Pennsylvania Regulated segment.
"Corporate and Other" primarily includes financing costs incurred at the corporate level that have not been allocated or assigned to the segments, as well as certain other unallocated costs, as well as the financial results of Safari Energy, which is presented to reconcile segment information to PPL's consolidated results. For the periods ended December 31, 2020 and 2019, these amounts have been adjusted for certain costs that were previously included in the U.K. Regulated segment.
On June 1, 2015,March 17, 2021, PPL completed the spinoff of PPL Energy Supply,WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which substantially represented PPL's SupplyU.K. Regulated segment. As a result, of this transaction, PPL determined segment information for the U.K. Regulated segment would no longer has a Supply segment and its results are presented in "Discontinued Operations".be provided beginning with the March 31, 2021 Form 10-Q. The sale of the U.K. utility business was completed on June 14, 2021. See Note 89 for additional information.
Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Operating Revenues from external customers (a) | |||||||||||||||||
| Kentucky Regulated | $ | 3,348 | $ | 3,106 | $ | 3,206 | |||||||||||
| Pennsylvania Regulated | 2,402 | 2,330 | 2,358 | ||||||||||||||
| Corporate and Other | 33 | 38 | 38 | ||||||||||||||
| Total | $ | 5,783 | $ | 5,474 | $ | 5,602 | |||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Depreciation | |||||||||||||||||
| Kentucky Regulated | $ | 647 | $ | 606 | $ | 547 | |||||||||||
| Pennsylvania Regulated | 424 | 403 | 386 | ||||||||||||||
| Corporate and Other | 11 | 13 | 16 | ||||||||||||||
| Total | $ | 1,082 | $ | 1,022 | $ | 949 | |||||||||||
| Amortization (b) | |||||||||||||||||
| Kentucky Regulated | $ | 15 | $ | 19 | $ | 27 | |||||||||||
| Pennsylvania Regulated | 19 | 26 | 24 | ||||||||||||||
| Corporate and Other | 5 | 13 | 7 | ||||||||||||||
| Total | $ | 39 | $ | 58 | $ | 58 | |||||||||||
| Interest Expense (c) | |||||||||||||||||
| Kentucky Regulated | $ | 249 | $ | 300 | $ | 298 | |||||||||||
| Pennsylvania Regulated | 162 | 172 | 169 | ||||||||||||||
| Corporate and Other (d) | 507 | 162 | 154 | ||||||||||||||
| Total | $ | 918 | $ | 634 | $ | 621 | |||||||||||
| Income Before Income Taxes | |||||||||||||||||
| Kentucky Regulated | $ | 562 | $ | 516 | $ | 530 | |||||||||||
| Pennsylvania Regulated | 599 | 664 | 607 | ||||||||||||||
| Corporate and Other | (640) | (226) | (218) | ||||||||||||||
| Total | $ | 521 | $ | 954 | $ | 919 | |||||||||||
| Income Taxes (e) | |||||||||||||||||
| Kentucky Regulated | $ | 94 | $ | 98 | $ | 94 | |||||||||||
| Pennsylvania Regulated | 154 | 167 | 149 | ||||||||||||||
| Corporate and Other | 255 | 49 | (60) | ||||||||||||||
| Total | $ | 503 | $ | 314 | $ | 183 | |||||||||||
| Deferred income taxes and investment tax credits (f) | |||||||||||||||||
| Kentucky Regulated | $ | 272 | $ | 64 | $ | 82 | |||||||||||
| Pennsylvania Regulated | 79 | 82 | 90 | ||||||||||||||
| Corporate and Other | (264) | 23 | (3) | ||||||||||||||
| Total | $ | 87 | $ | 169 | $ | 169 | |||||||||||
| Net Income | |||||||||||||||||
| Kentucky Regulated | $ | 468 | $ | 418 | $ | 436 | |||||||||||
| Pennsylvania Regulated | 445 | 497 | 458 | ||||||||||||||
| Corporate and Other (d) | (895) | (275) | (158) | ||||||||||||||
| Discontinued Operations | (1,498) | 829 | 1,010 | ||||||||||||||
| Total | $ | (1,480) | $ | 1,469 | $ | 1,746 | |||||||||||
(a)See Note 1 and Note 3 for additional information on Operating Revenues.
(b)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.
(c)Beginning in 2021, corporate level financing costs are no longer allocated to the reportable segments and are being reported in Corporate and Other. For the years ended December 31, 2020 and 2019, corporate level financing costs of $32 million, net of $8 million of income taxes, and $32 million, net of $9 million of income taxes, were allocated to the Kentucky Regulated segment. For the years ended December 31, 2020 and 2019, an immaterial amount of financing costs were allocated to the Pennsylvania Regulated segment.
(d)2021 includes losses from the extinguishment of PPL Capital Funding debt. See Note 8 for additional information.
(e)Represents both current and deferred income taxes, including investment tax credits.
(f)Represents a non-cash expense item that is also included in "Income Taxes."
| 2017 | 2016 | 2015 | |||||||||
| Operating Revenues from external customers (a) | |||||||||||
| U.K. Regulated | $ | 2,091 | $ | 2,207 | $ | 2,410 | |||||
| Kentucky Regulated | 3,156 | 3,141 | 3,115 | ||||||||
| Pennsylvania Regulated | 2,195 | 2,156 | 2,124 | ||||||||
| Corporate and Other | 5 | 13 | 20 | ||||||||
| Total | $ | 7,447 | $ | 7,517 | $ | 7,669 | |||||
| Depreciation | |||||||||||
| U.K. Regulated | $ | 230 | $ | 233 | $ | 242 | |||||
| Kentucky Regulated | 439 | 404 | 382 | ||||||||
| Pennsylvania Regulated | 309 | 253 | 214 | ||||||||
| Corporate and Other | 30 | 36 | 45 | ||||||||
| Total | $ | 1,008 | $ | 926 | $ | 883 | |||||
| Amortization (b) | |||||||||||
| U.K. Regulated | $ | 34 | $ | 16 | $ | 6 | |||||
| Kentucky Regulated | 24 | 29 | 27 | ||||||||
| Pennsylvania Regulated | 33 | 32 | 26 | ||||||||
| Corporate and Other | 6 | 3 | — | ||||||||
| Total | $ | 97 | $ | 80 | $ | 59 | |||||
| Unrealized (gains) losses on derivatives and other hedging activities (c) | |||||||||||
| U.K. Regulated | $ | 166 | $ | 13 | $ | (88 | ) | ||||
| Kentucky Regulated | 6 | 6 | 11 | ||||||||
| Corporate and Other | 6 | — | — | ||||||||
| Total | $ | 178 | $ | 19 | $ | (77 | ) | ||||
| Interest Expense | |||||||||||
| U.K. Regulated | $ | 397 | $ | 402 | $ | 417 | |||||
| Kentucky Regulated | 261 | 260 | 232 | ||||||||
| Pennsylvania Regulated | 142 | 129 | 130 | ||||||||
| Corporate and Other | 101 | 97 | 92 | ||||||||
| Total | $ | 901 | $ | 888 | $ | 871 | |||||
| Income from Continuing Operations Before Income Taxes | |||||||||||
| U.K. Regulated | $ | 804 | $ | 1,479 | $ | 1,249 | |||||
| Kentucky Regulated | 645 | 640 | 547 | ||||||||
| Pennsylvania Regulated | 575 | 550 | 416 | ||||||||
| Corporate and Other (d) | (112 | ) | (119 | ) | (144 | ) | |||||
| Total | $ | 1,912 | $ | 2,550 | $ | 2,068 | |||||
| Income Taxes (e) | |||||||||||
| U.K. Regulated | $ | 152 | $ | 233 | $ | 128 | |||||
| Kentucky Regulated | 359 | 242 | 221 | ||||||||
| Pennsylvania Regulated | 216 | 212 | 164 | ||||||||
| Corporate and Other (d) | 57 | (39 | ) | (48 | ) | ||||||
| Total | $ | 784 | $ | 648 | $ | 465 | |||||
| Deferred income taxes and investment tax credits (f) | |||||||||||
| U.K. Regulated | $ | 66 | $ | 31 | $ | 45 | |||||
| Kentucky Regulated | 294 | 291 | 236 | ||||||||
| Pennsylvania Regulated | 257 | 221 | 220 | ||||||||
| Corporate and Other (d) | 90 | 17 | (73 | ) | |||||||
| Total | $ | 707 | $ | 560 | $ | 428 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Net Income | |||||||||||
| U.K. Regulated | $ | 652 | $ | 1,246 | $ | 1,121 | |||||
| Kentucky Regulated | 286 | 398 | 326 | ||||||||
| Pennsylvania Regulated | 359 | 338 | 252 | ||||||||
| Corporate and Other (d) | (169 | ) | (80 | ) | (96 | ) | |||||
| Discontinued Operations (g) | — | — | (921 | ) | |||||||
| Total | $ | 1,128 | $ | 1,902 | $ | 682 | |||||
Cash Flow data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Expenditures for long-lived assets | |||||||||||||||||
| Kentucky Regulated | $ | 1,026 | $ | 966 | $ | 1,097 | |||||||||||
| Pennsylvania Regulated | 904 | 1,154 | 1,121 | ||||||||||||||
| Corporate and Other | 49 | 158 | 32 | ||||||||||||||
| Total | $ | 1,979 | $ | 2,278 | $ | 2,250 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Expenditures for long-lived assets | |||||||||||
| U.K. Regulated | $ | 1,015 | $ | 1,031 | $ | 1,242 | |||||
| Kentucky Regulated | 892 | 791 | 1,210 | ||||||||
| Pennsylvania Regulated | 1,254 | 1,134 | 1,107 | ||||||||
| Corporate and Other | 10 | 1 | 11 | ||||||||
| Total | $ | 3,171 | $ | 2,957 | $ | 3,570 | |||||
The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of:
| As of December 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Total Assets | |||||||||||
| Kentucky Regulated | $ | 16,360 | $ | 15,943 | |||||||
| Pennsylvania Regulated | 13,336 | 12,347 | |||||||||
| Corporate and Other (a) | 3,527 | 843 | |||||||||
| Assets held for sale (b) | — | 18,983 | |||||||||
| Total | $ | 33,223 | $ | 48,116 | |||||||
| As of December 31, | |||||||
| 2017 | 2016 | ||||||
| Total Assets | |||||||
| U.K. Regulated (a) | $ | 16,813 | $ | 14,537 | |||
| Kentucky Regulated | 14,468 | 14,037 | |||||
| Pennsylvania Regulated | 10,082 | 9,426 | |||||
| Corporate and Other (b) | 116 | 315 | |||||
| Total | $ | 41,479 | $ | 38,315 | |||
(a)Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy.
| 2017 | 2016 | 2015 | |||||||||
| Revenues from external customers | |||||||||||
| U.K. | $ | 2,091 | $ | 2,207 | $ | 2,410 | |||||
| U.S. | 5,356 | 5,310 | 5,259 | ||||||||
| Total | $ | 7,447 | $ | 7,517 | $ | 7,669 | |||||
| As of December 31, | |||||||
| 2017 | 2016 | ||||||
| Long-Lived Assets | |||||||
| U.K. | $ | 12,851 | $ | 11,177 | |||
| U.S. | 20,936 | 19,595 | |||||
| Total | $ | 33,787 | $ | 30,772 | |||
(PPL Electric, LKE, LG&E and KU)
PPL Electric has two2 operating segments that are aggregated into a single reportable segment. LKE, LG&E and KU are individually single operating and reportable segments.
3. Revenue from Contracts with Customers
(All Registrants)
The following is a description of the principal activities from which the Registrants and PPL’s segments generate their revenues.
(PPL and PPL Electric)
Pennsylvania Regulated Segment Revenue
The Pennsylvania Regulated Segment generates substantially all of its revenues from contracts with customers from PPL Electric’s tariff-based distribution and transmission of electricity.
Distribution Revenue
PPL Electric provides distribution services to residential, commercial, industrial, municipal and governmental end users of energy. PPL Electric satisfies its performance obligation to its distribution customers and revenue is recognized over-time as electricity is delivered and simultaneously consumed by the customer. The amount of revenue recognized is the volume of electricity delivered during the period multiplied by the price per tariff, plus a monthly fixed charge. This method of recognition fairly presents PPL Electric's transfer of electric service to the customer as the calculation is based on actual volumes, and the price per tariff and the monthly fixed charge are set by the PUC. Customers are typically billed monthly and outstanding amounts are normally due within 21 days of the date of the bill.
Distribution customers are "at will" customers of PPL Electric with no term contract and no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with PPL Electric’s retail account contracts.
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Transmission Revenue
PPL Electric generates transmission revenues from a FERC-approved PJM Open Access Transmission Tariff. An annual revenue requirement for PPL Electric to provide transmission services is calculated using a formula-based rate. This revenue requirement is converted into a daily rate (dollars per day). PPL Electric satisfies its performance obligation to provide transmission services and revenue is recognized over-time as transmission services are provided and consumed. This method of recognition fairly presents PPL Electric's transfer of transmission services as the daily rate is set by a FERC approved formula-based rate. PJM remits payment on a weekly basis.
PPL Electric's agreement to provide transmission services contains no minimum purchase commitment. The performance obligation is limited to the service requested and received to date. Accordingly, PPL Electric has no unsatisfied performance obligations.
(PPL, LG&E and KU)
Kentucky Regulated Segment Revenue
The Kentucky Regulated Segment generates substantially all of its revenues from contracts with customers from LG&E's and KU's regulated tariff-based sales of electricity and LG&E's regulated tariff-based sales of natural gas.
LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity in Kentucky and, in KU's case, Virginia. LG&E also engages in the distribution and sale of natural gas in Kentucky. Revenue from these activities is generated from tariffs approved by applicable regulatory authorities including the FERC, KPSC and VSCC. LG&E and KU satisfy their performance obligations upon LG&E's and KU's delivery of electricity and LG&E's delivery of natural gas to customers. This revenue is recognized over-time as the customer simultaneously receives and consumes the benefits provided by LG&E and KU. The amount of revenue recognized is the billed volume of electricity or natural gas delivered multiplied by a tariff rate per-unit of energy, plus any applicable fixed charges or additional regulatory mechanisms. Customers are billed monthly and outstanding amounts are typically due within 22 days of the date of the bill. Additionally, unbilled revenues are recognized as a result of customers' bills rendered throughout the month, rather than bills being rendered at the end of the month. Unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf delivered but not yet billed by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. This method of recognition fairly presents LG&E's and KU's transfer of electricity and LG&E's transfer of natural gas to the customer as the amount recognized is based on actual and estimated volumes delivered and the tariff rate per-unit of energy and any applicable fixed charges or regulatory mechanisms as set by the respective regulatory body.
LG&E's and KU's customers generally have no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with these customers.
(All Registrants)
The following table reconciles "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the years ended December31:
| 2021 | |||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| Operating Revenues (a) | $ | 5,783 | $ | 2,402 | $ | 1,569 | $ | 1,826 | |||||||||||||||
| Revenues derived from: | |||||||||||||||||||||||
| Alternative revenue programs (b) | 77 | 83 | (3) | (3) | |||||||||||||||||||
| Other (c) | (22) | (3) | (8) | (9) | |||||||||||||||||||
| Revenues from Contracts with Customers | $ | 5,838 | $ | 2,482 | $ | 1,558 | $ | 1,814 | |||||||||||||||
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| 2020 | |||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| Operating Revenues (a) | $ | 5,474 | $ | 2,331 | $ | 1,456 | $ | 1,690 | |||||||||||||||
| Revenues derived from: | |||||||||||||||||||||||
| Alternative revenue programs (b) | (24) | (12) | (8) | (4) | |||||||||||||||||||
| Other (c) | (21) | (3) | (7) | (10) | |||||||||||||||||||
| Revenues from Contracts with Customers | $ | 5,429 | $ | 2,316 | $ | 1,441 | $ | 1,676 | |||||||||||||||
| 2019 | |||||||||||||||||||||||
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||
| Operating Revenues (a) | $ | 5,602 | $ | 2,358 | $ | 1,500 | $ | 1,740 | |||||||||||||||
| Revenues derived from: | |||||||||||||||||||||||
| Alternative revenue programs (b) | (30) | (6) | (10) | (14) | |||||||||||||||||||
| Other (c) | (31) | (10) | (9) | (12) | |||||||||||||||||||
| Revenues from Contracts with Customers | $ | 5,541 | $ | 2,342 | $ | 1,481 | $ | 1,714 | |||||||||||||||
(a)Amounts for PPL Electric represent revenues from external customers reported by the Pennsylvania Regulated segment and amounts for 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)Alternative revenue programs include the transmission formula rate for PPL Electric, the ECR and DSM programs for LG&E and KU, the GLT and GSC programs for LG&E, and the generation formula rate for KU. For PPL Electric, revenue in 2021 was reduced by $78 million for a reduction in the transmission formula rate return on equity. See Note 7 for additional information. This line item shows the over/under collection of these rate mechanisms with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts.
(c)Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues.
The following table shows revenues from contracts with customers disaggregated by customer class for the years ended December31:
| 2021 | |||||||||||||||||||||||||||||||||||||||||||||||
| Residential | Commercial | Industrial | Other (a) | Wholesale - municipality | Wholesale - other (b) | Transmission | Revenues from Contracts with Customers | ||||||||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||||||||
| PA Regulated | $ | 1,299 | $ | 350 | $ | 53 | $ | 50 | $ | — | $ | — | $ | 730 | $ | 2,482 | |||||||||||||||||||||||||||||||
| KY Regulated | 1,416 | 928 | 586 | 305 | 24 | 66 | — | 3,325 | |||||||||||||||||||||||||||||||||||||||
| Corp and Other | — | — | — | 31 | — | — | — | 31 | |||||||||||||||||||||||||||||||||||||||
| Total PPL | $ | 2,715 | $ | 1,278 | $ | 639 | $ | 386 | $ | 24 | $ | 66 | $ | 730 | $ | 5,838 | |||||||||||||||||||||||||||||||
| PPL Electric | $ | 1,299 | $ | 350 | $ | 53 | $ | 50 | $ | — | $ | — | $ | 730 | $ | 2,482 | |||||||||||||||||||||||||||||||
| LG&E | $ | 711 | $ | 473 | $ | 180 | $ | 145 | $ | — | $ | 49 | $ | — | $ | 1,558 | |||||||||||||||||||||||||||||||
| KU | $ | 705 | $ | 455 | $ | 406 | $ | 160 | $ | 24 | $ | 64 | $ | — | $ | 1,814 | |||||||||||||||||||||||||||||||
111
| 2020 | |||||||||||||||||||||||||||||||||||||||||||||||
| Residential | Commercial | Industrial | Other (a) | Wholesale - municipality | Wholesale - other (b) | Transmission | Revenues from Contracts with Customers | ||||||||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||||||||
| PA Regulated | $ | 1,238 | $ | 314 | $ | 44 | $ | 50 | $ | — | $ | — | $ | 670 | $ | 2,316 | |||||||||||||||||||||||||||||||
| KY Regulated | 1,347 | 871 | 538 | 261 | 20 | 40 | — | 3,077 | |||||||||||||||||||||||||||||||||||||||
| Corp and Other | — | — | — | 36 | — | — | — | 36 | |||||||||||||||||||||||||||||||||||||||
| Total PPL | $ | 2,585 | $ | 1,185 | $ | 582 | $ | 347 | $ | 20 | $ | 40 | $ | 670 | $ | 5,429 | |||||||||||||||||||||||||||||||
| PPL Electric | $ | 1,238 | $ | 314 | $ | 44 | $ | 50 | $ | — | $ | — | $ | 670 | $ | 2,316 | |||||||||||||||||||||||||||||||
| LG&E | $ | 676 | $ | 444 | $ | 173 | $ | 114 | $ | — | $ | 34 | $ | — | $ | 1,441 | |||||||||||||||||||||||||||||||
| KU | $ | 671 | $ | 427 | $ | 365 | $ | 147 | $ | 20 | $ | 46 | $ | — | $ | 1,676 | |||||||||||||||||||||||||||||||
| 2019 | |||||||||||||||||||||||||||||||||||||||||||||||
| Residential | Commercial | Industrial | Other (a) | Wholesale - municipality | Wholesale - other (b) | Transmission | Revenues from Contracts with Customers | ||||||||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||||||||
| PA Regulated | $ | 1,288 | $ | 349 | $ | 59 | $ | 52 | $ | — | $ | — | $ | 594 | $ | 2,342 | |||||||||||||||||||||||||||||||
| KY Regulated | 1,322 | 908 | 562 | 277 | 43 | 49 | — | 3,161 | |||||||||||||||||||||||||||||||||||||||
| Corp and Other | — | — | — | 38 | — | — | — | 38 | |||||||||||||||||||||||||||||||||||||||
| Total PPL | $ | 2,610 | $ | 1,257 | $ | 621 | $ | 367 | $ | 43 | $ | 49 | $ | 594 | $ | 5,541 | |||||||||||||||||||||||||||||||
| PPL Electric | $ | 1,288 | $ | 349 | $ | 59 | $ | 52 | $ | — | $ | — | $ | 594 | $ | 2,342 | |||||||||||||||||||||||||||||||
| LG&E | $ | 668 | $ | 466 | $ | 180 | $ | 121 | $ | — | $ | 46 | $ | — | $ | 1,481 | |||||||||||||||||||||||||||||||
| KU | $ | 654 | $ | 442 | $ | 382 | $ | 156 | $ | 43 | $ | 37 | $ | — | $ | 1,714 | |||||||||||||||||||||||||||||||
(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses.
(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 PPL.
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. PPL Electric's revenues from contracts with customers are further disaggregated by distribution and transmission as indicated in the above tables.
Contract receivables from customers are primarily included in "Accounts receivable - Customer" and "Unbilled revenues" on the Balance Sheets.
The following table shows the accounts receivable and unbilled revenues balances that were impaired for the year ended December31:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 22 | $ | 25 | $ | 27 | |||||||||||
| PPL Electric | 10 | 17 | 21 | ||||||||||||||
| LG&E | 4 | 4 | 2 | ||||||||||||||
| KU | 8 | 4 | 4 | ||||||||||||||
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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 as of December 31, 2021 | $ | 42 | $ | 25 | $ | 6 | $ | 6 | |||||||||||||||
| Contract liabilities as of December 31, 2020 | 40 | 23 | 5 | 6 | |||||||||||||||||||
| Revenue recognized during the year ended December 31, 2021 that was included in the contract liability balance at December 31, 2020 | 24 | 11 | 5 | 6 | |||||||||||||||||||
| Contract liabilities as of December 31, 2020 | $ | 40 | $ | 23 | $ | 5 | $ | 6 | |||||||||||||||
| Contract liabilities as of December 31, 2019 | 37 | 21 | 5 | 4 | |||||||||||||||||||
| Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 | 22 | 9 | 5 | 4 | |||||||||||||||||||
| Contract liabilities as of December 31, 2019 | $ | 37 | $ | 21 | $ | 5 | $ | 4 | |||||||||||||||
| Contract liabilities as of December 31, 2018 | 40 | 23 | 5 | 4 | |||||||||||||||||||
| Revenue recognized during the year ended December 31, 2019 that was included in the contract liability balance at December 31, 2018 | 25 | 11 | 5 | 4 | |||||||||||||||||||
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 recognized as revenue ratably over the billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods.
At December 31, 2021, PPL had $46 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $41 million within the next 12 months.
4. Preferred Securities
(PPL)
PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2017, 20162021, 2020 or 2015.2019.
(PPL Electric)
PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2017, 20162021, 2020 or 2015.2019.
(LG&E)
LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2017, 20162021, 2020 or 2015.2019.
(KU)
KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2017, 20162021, 2020 or 2015.2019.
(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 incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below.
113
These securities also included the remaining shares of PPL common stock forward sale agreements, which were settled in 2019. The forward sale agreements were dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares exceeded the forward sale price prescribed in the agreements.
Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31, used in the EPS calculation are:
| 2021 | 2020 | 2019 | |||||||||||||||
| Income (Numerator) | |||||||||||||||||
| Income from continuing operations after income taxes | $ | 18 | $ | 640 | $ | 736 | |||||||||||
| Less amounts allocated to participating securities | — | 1 | 1 | ||||||||||||||
| Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted | $ | 18 | $ | 639 | $ | 735 | |||||||||||
| Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted | $ | (1,498) | $ | 829 | $ | 1,010 | |||||||||||
| Net income (loss) attributable to PPL | $ | (1,480) | $ | 1,469 | 1,746 | ||||||||||||
| Less amounts allocated to participating securities | — | 1 | 1 | ||||||||||||||
| Net income (loss) available to PPL common shareowners - Basic and Diluted | $ | (1,480) | $ | 1,468 | $ | 1,745 | |||||||||||
| Shares of Common Stock (Denominator) | |||||||||||||||||
| Weighted-average shares - Basic EPS | 762,902 | 768,590 | 728,512 | ||||||||||||||
| Add incremental non-participating securities: | |||||||||||||||||
| Add: Dilutive share-based payment awards (a) | 1,917 | 794 | 1,101 | ||||||||||||||
| Add: Forward sale agreements | — | — | 7,141 | ||||||||||||||
| Weighted-average shares - Diluted EPS | 764,819 | 769,384 | 736,754 | ||||||||||||||
| Basic EPS | |||||||||||||||||
| Available to PPL common shareowners: | |||||||||||||||||
| Income from continuing operations after income taxes | $ | 0.03 | $ | 0.83 | $ | 1.01 | |||||||||||
| Income (loss) from discontinued operations (net of income taxes) | (1.96) | 1.08 | 1.38 | ||||||||||||||
| Net Income (Loss) available to PPL common shareowners | $ | (1.93) | $ | 1.91 | $ | 2.39 | |||||||||||
| Diluted EPS | |||||||||||||||||
| Available to PPL common shareowners: | |||||||||||||||||
| Income from continuing operations after income taxes | $ | 0.03 | $ | 0.83 | $ | 1.00 | |||||||||||
| Income (loss) from discontinued operations (net of income taxes) | (1.96) | 1.08 | 1.37 | ||||||||||||||
| Net Income (Loss) available to PPL common shareowners | $ | (1.93) | $ | 1.91 | $ | 2.37 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income (Numerator) | |||||||||||
| Income from continuing operations after income taxes | $ | 1,128 | $ | 1,902 | $ | 1,603 | |||||
| Less amounts allocated to participating securities | 2 | 6 | 6 | ||||||||
Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted | $ | 1,126 | $ | 1,896 | $ | 1,597 | |||||
Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted | $ | — | $ | — | $ | (921 | ) | ||||
| Net income | $ | 1,128 | $ | 1,902 | $ | 682 | |||||
| Less amounts allocated to participating securities | 2 | 6 | 2 | ||||||||
| Net income available to PPL common shareowners - Basic and Diluted | $ | 1,126 | $ | 1,896 | $ | 680 | |||||
(a)The Treasury Stock Method was applied to non-participating share-based payment awards.
| 2017 | 2016 | 2015 | |||||||||
| Shares of Common Stock (Denominator) | |||||||||||
| Weighted-average shares - Basic EPS | 685,240 | 677,592 | 669,814 | ||||||||
| Add incremental non-participating securities: | |||||||||||
| Share-based payment awards (a) | 2,094 | 2,854 | 2,772 | ||||||||
| Weighted-average shares - Diluted EPS | 687,334 | 680,446 | 672,586 | ||||||||
| Basic EPS | |||||||||||
| Available to PPL common shareowners: | |||||||||||
| Income from continuing operations after income taxes | $ | 1.64 | $ | 2.80 | $ | 2.38 | |||||
| Income (loss) from discontinued operations (net of income taxes) | — | — | (1.37 | ) | |||||||
| Net Income | $ | 1.64 | $ | 2.80 | $ | 1.01 | |||||
| Diluted EPS | |||||||||||
| Available to PPL common shareowners: | |||||||||||
| Income from continuing operations after income taxes | $ | 1.64 | $ | 2.79 | $ | 2.37 | |||||
| Income (loss) from discontinued operations (net of income taxes) | — | — | (1.36 | ) | |||||||
| Net Income | $ | 1.64 | $ | 2.79 | $ | 1.01 | |||||
For the yearyears ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousands):
| 2021 | 2020 | ||||||||||
| Stock-based compensation plans (a) | 983 | 731 | |||||||||
| DRIP | — | 943 | |||||||||
(a)Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive:
| 2017 | 2016 | 2015 | ||||||
| Stock options | 696 | 696 | 1,087 | |||||
| Performance units | — | 176 | 36 | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Stock-based compensation awards | 1,783 | 452 | 8 | ||||||||||||||
6. Income and Other Taxes
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Income tax expense (benefit) | $ | 321 | $ | (13 | ) | $ | 112 | $ | — | $ | — | ||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Income tax expense (benefit) | $ | 220 | $ | (13 | ) | $ | 112 | $ | — | $ | — | ||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| Net Increase in Regulatory Liabilities | $ | 2,185 | $ | 1,019 | $ | 1,166 | $ | 532 | $ | 634 | |||||||||
(PPL)
"Income (Loss) from Continuing Operations Before Income Taxes" included the following:is from domestic operations.
| 2017 | 2016 | 2015 | |||||||||
| Domestic income | $ | 874 | $ | 1,463 | $ | 968 | |||||
| Foreign income | 1,038 | 1,087 | 1,100 | ||||||||
| Total | $ | 1,912 | $ | 2,550 | $ | 2,068 | |||||
Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes and the tax effects of net operating loss and tax credit carryforwards. The provision for PPL's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles of the applicable jurisdiction. See Notes 1 and 67 for additional information.
Net deferred tax assets have been recognized based on management's estimates of future taxable income for the U.S. and the U.K.income.
Significant components of PPL's deferred income tax assets and liabilities were as follows:
| 2021 | 2020 | ||||||||||
| Deferred Tax Assets | |||||||||||
| Deferred investment tax credits | $ | 30 | $ | 30 | |||||||
| Regulatory liabilities | 94 | 68 | |||||||||
| Income taxes due to customers | 422 | 444 | |||||||||
| Accrued pension and postretirement costs | 75 | 106 | |||||||||
| Federal loss carryforwards (a) | — | 234 | |||||||||
| State loss carryforwards | 483 | 448 | |||||||||
| Federal and state tax credit carryforwards (a) | 15 | 401 | |||||||||
| Leases | 67 | 68 | |||||||||
| Contributions in aid of construction | 120 | 115 | |||||||||
| Other | 84 | 68 | |||||||||
| Valuation allowances | (462) | (536) | |||||||||
| Total deferred tax assets | 928 | 1,446 | |||||||||
| Deferred Tax Liabilities | |||||||||||
| Plant - net | 3,812 | 3,700 | |||||||||
| Regulatory assets | 180 | 195 | |||||||||
| Other | 75 | 70 | |||||||||
| Total deferred tax liabilities | 4,067 | 3,965 | |||||||||
| Net deferred tax liability | $ | 3,139 | $ | 2,519 | |||||||
(a)PPL utilized federal net operating losses of $1,115 million and tax credit carryforwards of $272 million in June 2021 as a result of the completion of the sale of the U.K. utility business on June 14, 2021. The related deferred tax assets decreased by approximately $506 million, with a corresponding reduction in current income taxes.
| 2017 (a) | 2016 | ||||||
| Deferred Tax Assets | |||||||
| Deferred investment tax credits | $ | 33 | $ | 51 | |||
| Regulatory liabilities | 62 | 94 | |||||
| Income taxes due to customer (b) | 499 | — | |||||
| Accrued pension costs | 159 | 250 | |||||
| Federal loss carryforwards | 356 | 565 | |||||
| State loss carryforwards | 409 | 326 | |||||
| Federal and state tax credit carryforwards | 455 | 256 | |||||
| Foreign capital loss carryforwards | 329 | 302 | |||||
| Foreign loss carryforwards | 2 | 3 | |||||
| Foreign - pensions | (32 | ) | 41 | ||||
| Foreign - regulatory obligations | 2 | 6 | |||||
| Foreign - other | 7 | 5 | |||||
| Contributions in aid of construction | 134 | 141 | |||||
| Domestic - other | 104 | 188 | |||||
| Unrealized losses on qualifying derivatives | 10 | 20 | |||||
| Valuation allowances | (838 | ) | (593 | ) | |||
| Total deferred tax assets | 1,691 | 1,655 | |||||
| Deferred Tax Liabilities | |||||||
| Domestic plant - net (b) | 3,168 | 4,325 | |||||
| Taxes recoverable through future rates (b) | — | 170 | |||||
| Regulatory assets | 211 | 343 | |||||
| Reacquired debt costs | 15 | 25 | |||||
| Foreign plant - net | 726 | 640 | |||||
| Domestic - other | 9 | 14 | |||||
| Total deferred tax liabilities | 4,129 | 5,517 | |||||
| Net deferred tax liability | $ | 2,438 | $ | 3,862 | |||
State deferred taxes are determined on a by entity and by jurisdiction basis.jurisdiction. As a result, $24$12 million and $27$17 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 20172021 and 2016.2020.
At December 31, 2017,2021, PPL had the following loss and tax credit carryforwards, related deferred tax assets and valuation allowances recorded against the deferred tax assets.assets:
| Gross | Deferred Tax Asset | Valuation Allowance | Expiration | ||||||||||||||||||||
| Loss and other carryforwards | |||||||||||||||||||||||
| State net operating losses | $ | 6,468 | $ | 483 | $ | (459) | 2022-2041 | ||||||||||||||||
| Gross | Deferred Tax Asset | Valuation Allowance | Expiration | ||||||||||
| Loss carryforwards | |||||||||||||
| Federal net operating losses (a) | $ | 1,662 | $ | 349 | $ | — | 2029-2037 | ||||||
| Federal charitable contributions (a) | 36 | 7 | — | 2020-2022 | |||||||||
| State net operating losses (a) | 5,512 | 407 | (348 | ) | 2018-2037 | ||||||||
| State charitable contributions (a) | 26 | 2 | — | 2018-2022 | |||||||||
| Foreign net operating losses | 10 | 2 | — | Indefinite | |||||||||
| Foreign capital losses | 1,938 | 329 | (329 | ) | Indefinite | ||||||||
| Credit carryforwards | |||||||||||||||||||||||
| State recycling credit | 14 | — | 2028 | ||||||||||||||||||||
| State - other | 1 | — | Indefinite | ||||||||||||||||||||
| Credit carryforwards | |||||||||
| Federal investment tax credit | 133 | — | 2025-2036 | ||||||
| Federal alternative minimum tax credit (b) | 30 | — | Indefinite | ||||||
| Federal foreign tax credits (c) | 267 | (148 | ) | 2024-2027 | |||||
| Federal - other | 24 | (8 | ) | 2019-2037 | |||||
| State - other | 1 | — | Indefinite | ||||||
Valuation allowances have been established for the amount that, more likely than not, will not be realized. The changes in deferred tax valuation allowances were as follows:
115
| Additions | |||||||||||||||||||
Balance at Beginning of Period | Charged to Income | Charged to Other Accounts | Deductions | Balance at End of Period | |||||||||||||||
| 2017 | $ | 593 | $ | 256 | (a) | $ | — | $ | 11 | $ | 838 | ||||||||
| 2016 | 662 | 17 | 2 | 88 | (b) | 593 | |||||||||||||
| 2015 | 622 | 24 | 77 | (c) | 61 | (b) | 662 | ||||||||||||
| Additions | |||||||||||||||||||||||||||||
| Balance at Beginning of Period | Charged to Income | Charged to Other Accounts | Deductions | Balance at End of Period | |||||||||||||||||||||||||
| 2021 | $ | 536 | $ | 48 | (a) | $ | — | $ | 122 | (b) | $ | 462 | |||||||||||||||||
| 2020 | 514 | 26 | — | 4 | 536 | ||||||||||||||||||||||||
| 2019 | 495 | 24 | — | 5 | 514 | ||||||||||||||||||||||||
(a)In addition, the reduction of the U.S. federal corporate income tax rate enacted by the TCJA in 2017 resulted in2021, PPL recorded a $62$31 million increase in federal deferred tax assets and a corresponding valuation allowance related to the federal tax benefits ofon a state net operating losses.
(b)In light of the disposition of PPL's U.K. utility business, there was a decrease in the valuation allowance of approximately $113 million.
A U.S. based company with foreign subsidiaries may be required to record deferred taxes associated with the differences in the outside book-tax basis of those subsidiaries. The primary component of such outside basis differences is ordinarily accumulated unremitted earnings. In anticipation of the WPD sale, indefinite reinvestment of accumulated unremitted earnings of WPD as management has determined that such earnings are indefinitely reinvested. Current year distributions from WPD towas no longer relevant and, in the U.S. are sourced fromfirst quarter of 2021, PPL recorded a portiondeferred tax liability reflecting the expected tax cost associated with the realization of the current year’s earningsoutside book-tax basis difference in the investment in WPD. In the second quarter of 2021, following completion of the WPD group. As noted above, the TCJA includes a conversion from a worldwide tax system to a territorial tax system, effective January 1, 2018. In the transition to the territorial regime, a one-time transitionsale, that deferred tax was imposed on PPL’s unrepatriated accumulated foreign earnings in 2017. These earnings were treated as a taxable deemed dividend from the U.K. The total amount of the taxable deemed dividend was approximately $462 million, including $205 million of foreignrecorded to current tax credits. The U.S. tax consequences of the deemed dividend have been recorded in PPL’s 2017 tax provision and are explained below. Despite this 2017 deemed dividend, there have been no material changes to the facts underlying PPL’s assertion that historically reinvested earnings of WPD as well as some portion of current year earnings will continue to be indefinitely reinvested. WPD's long-term working capital forecasts and capital expenditure projections for the foreseeable future require reinvestment of WPD's undistributed earnings. Additionally, U.S. long-term working capital forecasts and capital expenditure projections for the foreseeable future do not require or contemplate annual distributions from WPD in excess of some portion of WPD's future annual earnings. The cumulative undistributed earnings are included in "Earnings reinvested" on the Balance Sheets. The amount considered indefinitely reinvested at December 31, 2017 was $6.0 billion. It is not practicable to estimate the amount of additional taxes that could be payable on these foreign earnings in the event of repatriation to the U.S.expense.
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income from Continuing Operations Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Income Tax Expense (Benefit) | |||||||||||||||||
| Current - Federal | $ | (1) | $ | (8) | $ | (10) | |||||||||||
| Current - State | 36 | 24 | 19 | ||||||||||||||
| Current - Foreign | (1) | (2) | — | ||||||||||||||
| Total Current Expense (Benefit) | 34 | 14 | 9 | ||||||||||||||
| Deferred - Federal | 28 | 135 | 141 | ||||||||||||||
| Deferred - State | 105 | 94 | 76 | ||||||||||||||
| Deferred - Foreign (a) | 383 | 101 | (14) | ||||||||||||||
| Total Deferred Expense (Benefit), excluding operating loss carryforwards | 516 | 330 | 203 | ||||||||||||||
| Amortization of investment tax credit | (3) | (3) | (3) | ||||||||||||||
| Tax expense (benefit) of operating loss carryforwards | |||||||||||||||||
| Deferred - Federal | 12 | 6 | 7 | ||||||||||||||
| Deferred - State | (56) | (33) | (33) | ||||||||||||||
| Total Tax Expense (Benefit) of Operating Loss Carryforwards | (44) | (27) | (26) | ||||||||||||||
| Total income tax expense (benefit) | $ | 503 | $ | 314 | $ | 183 | |||||||||||
| Total income tax expense (benefit) - Federal | $ | 36 | $ | 130 | $ | 135 | |||||||||||
| Total income tax expense (benefit) - State | 85 | 85 | 62 | ||||||||||||||
| Total income tax expense (benefit) - Foreign | 382 | 99 | (14) | ||||||||||||||
| Total income tax expense (benefit) | $ | 503 | $ | 314 | $ | 183 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Current - Federal | $ | 6 | $ | (14 | ) | $ | (26 | ) | |||
| Current - State | 25 | 21 | 25 | ||||||||
| Current - Foreign | 45 | 80 | 89 | ||||||||
| Total Current Expense | 76 | 87 | 88 | ||||||||
| Deferred - Federal (a) | 532 | 385 | 699 | ||||||||
| Deferred - State | 88 | 89 | 68 | ||||||||
| Deferred - Foreign | 133 | 86 | 41 | ||||||||
| Total Deferred Expense, excluding operating loss carryforwards | 753 | 560 | 808 | ||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Amortization of investment tax credit | (3 | ) | (3 | ) | (4 | ) | |||||
| Tax expense (benefit) of operating loss carryforwards | |||||||||||
| Deferred - Federal (b) | (16 | ) | 25 | (396 | ) | ||||||
| Deferred - State | (26 | ) | (21 | ) | (31 | ) | |||||
| Total Tax Expense (Benefit) of Operating Loss Carryforwards | (42 | ) | 4 | (427 | ) | ||||||
| Total income taxes from continuing operations | $ | 784 | $ | 648 | $ | 465 | |||||
| Total income tax expense - Federal | $ | 519 | $ | 393 | $ | 273 | |||||
| Total income tax expense - State | 87 | 89 | 62 | ||||||||
| Total income tax expense - Foreign | 178 | 166 | 130 | ||||||||
| Total income taxes from continuing operations | $ | 784 | $ | 648 | $ | 465 | |||||
In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction from 35%19% to 21% on17%. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax assetsliabilities and liabilities;
In the table above, the following income tax expense (benefit) are excluded from income taxes from continuing operations:taxes:
| 2021 | 2020 | 2019 | |||||||||||||||
| Discontinued operations - PPL U.K. utility business | $ | 759 | $ | 188 | $ | 226 | |||||||||||
| Reclassification from AOCI due to sale of UK utility business | 660 | — | — | ||||||||||||||
| Other comprehensive income | 150 | (19) | (93) | ||||||||||||||
| Total | $ | 1,569 | $ | 169 | $ | 133 | |||||||||||
116
| 2017 | 2016 | 2015 | |||||||||
| Discontinued operations - PPL Energy Supply Segment | $ | — | $ | — | $ | (30 | ) | ||||
| Stock-based compensation recorded to Earnings Reinvested | — | (7 | ) | — | |||||||
| Other comprehensive income | (34 | ) | (6 | ) | (2 | ) | |||||
| Valuation allowance on state deferred taxes recorded to other comprehensive income | (1 | ) | 1 | (4 | ) | ||||||
| Total | $ | (35 | ) | $ | (12 | ) | $ | (36 | ) | ||
| 2021 | 2020 | 2019 | |||||||||||||||
| Reconciliation of Income Tax Expense (Benefit) | |||||||||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 109 | $ | 200 | $ | 193 | |||||||||||
| State income taxes, net of federal income tax benefit | 23 | 48 | 45 | ||||||||||||||
| Valuation allowance adjustments (a) | 48 | 24 | 22 | ||||||||||||||
| Federal and state income tax return adjustments | (3) | (9) | 1 | ||||||||||||||
| Impact of the U.K. Finance Acts on deferred tax balances (b) | 383 | 101 | (14) | ||||||||||||||
| Depreciation and other items not normalized | (5) | (5) | (10) | ||||||||||||||
| Amortization of excess deferred federal and state income taxes | (54) | (43) | (40) | ||||||||||||||
| Non-deductible officer's salary | 6 | 7 | 4 | ||||||||||||||
| Kentucky recycling credit, net of federal income tax expense (c) | — | — | (18) | ||||||||||||||
| Other | (4) | (9) | — | ||||||||||||||
| Total increase (decrease) | 394 | 114 | (10) | ||||||||||||||
| Total income tax expense (benefit) | $ | 503 | $ | 314 | $ | 183 | |||||||||||
| Effective income tax rate | 96.5% | 32.9% | 19.9% | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Reconciliation of Income Tax Expense | |||||||||||
| Federal income tax on Income from Continuing Operations Before Income Taxes at statutory tax rate - 35% | $ | 669 | $ | 893 | $ | 724 | |||||
| Increase (decrease) due to: | |||||||||||
| State income taxes, net of federal income tax benefit | 46 | 46 | 31 | ||||||||
| Valuation allowance adjustments (a) | 36 | 16 | 24 | ||||||||
| Impact of lower U.K. income tax rates (b) | (176 | ) | (177 | ) | (176 | ) | |||||
| U.S. income tax on foreign earnings - net of foreign tax credit (c) | 47 | (42 | ) | 8 | |||||||
| Federal and state tax reserves adjustments (d) | — | — | (22 | ) | |||||||
| Foreign income return adjustments | (8 | ) | 2 | — | |||||||
| Impact of the U.K. Finance Acts on deferred tax balances (b) | (16 | ) | (49 | ) | (91 | ) | |||||
| Depreciation not normalized | (10 | ) | (10 | ) | (5 | ) | |||||
| Interest benefit on U.K. financing entities | (16 | ) | (17 | ) | (20 | ) | |||||
| Stock-based compensation (e) | (3 | ) | (10 | ) | — | ||||||
| Deferred tax impact of U.S. tax reform (f) | 220 | — | — | ||||||||
| Other | (5 | ) | (4 | ) | (8 | ) | |||||
| Total increase (decrease) | 115 | (245 | ) | (259 | ) | ||||||
| Total income taxes from continuing operations | $ | 784 | $ | 648 | $ | 465 | |||||
| Effective income tax rate | 41.0 | % | 25.4 | % | 22.5 | % | |||||
In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in the second quarter of 2021.
(c)In 2019, LG&E recorded a $90 million deferred income tax benefit during 2015, related to both rate decreases.
| 2021 | 2020 | 2019 | |||||||||||||||
| Taxes, other than income | |||||||||||||||||
| State gross receipts | $ | 113 | $ | 100 | $ | 107 | |||||||||||
| Domestic - other | 94 | 80 | 79 | ||||||||||||||
| Total | $ | 207 | $ | 180 | $ | 186 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Taxes, other than income | |||||||||||
| State gross receipts (a) | $ | 102 | $ | 100 | $ | 89 | |||||
| State capital stock | (6 | ) | — | — | |||||||
| Foreign property | 127 | 135 | 148 | ||||||||
| Domestic Other | 69 | 66 | 62 | ||||||||
| Total | $ | 292 | $ | 301 | $ | 299 | |||||
(PPL Electric)
The provision for PPL Electric's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the PUC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets.
Significant components of PPL Electric's deferred income tax assets and liabilities were as follows:
117
| 2017 (a) | 2016 | 2021 | 2020 | |||||||||||||||
| Deferred Tax Assets | Deferred Tax Assets | |||||||||||||||||
| Accrued pension costs | $ | 63 | $ | 107 | ||||||||||||||
| Accrued pension and postretirement costs | Accrued pension and postretirement costs | $ | 14 | $ | 25 | |||||||||||||
| Contributions in aid of construction | 117 | 112 | Contributions in aid of construction | 95 | 91 | |||||||||||||
| Regulatory liabilities | 25 | 34 | Regulatory liabilities | 52 | 24 | |||||||||||||
| Income taxes due to customers (b) | 193 | — | ||||||||||||||||
| State loss carryforwards | 19 | 22 | ||||||||||||||||
| Income taxes due to customers | Income taxes due to customers | 154 | 162 | |||||||||||||||
| Federal loss carryforwards | 91 | 147 | — | 52 | ||||||||||||||
| Other | 45 | 81 | Other | 21 | 29 | |||||||||||||
| Total deferred tax assets | 553 | 503 | Total deferred tax assets | 336 | 383 | |||||||||||||
| Deferred Tax Liabilities | Deferred Tax Liabilities | |||||||||||||||||
| Electric utility plant - net (b) | 1,544 | 2,001 | ||||||||||||||||
| Taxes recoverable through future rates (b) | — | 141 | ||||||||||||||||
| Reacquired debt costs | 8 | 15 | ||||||||||||||||
| Electric utility plant - net | Electric utility plant - net | 1,891 | 1,826 | |||||||||||||||
| Regulatory assets | 150 | 240 | Regulatory assets | 74 | 86 | |||||||||||||
| Other | 5 | 5 | Other | 39 | 30 | |||||||||||||
| Total deferred tax liabilities | 1,707 | 2,402 | Total deferred tax liabilities | 2,004 | 1,942 | |||||||||||||
| Net deferred tax liability | $ | 1,154 | $ | 1,899 | Net deferred tax liability | $ | 1,668 | $ | 1,559 | |||||||||
| Gross | Deferred Tax Asset | Expiration | |||||||
| Loss carryforwards (a) | |||||||||
| Federal net operating losses | $ | 426 | $ | 89 | 2031-2037 | ||||
| Federal charitable contributions | 8 | 2 | 2020-2022 | ||||||
| State net operating losses | 233 | 18 | 2030-2032 | ||||||
| State charitable contributions | 13 | 1 | 2018-2022 | ||||||
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows.follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Income Tax Expense (Benefit) | |||||||||||||||||
| Current - Federal | $ | 40 | $ | 61 | $ | 44 | |||||||||||
| Current - State | 35 | 23 | 15 | ||||||||||||||
| Total Current Expense (Benefit) | 75 | 84 | 59 | ||||||||||||||
| Deferred - Federal | 59 | 45 | 51 | ||||||||||||||
| Deferred - State | 20 | 38 | 39 | ||||||||||||||
| Total Deferred Expense (Benefit), excluding operating loss carryforwards | 79 | 83 | 90 | ||||||||||||||
| Total income tax expense (benefit) | $ | 154 | $ | 167 | $ | 149 | |||||||||||
| Total income tax expense (benefit) - Federal | $ | 99 | $ | 106 | $ | 95 | |||||||||||
| Total income tax expense (benefit) - State | 55 | 61 | 54 | ||||||||||||||
| Total income tax expense (benefit) | $ | 154 | $ | 167 | $ | 149 | |||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Reconciliation of Income Tax Expense (Benefit) | |||||||||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 126 | $ | 139 | $ | 127 | |||||||||||
| Increase (decrease) due to: | |||||||||||||||||
| State income taxes, net of federal income tax benefit | 46 | 52 | 47 | ||||||||||||||
| Federal and state income tax return adjustments | — | (4) | 1 | ||||||||||||||
| Depreciation and other items not normalized | (5) | (5) | (10) | ||||||||||||||
| Amortization of excess deferred federal income taxes (a) | (14) | (16) | (18) | ||||||||||||||
| Other | 1 | 1 | 2 | ||||||||||||||
| Total increase (decrease) | 28 | 28 | 22 | ||||||||||||||
| Total income tax expense (benefit) | $ | 154 | $ | 167 | $ | 149 | |||||||||||
| Effective income tax rate | 25.7% | 25.2% | 24.6% | ||||||||||||||
(a)In 2021, 2020 and 2019, PPL Electric recorded lower income tax expense for the amortization of excess deferred taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. This amortization represents each year's refund amount, prior to a tax gross-up, to be paid to customers for previously collected deferred taxes at higher income tax rates.
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Current - Federal | $ | (65 | ) | $ | (29 | ) | $ | (80 | ) | ||
| Current - State | 20 | 19 | 23 | ||||||||
| Total Current Expense (Benefit) | (45 | ) | (10 | ) | (57 | ) | |||||
| Deferred - Federal (a) | 234 | 193 | 287 | ||||||||
| Deferred - State | 29 | 29 | 12 | ||||||||
| Total Deferred Expense, excluding operating loss carryforwards | 263 | 222 | 299 | ||||||||
| 2017 | 2016 | 2015 | |||||||||
| Amortization of investment tax credit | — | — | — | ||||||||
| Tax expense (benefit) of operating loss carryforwards | |||||||||||
| Deferred - Federal | (5 | ) | — | (75 | ) | ||||||
| Deferred - State | — | — | (3 | ) | |||||||
| Total Tax Expense (Benefit) of Operating Loss Carryforwards | (5 | ) | — | (78 | ) | ||||||
| Total income tax expense | $ | 213 | $ | 212 | $ | 164 | |||||
| Total income tax expense - Federal | $ | 164 | $ | 164 | $ | 132 | |||||
| Total income tax expense - State | 49 | 48 | 32 | ||||||||
| Total income tax expense | $ | 213 | $ | 212 | $ | 164 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Reconciliation of Income Taxes | |||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 35% | $ | 201 | $ | 193 | $ | 146 | |||||
| Increase (decrease) due to: | |||||||||||
| State income taxes, net of federal income tax benefit | 36 | 36 | 25 | ||||||||
| Depreciation not normalized | (8 | ) | (8 | ) | (4 | ) | |||||
| Stock-based compensation (a) | (2 | ) | (6 | ) | — | ||||||
| Deferred tax impact of U.S. tax reform (b) | (13 | ) | — | — | |||||||
| Other | (1 | ) | (3 | ) | (3 | ) | |||||
| Total increase (decrease) | 12 | 19 | 18 | ||||||||
| Total income tax expense | $ | 213 | $ | 212 | $ | 164 | |||||
| Effective income tax rate | 37.0 | % | 38.4 | % | 39.4 | % | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Taxes, other than income | |||||||||||||||||
| State gross receipts | $ | 113 | $ | 100 | $ | 107 | |||||||||||
| Property and other | 7 | 7 | 5 | ||||||||||||||
| Total | $ | 120 | $ | 107 | $ | 112 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Taxes, other than income | |||||||||||
| State gross receipts (a) | $ | 102 | $ | 100 | $ | 89 | |||||
| Property and other | 5 | 5 | 5 | ||||||||
| Total | $ | 107 | $ | 105 | $ | 94 | |||||
| 2017 (a) | 2016 | ||||||
| Deferred Tax Assets | |||||||
| Federal loss carryforwards | $ | 150 | $ | 248 | |||
| State loss carryforwards | 41 | 35 | |||||
| Federal tax credit carryforwards | 181 | 186 | |||||
| Contributions in aid of construction | 17 | 29 | |||||
| Regulatory liabilities | 37 | 60 | |||||
| Accrued pension costs | 29 | 58 | |||||
| Income taxes due to customers (b) | 305 | 15 | |||||
| Deferred investment tax credits | 33 | 51 | |||||
| Derivative liability | 7 | 12 | |||||
| Other | 26 | 49 | |||||
| Valuation allowances | (8 | ) | (11 | ) | |||
| Total deferred tax assets | 818 | 732 | |||||
| Deferred Tax Liabilities | |||||||
| Plant - net (b) | 1,615 | 2,352 | |||||
| Regulatory assets | 61 | 102 | |||||
| Other | 8 | 13 | |||||
| Total deferred tax liabilities | 1,684 | 2,467 | |||||
| Net deferred tax liability | $ | 866 | $ | 1,735 | |||
| Gross | Deferred Tax Asset | Valuation Allowance | Expiration | ||||||||||
| Loss carryforwards (a) | |||||||||||||
| Federal net operating losses | $ | 713 | $ | 150 | $ | — | 2028-2037 | ||||||
| Federal charitable contributions | 14 | 3 | — | 2020-2022 | |||||||||
| State net operating losses | 874 | 41 | — | 2028-2037 | |||||||||
| Credit carryforwards | |||||||||
| Federal investment tax credit | 133 | — | 2025-2036 | ||||||
| Federal alternative minimum tax credit (b) | 27 | — | Indefinite | ||||||
| Federal - other | 21 | (8 | ) | 2019-2037 | |||||
| State - other | 1 | — | Indefinite | ||||||
Balance at Beginning of Period | Additions | Deductions | Balance at End of Period | ||||||||||||
| 2017 | $ | 11 | $ | 4 | (a) | $ | 7 | (b) | $ | 8 | |||||
| 2016 | 12 | — | 1 | (b) | 11 | ||||||||||
| 2015 | — | 12 | (c) | — | 12 | ||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Current - Federal | $ | 74 | $ | (36 | ) | $ | 2 | ||||
| Current - State | 6 | 1 | 1 | ||||||||
| Total Current Expense (Benefit) | 80 | (35 | ) | 3 | |||||||
| Deferred - Federal (a) | 268 | 248 | 405 | ||||||||
| Deferred - State | 32 | 38 | 32 | ||||||||
| Total Deferred Expense, excluding benefits of operating loss carryforwards | 300 | 286 | 437 | ||||||||
| Amortization of investment tax credit - Federal | (3 | ) | (3 | ) | (3 | ) | |||||
| Tax benefit of operating loss carryforwards | |||||||||||
| Deferred - Federal | (2 | ) | 10 | (198 | ) | ||||||
| Deferred - State | — | (1 | ) | — | |||||||
| Total Tax Expense (Benefit) of Operating Loss Carryforwards | (2 | ) | 9 | (198 | ) | ||||||
| Total income tax expense from continuing operations (b) | $ | 375 | $ | 257 | $ | 239 | |||||
| Total income tax expense - Federal | $ | 337 | $ | 219 | $ | 206 | |||||
| Total income tax expense - State | 38 | 38 | 33 | ||||||||
| Total income tax expense from continuing operations (b) | $ | 375 | $ | 257 | $ | 239 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Reconciliation of Income Taxes | |||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 35% | $ | 242 | $ | 240 | $ | 211 | |||||
| Increase (decrease) due to: | |||||||||||
| State income taxes, net of federal income tax benefit | 25 | 25 | 22 | ||||||||
| Amortization of investment tax credit | (3 | ) | (3 | ) | (3 | ) | |||||
| Valuation allowance adjustment (a) | — | — | 12 | ||||||||
| Stock-based compensation (b) | 1 | (3 | ) | — | |||||||
| Deferred tax impact of U.S. tax reform (c) | 112 | — | — | ||||||||
| Other | (2 | ) | (2 | ) | (3 | ) | |||||
| Total increase | 133 | 17 | 28 | ||||||||
| Total income tax expense | $ | 375 | $ | 257 | $ | 239 | |||||
| Effective income tax rate | 54.3 | % | 37.5 | % | 39.6 | % | |||||
| 2017 | 2016 | 2015 | |||||||||
| Taxes, other than income | |||||||||||
| Property and other | $ | 65 | $ | 62 | $ | 57 | |||||
| Total | $ | 65 | $ | 62 | $ | 57 | |||||
(LG&E)
The provision for LG&E's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets.
Significant components of LG&E's deferred income tax assets and liabilities were as follows:
| 2021 | 2020 | ||||||||||
| Deferred Tax Assets | |||||||||||
| Contributions in aid of construction | $ | 15 | $ | 15 | |||||||
| Regulatory liabilities | 18 | 20 | |||||||||
| Deferred investment tax credits | 8 | 8 | |||||||||
| Income taxes due to customers | 125 | 132 | |||||||||
| State tax credit carryforwards | 11 | 12 | |||||||||
| Lease liabilities | 4 | 5 | |||||||||
| Valuation allowances | (11) | (12) | |||||||||
| Other | 11 | 11 | |||||||||
| Total deferred tax assets | 181 | 191 | |||||||||
| Deferred Tax Liabilities | |||||||||||
| Plant - net | 854 | 833 | |||||||||
| Regulatory assets | 65 | 66 | |||||||||
| Lease right-of-use assets | 4 | 4 | |||||||||
| Other | 9 | 4 | |||||||||
| Total deferred tax liabilities | 932 | 907 | |||||||||
| Net deferred tax liability | $ | 751 | $ | 716 | |||||||
| 2017 (a) | 2016 | ||||||
| Deferred Tax Assets | |||||||
| Federal loss carryforwards | $ | 29 | $ | 80 | |||
| Contributions in aid of construction | 11 | 18 | |||||
| Regulatory liabilities | 21 | 34 | |||||
| Deferred investment tax credits | 9 | 14 | |||||
| Income taxes due to customers (b) | 142 | 17 | |||||
| Derivative liability | 7 | 12 | |||||
| Other | 12 | 17 | |||||
| Total deferred tax assets | 231 | 192 | |||||
| Deferred Tax Liabilities | |||||||
| Plant - net (b) | 724 | 1,058 | |||||
| Regulatory assets | 40 | 65 | |||||
| Accrued pension costs | 34 | 35 | |||||
| Other | 5 | 8 | |||||
| Total deferred tax liabilities | 803 | 1,166 | |||||
| Net deferred tax liability | $ | 572 | $ | 974 | |||
At December 31, 2017,2021 LG&E had $140$11 million of federal net operating lossstate credit carryforwards that expire in 20352028 and $6an $11 million of federalvaluation allowance related to state credit carryforwards that expire from 2034due to 2037.insufficient projected Kentucky taxable income.
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
| 2021 | 2020 | 2019 | |||||||||||||||
| Income Tax Expense (Benefit) | |||||||||||||||||
| Current - Federal | $ | 41 | $ | 53 | $ | 4 | |||||||||||
| Current - State | 5 | 7 | 4 | ||||||||||||||
| Total Current Expense (Benefit) | 46 | 60 | 8 | ||||||||||||||
| Deferred - Federal | 1 | (4) | 46 | ||||||||||||||
| Deferred - State | 8 | 7 | 10 | ||||||||||||||
| Total Deferred Expense (Benefit) | 9 | 3 | 56 | ||||||||||||||
| Amortization of investment tax credit - Federal | (1) | (1) | (1) | ||||||||||||||
| Total income tax expense (benefit) | $ | 54 | $ | 62 | $ | 63 | |||||||||||
| Total income tax expense (benefit) - Federal | $ | 41 | $ | 48 | $ | 49 | |||||||||||
| Total income tax expense (benefit) - State | 13 | 14 | 14 | ||||||||||||||
| Total income tax expense (benefit) | $ | 54 | $ | 62 | $ | 63 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Current - Federal | $ | — | $ | (22 | ) | $ | (15 | ) | |||
| Current - State | 5 | 1 | 3 | ||||||||
| Total current Expense (Benefit) | 5 | (21 | ) | (12 | ) | ||||||
| Deferred - Federal | 112 | 134 | 190 | ||||||||
| Deferred - State | 14 | 18 | 13 | ||||||||
| Total Deferred Expense, excluding benefits of operating loss carryforwards | 126 | 152 | 203 | ||||||||
| Amortization of investment tax credit - Federal | (1 | ) | (1 | ) | (1 | ) | |||||
| Tax benefit of operating loss carryforwards | |||||||||||
| Deferred - Federal | 1 | (4 | ) | (76 | ) | ||||||
| Total Tax Benefit of Operating Loss Carryforwards | 1 | (4 | ) | (76 | ) | ||||||
| Total income tax expense | $ | 131 | $ | 126 | $ | 114 | |||||
| Total income tax expense - Federal | $ | 112 | $ | 107 | $ | 98 | |||||
| Total income tax expense - State | 19 | 19 | 16 | ||||||||
| Total income tax expense | $ | 131 | $ | 126 | $ | 114 | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Reconciliation of Income Tax Expense (Benefit) | |||||||||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 64 | $ | 64 | $ | 62 | |||||||||||
| Increase (decrease) due to: | |||||||||||||||||
| State income taxes, net of federal income tax benefit | 12 | 12 | 12 | ||||||||||||||
| Amortization of excess deferred federal and state income taxes | (20) | (11) | (10) | ||||||||||||||
| Kentucky recycling credit, net of federal income tax expense (a) | — | — | (14) | ||||||||||||||
| Valuation allowance adjustments (a) | — | — | 14 | ||||||||||||||
| Other | (2) | (3) | (1) | ||||||||||||||
| Total increase (decrease) | (10) | (2) | 1 | ||||||||||||||
| Total income tax expense (benefit) | $ | 54 | $ | 62 | $ | 63 | |||||||||||
| Effective income tax rate | 17.8% | 20.3% | 21.4% | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Reconciliation of Income Taxes | |||||||||||
| Federal income tax on Income Before Income Taxes at | |||||||||||
| statutory tax rate - 35% | $ | 120 | $ | 115 | $ | 105 | |||||
| Increase (decrease) due to: | |||||||||||
| State income taxes, net of federal income tax benefit | 13 | 12 | 11 | ||||||||
| Amortization of investment tax credit | (1 | ) | (1 | ) | (1 | ) | |||||
| Other | (1 | ) | — | (1 | ) | ||||||
| Total increase | 11 | 11 | 9 | ||||||||
| Total income tax expense | $ | 131 | $ | 126 | $ | 114 | |||||
| Effective income tax rate | 38.1 | % | 38.3 | % | 38.1 | % | |||||
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Taxes, other than income | Taxes, other than income | |||||||||||||||||||||||||||
| Property and other | $ | 33 | $ | 32 | $ | 28 | Property and other | $ | 46 | $ | 40 | $ | 39 | |||||||||||||||
| Total | $ | 33 | $ | 32 | $ | 28 | Total | $ | 46 | $ | 40 | $ | 39 | |||||||||||||||
(KU)
The provision for KU's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC, VSCC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets.
Significant components of KU's deferred income tax assets and liabilities were as follows:
| 2021 | 2020 | ||||||||||
| Deferred Tax Assets | |||||||||||
| Contributions in aid of construction | $ | 9 | $ | 8 | |||||||
| Regulatory liabilities | 23 | 23 | |||||||||
| Deferred investment tax credits | 22 | 22 | |||||||||
| Income taxes due to customers | 143 | 150 | |||||||||
| State tax credit carryforwards | 4 | 5 | |||||||||
| Lease liabilities | 7 | 8 | |||||||||
| Valuation allowances | (3) | (4) | |||||||||
| Other | 4 | 4 | |||||||||
| Total deferred tax assets | 209 | 216 | |||||||||
| Deferred Tax Liabilities | |||||||||||
| Plant - net | 1,012 | 992 | |||||||||
| Regulatory assets | 41 | 43 | |||||||||
| Pension and postretirement costs | 13 | 8 | |||||||||
| Lease right-of-use assets | 6 | 7 | |||||||||
| Other | 2 | 1 | |||||||||
| Total deferred tax liabilities | 1,074 | 1,051 | |||||||||
| Net deferred tax liability | $ | 865 | $ | 835 | |||||||
| 2017 (a) | 2016 | ||||||
| Deferred Tax Assets | |||||||
| Federal loss carryforwards | $ | 13 | $ | 79 | |||
| Contributions in aid of construction | 6 | 11 | |||||
| Regulatory liabilities | 16 | 26 | |||||
| Deferred investment tax credits | 24 | 37 | |||||
| Income taxes due to customers (b) | 163 | — | |||||
| Other | 9 | 11 | |||||
| Total deferred tax assets | 231 | 164 | |||||
| Deferred Tax Liabilities | |||||||
| Plant - net (b) | 882 | 1,280 | |||||
| Regulatory assets | 21 | 37 | |||||
| Accrued pension costs | 17 | 12 | |||||
| Other | 2 | 5 | |||||
| Total deferred tax liabilities | 922 | 1,334 | |||||
| Net deferred tax liability | $ | 691 | $ | 1,170 | |||
At December 31, 2021KU expects to have adequate levelshad $4 million of taxable income to realize its recorded deferred income tax assets.
state credit carryforwards of which $3 million will expire in 2028 and $1 million that has an indefinite carryforward period. At December 31, 2017,2021 KU had $61a $3 million of federal net operating loss carryforwards that expire in 2035 and $6 million of federalvaluation allowance related to state credit carryforwards that expire from 2034due to 2037.insufficient projected Kentucky taxable income.
Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were:
| 2021 | 2020 | 2019 | |||||||||||||||
| Income Tax Expense (Benefit) | |||||||||||||||||
| Current - Federal | $ | 58 | $ | 40 | $ | 35 | |||||||||||
| Current - State | 8 | 3 | 5 | ||||||||||||||
| Total Current Expense (Benefit) | 66 | 43 | 40 | ||||||||||||||
| Deferred - Federal | (4) | 11 | 28 | ||||||||||||||
| Deferred - State | 7 | 11 | 13 | ||||||||||||||
| Total Deferred Expense (Benefit) | 3 | 22 | 41 | ||||||||||||||
| Amortization of investment tax credit - Federal | (2) | (2) | (2) | ||||||||||||||
| Total income tax expense (benefit) | $ | 67 | $ | 63 | $ | 79 | |||||||||||
| Total income tax expense (benefit) - Federal | $ | 52 | $ | 49 | $ | 61 | |||||||||||
| Total income tax expense (benefit) - State | 15 | 14 | 18 | ||||||||||||||
| Total income tax expense (benefit) | $ | 67 | $ | 63 | $ | 79 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Income Tax Expense (Benefit) | |||||||||||
| Current - Federal | $ | — | $ | 31 | $ | (21 | ) | ||||
| Current - State | 7 | 5 | 1 | ||||||||
| Total Current Expense (Benefit) | 7 | 36 | (20 | ) | |||||||
| Deferred - Federal | 138 | 131 | 240 | ||||||||
| Deferred - State | 16 | 19 | 19 | ||||||||
| Total Deferred Expense, excluding benefits of operating loss carryforwards | 154 | 150 | 259 | ||||||||
| Amortization of investment tax credit - Federal | (2 | ) | (2 | ) | (2 | ) | |||||
| Tax benefit of operating loss carryforwards | |||||||||||
| Deferred - Federal | — | (21 | ) | (97 | ) | ||||||
| Total Tax Benefit of Operating Loss Carryforwards | — | (21 | ) | (97 | ) | ||||||
| Total income tax expense (a) | $ | 159 | $ | 163 | $ | 140 | |||||
| Total income tax expense - Federal | $ | 136 | $ | 139 | $ | 120 | |||||
| Total income tax expense - State | 23 | 24 | 20 | ||||||||
| Total income tax expense (a) | $ | 159 | $ | 163 | $ | 140 | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Reconciliation of Income Tax Expense (Benefit) | |||||||||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 21% | $ | 76 | $ | 72 | $ | 78 | |||||||||||
| Increase (decrease) due to: | |||||||||||||||||
| State income taxes, net of federal income tax benefit | 14 | 14 | 15 | ||||||||||||||
| Amortization of investment tax credit | (2) | (2) | (2) | ||||||||||||||
| Amortization of excess deferred federal and state income taxes | (20) | (17) | (13) | ||||||||||||||
| Kentucky recycling credit, net of federal income tax expense (a) | — | — | (4) | ||||||||||||||
| Valuation allowance adjustments (a) | — | — | 4 | ||||||||||||||
| Other | (1) | (4) | 1 | ||||||||||||||
| Total increase (decrease) | (9) | (9) | 1 | ||||||||||||||
| Total income tax expense (benefit) | $ | 67 | $ | 63 | $ | 79 | |||||||||||
| Effective income tax rate | 18.4% | 18.4% | 21.2% | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Reconciliation of Income Taxes | |||||||||||
| Federal income tax on Income Before Income Taxes at statutory tax rate - 35% | $ | 146 | $ | 150 | $ | 131 | |||||
| Increase (decrease) due to: | |||||||||||
| State income taxes, net of federal income tax benefit | 15 | 16 | 13 | ||||||||
| Amortization of investment tax credit | (2 | ) | (2 | ) | (2 | ) | |||||
| Other | — | (1 | ) | (2 | ) | ||||||
| Total increase | 13 | 13 | 9 | ||||||||
| Total income tax expense | $ | 159 | $ | 163 | $ | 140 | |||||
| Effective income tax rate | 38.0 | % | 38.1 | % | 37.4 | % | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Taxes, other than income | |||||||||||||||||
| Property and other | $ | 41 | $ | 37 | $ | 35 | |||||||||||
| Total | $ | 41 | $ | 37 | $ | 35 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Taxes, other than income | |||||||||||
| Property and other | $ | 32 | $ | 30 | $ | 29 | |||||
| Total | $ | 32 | $ | 30 | $ | 29 | |||||
(All Registrants)
Unrecognized Tax Benefits(All Registrants)
PPL or its subsidiaries file tax returns in four4 major tax jurisdictions. The income tax provisions for PPL Electric, LG&E and KU are calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if each domestic subsidiary filed a separate consolidated return. Based on this tax sharing agreement, PPL Electric or its subsidiaries indirectly or directly file tax returns in two2 major tax jurisdictions, and LKE, LG&E and KU or their subsidiaries indirectly or directly file tax returns in two2 major tax jurisdictions. With few exceptions, at December 31, 2017,2021, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows.
| PPL | PPL Electric | KU | |||||||||||||||||||||||
| U.S. (federal) | |||||||||||||||||||||||||
| Pennsylvania (state) | |||||||||||||||||||||||||
| Kentucky (state) | |||||||||||||||||||||||||
| 2014 and prior | 2014 and prior | 2014 and prior | |||||||||||||||||||||||
| U.K. (foreign) | 2019 and prior | ||||||||||||||||||||||||
Regulatory Assets and Liabilities
(All Registrants)
PPL, PPL Electric, LKE, LG&E and KU reflect the effects of regulatory actions in the financial statements for their cost-based rate-regulated utility operations. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to an item will be recovered or refunded within a year of the balance sheet date.
(PPL, LKE, LG&E and KU)
LG&E is subject to the jurisdiction of the KPSC and FERC, and KU is subject to the jurisdiction of the KPSC, FERC and VSCC.
LG&E's and KU's Kentucky base rates are calculated based on recovery of costs as well as a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets.
(PPL LKE and KU)
KU's Virginia base rates are calculated based on recovery of costs as well as a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). AllAs all regulatory assets and liabilities, except for regulatory assets and liabilities related to the levelized fuel factor, are excluded from the return on rate base utilized in the calculation of Virginia base rates. Therefore, no return is earned on the related assets.
KU's rates to municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except accumulated deferred income taxes, are excluded from the return on rate base utilized in the development of municipal rates, no return is earned on the related assets.
(PPL and PPL Electric)
PPL Electric's distribution base rates are calculated based on recovery of costs as well as a return on distribution rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). PPL Electric's transmission revenues are billed in accordance with a FERC tariff that allows for recovery of transmission costs incurred, a return on transmission-related rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions) and an automatic annual update. See "Transmission Formula Rate" below for additional information on this tariff. All regulatory assets and liabilities are excluded from distribution and transmission return on investment calculations; therefore, generally no return is earned on PPL Electric's regulatory assets.
(All Registrants)
The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31,:31:
| PPL | PPL Electric | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| Current Regulatory Assets: | |||||||||||||||
| Environmental cost recovery | $ | 5 | $ | 6 | $ | — | $ | — | |||||||
| Generation formula rate | 6 | 11 | — | — | |||||||||||
| Transmission service charge | — | 7 | — | 7 | |||||||||||
| Gas supply clause | 4 | 3 | — | — | |||||||||||
| Smart meter rider | 15 | 6 | 15 | 6 | |||||||||||
| Storm costs | — | 5 | — | 5 | |||||||||||
| Other | 4 | 1 | 1 | 1 | |||||||||||
| Total current regulatory assets (a) | $ | 34 | $ | 39 | $ | 16 | $ | 19 | |||||||
| Noncurrent Regulatory Assets: | |||||||||||||||
| Defined benefit plans | $ | 880 | $ | 947 | $ | 504 | $ | 549 | |||||||
| Taxes recoverable through future rates | 3 | 340 | 3 | 340 | |||||||||||
| Storm costs | 33 | 57 | — | 9 | |||||||||||
| Unamortized loss on debt | 54 | 61 | 29 | 36 | |||||||||||
| Interest rate swaps | 26 | 31 | — | — | |||||||||||
| Terminated interest rate swaps | 92 | 98 | — | — | |||||||||||
| Accumulated cost of removal of utility plant | 173 | 159 | 173 | 159 | |||||||||||
| AROs | 234 | 211 | — | — | |||||||||||
| Other | 9 | 14 | — | 1 | |||||||||||
| Total noncurrent regulatory assets | $ | 1,504 | $ | 1,918 | $ | 709 | $ | 1,094 | |||||||
| Current Regulatory Liabilities: | |||||||||||||||
| Generation supply charge | $ | 34 | $ | 23 | $ | 34 | $ | 23 | |||||||
| Transmission service charge | 9 | — | 9 | — | |||||||||||
| Universal service rider | 26 | 14 | 26 | 14 | |||||||||||
| Transmission formula rate | 9 | 15 | 9 | 15 | |||||||||||
| Fuel adjustment clauses | 3 | 11 | — | — | |||||||||||
| Act 129 compliance rider | — | 17 | — | 17 | |||||||||||
| Storm damage expense rider | 8 | 13 | 8 | 13 | |||||||||||
| Other | 6 | 8 | — | 1 | |||||||||||
| Total current regulatory liabilities | $ | 95 | $ | 101 | $ | 86 | $ | 83 | |||||||
| Noncurrent Regulatory Liabilities: | |||||||||||||||
| Accumulated cost of removal of utility plant | $ | 677 | $ | 700 | $ | — | $ | — | |||||||
| Power purchase agreement - OVEC (b) | 68 | 75 | — | — | |||||||||||
| Net deferred taxes (c) | 1,853 | 23 | 668 | — | |||||||||||
| Defined benefit plans | 27 | 23 | — | — | |||||||||||
| Terminated interest rate swaps | 74 | 78 | — | — | |||||||||||
| Other | 5 | — | — | — | |||||||||||
| Total noncurrent regulatory liabilities | $ | 2,704 | $ | 899 | $ | 668 | $ | — | |||||||
| LKE | LG&E | KU | |||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||
| Current Regulatory Assets: | |||||||||||||||||||||||
| Environmental cost recovery | $ | 5 | $ | 6 | $ | 5 | $ | 6 | $ | — | $ | — | |||||||||||
| Generation formula rate | 6 | 11 | — | — | 6 | 11 | |||||||||||||||||
| Gas supply clause | 4 | 3 | 4 | 3 | — | — | |||||||||||||||||
| Other | 3 | — | 3 | — | — | — | |||||||||||||||||
| Total current regulatory assets | $ | 18 | $ | 20 | $ | 12 | $ | 9 | $ | 6 | $ | 11 | |||||||||||
| PPL | PPL Electric | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| Current Regulatory Assets: | |||||||||||||||||||||||
| Plant outage costs | $ | — | $ | 46 | $ | — | $ | — | |||||||||||||||
| Gas supply clause | 21 | 4 | — | — | |||||||||||||||||||
| Smart meter rider | 11 | 17 | 11 | 17 | |||||||||||||||||||
| Transmission formula rate | 6 | 15 | 6 | 15 | |||||||||||||||||||
| Storm costs | — | 7 | — | 7 | |||||||||||||||||||
| Fuel adjustment clause | 11 | — | — | — | |||||||||||||||||||
| Other | 15 | 10 | 5 | 1 | |||||||||||||||||||
| Total current regulatory assets (a) | $ | 64 | $ | 99 | $ | 22 | $ | 40 | |||||||||||||||
| Noncurrent Regulatory Assets: | |||||||||||||||||||||||
| Defined benefit plans | $ | 523 | $ | 570 | $ | 256 | $ | 290 | |||||||||||||||
| Plant outage cost | 54 | — | — | — | |||||||||||||||||||
| Storm costs | 11 | 17 | — | — | |||||||||||||||||||
| Unamortized loss on debt | 24 | 30 | 4 | 8 | |||||||||||||||||||
| Interest rate swaps | 18 | 23 | — | — | |||||||||||||||||||
| Terminated interest rate swaps | 70 | 75 | — | — | |||||||||||||||||||
| Accumulated cost of removal of utility plant | 228 | 240 | 228 | 240 | |||||||||||||||||||
| AROs | 302 | 300 | — | — | |||||||||||||||||||
| Other | 6 | 7 | — | 3 | |||||||||||||||||||
| Total noncurrent regulatory assets | $ | 1,236 | $ | 1,262 | $ | 488 | $ | 541 | |||||||||||||||
| PPL | PPL Electric | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| Current Regulatory Liabilities: | |||||||||||||||||||||||
| Generation supply charge | $ | 10 | $ | 21 | $ | 10 | $ | 21 | |||||||||||||||
| Transmission service charge | 21 | 1 | 21 | 1 | |||||||||||||||||||
| Universal service rider | 17 | 22 | 17 | 22 | |||||||||||||||||||
| TCJA customer refund | 22 | 11 | 22 | 11 | |||||||||||||||||||
| Act 129 compliance rider | 10 | 7 | 10 | 7 | |||||||||||||||||||
| Transmission formula rate return on equity (b) | 73 | — | 73 | — | |||||||||||||||||||
| Economic relief billing rate | 27 | — | — | — | |||||||||||||||||||
| Other | 2 | 17 | — | 6 | |||||||||||||||||||
| Total current regulatory liabilities | $ | 182 | $ | 79 | $ | 153 | $ | 68 | |||||||||||||||
| Noncurrent Regulatory Liabilities: | |||||||||||||||||||||||
| Accumulated cost of removal of utility plant | $ | 639 | $ | 653 | $ | — | $ | — | |||||||||||||||
| Power purchase agreement - OVEC | 35 | 43 | — | — | |||||||||||||||||||
| Net deferred taxes | 1,591 | 1,690 | 531 | 560 | |||||||||||||||||||
| Defined benefit plans | 95 | 60 | 28 | 18 | |||||||||||||||||||
| Terminated interest rate swaps | 62 | 66 | — | — | |||||||||||||||||||
| Other | — | 18 | — | — | |||||||||||||||||||
| Total noncurrent regulatory liabilities | $ | 2,422 | $ | 2,530 | $ | 559 | $ | 578 | |||||||||||||||
123
| LG&E | KU | |||||||||||||||||||||||||||||||||||||||||||||
| LKE | LG&E | KU | 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||||||||||||||||||||||
| Current Regulatory Assets: | Current Regulatory Assets: | |||||||||||||||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | |||||||||||||||||||||||||||||||||||||||||
| Gas supply clause | Gas supply clause | $ | 21 | $ | 4 | $ | — | $ | — | |||||||||||||||||||||||||||||||||||||
| Fuel adjustment clause | Fuel adjustment clause | 4 | — | 7 | — | |||||||||||||||||||||||||||||||||||||||||
| Gas line tracker | Gas line tracker | 3 | 4 | — | — | |||||||||||||||||||||||||||||||||||||||||
| Generation formula rate | Generation formula rate | — | — | 2 | 2 | |||||||||||||||||||||||||||||||||||||||||
| Plant outage costs | Plant outage costs | — | 12 | — | 34 | |||||||||||||||||||||||||||||||||||||||||
| Other | Other | 5 | 3 | — | — | |||||||||||||||||||||||||||||||||||||||||
| Total current regulatory assets | Total current regulatory assets | $ | 33 | $ | 23 | $ | 9 | $ | 36 | |||||||||||||||||||||||||||||||||||||
| Noncurrent Regulatory Assets: | Noncurrent Regulatory Assets: | |||||||||||||||||||||||||||||||||||||||||||||
| Defined benefit plans | $ | 376 | $ | 398 | $ | 234 | $ | 246 | $ | 142 | $ | 152 | Defined benefit plans | $ | 164 | $ | 174 | $ | 103 | $ | 106 | |||||||||||||||||||||||||
| Storm costs | 33 | 48 | 18 | 26 | 15 | 22 | Storm costs | 8 | 11 | 3 | 6 | |||||||||||||||||||||||||||||||||||
| Unamortized loss on debt | 25 | 25 | 16 | 16 | 9 | 9 | Unamortized loss on debt | 12 | 13 | 8 | 9 | |||||||||||||||||||||||||||||||||||
| Interest rate swaps | 26 | 31 | 26 | 31 | — | — | Interest rate swaps | 18 | 23 | — | — | |||||||||||||||||||||||||||||||||||
| Terminated interest rate swaps | 92 | 98 | 54 | 57 | 38 | 41 | Terminated interest rate swaps | 41 | 44 | 29 | 31 | |||||||||||||||||||||||||||||||||||
| AROs | 234 | 211 | 61 | 70 | 173 | 141 | AROs | 75 | 85 | 227 | 215 | |||||||||||||||||||||||||||||||||||
| Plant outage costs | Plant outage costs | 15 | — | 39 | — | |||||||||||||||||||||||||||||||||||||||||
| Other | 9 | 13 | 2 | 4 | 7 | 9 | Other | 4 | 1 | 2 | 3 | |||||||||||||||||||||||||||||||||||
| Total noncurrent regulatory assets | $ | 795 | $ | 824 | $ | 411 | $ | 450 | $ | 384 | $ | 374 | Total noncurrent regulatory assets | $ | 337 | $ | 351 | $ | 411 | $ | 370 | |||||||||||||||||||||||||
| LG&E | KU | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| Current Regulatory Liabilities: | |||||||||||||||||||||||
| Economic relief billing credit | $ | 21 | $ | — | $ | 6 | $ | — | |||||||||||||||
| Fuel adjustment clauses | — | — | — | 5 | |||||||||||||||||||
| Environmental cost recovery | — | — | — | 4 | |||||||||||||||||||
| Other | — | — | 2 | 2 | |||||||||||||||||||
| Total current regulatory liabilities | $ | 21 | $ | — | $ | 8 | $ | 11 | |||||||||||||||
| Noncurrent Regulatory Liabilities: | |||||||||||||||||||||||
| Accumulated cost of removal of utility plant | $ | 262 | $ | 274 | $ | 377 | $ | 379 | |||||||||||||||
| Power purchase agreement - OVEC | 24 | 30 | 11 | 13 | |||||||||||||||||||
| Net deferred taxes | 491 | 528 | 569 | 602 | |||||||||||||||||||
| Defined benefit plans | 10 | — | 57 | 42 | |||||||||||||||||||
| Terminated interest rate swaps | 31 | 33 | 31 | 33 | |||||||||||||||||||
| Other | — | 17 | — | 1 | |||||||||||||||||||
| Total noncurrent regulatory liabilities | $ | 818 | $ | 882 | $ | 1,045 | $ | 1,070 | |||||||||||||||
| Current Regulatory Liabilities: | |||||||||||||||||||||||
| Demand side management | $ | — | $ | 3 | $ | — | $ | 2 | $ | — | $ | 1 | |||||||||||
| Fuel adjustment clause | 3 | 11 | — | 2 | 3 | 9 | |||||||||||||||||
| Gas line tracker | 3 | — | 3 | — | — | — | |||||||||||||||||
| Other | 3 | 4 | — | 1 | 3 | 3 | |||||||||||||||||
| Total current regulatory liabilities | $ | 9 | $ | 18 | $ | 3 | $ | 5 | $ | 6 | $ | 13 | |||||||||||
| Noncurrent Regulatory Liabilities: | |||||||||||||||||||||||
| Accumulated cost of removal | |||||||||||||||||||||||
| of utility plant | $ | 677 | $ | 700 | $ | 282 | $ | 305 | $ | 395 | $ | 395 | |||||||||||
| Power purchase agreement - OVEC (b) | 68 | 75 | 47 | 52 | 21 | 23 | |||||||||||||||||
| Net deferred taxes (c) | 1,185 | 23 | 552 | 23 | 633 | — | |||||||||||||||||
| Defined benefit plans | 27 | 23 | — | — | 27 | 23 | |||||||||||||||||
| Terminated interest rate swaps | 74 | 78 | 37 | 39 | 37 | 39 | |||||||||||||||||
| Other | 5 | — | 1 | — | 4 | — | |||||||||||||||||
| Total noncurrent regulatory liabilities | $ | 2,036 | $ | 899 | $ | 919 | $ | 419 | $ | 1,117 | $ | 480 | |||||||||||
(a)For PPL, these amounts are included in "Other current assets" on the Balance Sheets.
(b)See “Regulatory Matters - Federal Matters - PPL Electric Transmission Formula Rate Return on Equity” below for additional information.
Following is an overview of selected regulatory assets and liabilities detailed in the preceding tables. Specific developments with respect to certain of these regulatory assets and liabilities are discussed in "Regulatory Matters."
Defined Benefit Plans
(All Registrants)
Defined benefit plan regulatory assets and liabilities represent prior service cost and net actuarial gains and losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and, generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is remeasured. Of the regulatory asset and liability balances recorded, costs of $68 million for PPL, $30 million for PPL Electric, $38 million for LKE, $26 million for LG&E and $12 million for KU, are expected to be amortized into net periodic defined benefit costs in 2018 in accordance with PPL's, PPL Electric's, LKE's, LG&E's and KU's pension accounting policy.
(PPL, LKE, LG&E and KU)
As a result of the 2014 Kentuckyprevious rate case settlement that became effective July 1, 2015,settlements and orders, the difference between pension cost calculated in accordance with LG&E's and KU's pension accounting policy and pension cost calculated using a 15-year amortization period for actuarial gains
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and losses isand settlements are recorded as a regulatory asset. As of December 31, 2017,2021, the balances were $33$98 million for PPL, and LKE, $18$54 million for LG&E and $15$44 million for KU. As of December 31, 2016,2020, the balances were $20$79 million for PPL, and LKE, $11$44 million for LG&E and $9$35 million for KU. Of the costs expected to be amortized into net periodic defined benefit costs in 2018, $16 million for PPL and LKE, $10 million for LG&E and $6 million for KU, are expected to be recorded as a regulatory asset in 2018.
(All Registrants)
Storm Costs
PPL Electric, LG&E and KU have the ability to request from the PUC, KPSC and VSCC, as applicable, the authority to treat expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once such authority is granted, LG&E and KU can request recovery of those expenses in a base rate case and begin amortizing the costs when recovery starts. PPL Electric can recover qualifying expenses caused by major storm events, as defined in its retail tariff, over three years through the Storm Damage Expense Rider commencing in the application year after the storm occurred. Storm costs incurred in PPL Electric's territory from a March 2018 storm were amortized through 2021. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2020.2031.
Unamortized Loss on Debt
Unamortized loss on reacquired debt represents losses on long-term debt refinanced, reacquired or redeemed that have been deferred and will be amortized and recovered over either the original life of the extinguished debt or the life of the replacement debt (in the case of refinancing). Such costs are being amortized through 2029 for PPL Electric, through 2042 for KU, and through 2044 for PPL, LKE and LG&E.
Accumulated Cost of Removal of Utility Plant
LG&E and KU charge costs of removal through depreciation expense with an offsetting credit to a regulatory liability. The regulatory liability is relieved as costs are incurred.
PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the costs as a regulatory asset. Such deferral is included in rates and amortized over the subsequent five-yearfive-year period.
Regulatory liabilities associated with net deferred taxes represent the future revenue impact from the adjustment of deferred income taxes required primarily for excess deferred taxes and unamortized investment tax credits. At December 31, 2017, excess deferred taxes recorded ascredits, largely a result of the TCJA were $2.2 billion at PPL, $1.0 billion at PPL Electric, $1.2 billion at LKE, $532 million at LG&E and $634 million at KU, which include the gross-up associated with the excess deferred taxes.enacted in 2017.
(PPL and PPL Electric)
Generation Supply Charge (GSC)
The GSC is a cost recovery mechanism that permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply, (energy and capacity and ancillary services), as well as administration of the acquisition process. In addition, the GSC contains a reconciliation mechanism whereby any over- or under-recovery from prior quartersperiods is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent rate filing period.
Transmission Service Charge (TSC)
PPL Electric is charged by PJM for transmission service-related costs applicable to its PLR customers. PPL Electric passes these costs on to customers, who receive basic generation supply service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year.
Transmission Formula Rate
PPL Electric's transmission revenues are billed in accordance with a FERC-approved Open Access Transmission Tariff that utilizes a formula-based rate recovery mechanism. Under this formula, rates are put into effect in June of each year based upon prior year actual expenditures and current year forecasted capital additions. Rates are then adjusted the following year to reflect
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actual annual expenses and capital additions, as reported in PPL Electric's annual FERC Form 1, filed under the FERC's
Uniform System of Accounts. Any difference between the revenue requirement in effect for the prior year and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability.
Storm Damage Expense Rider (SDER)
The SDER is a reconcilable automatic adjustment clause under which PPL Electric annually will compare actual storm costs to storm costs allowed in base rates and refund or recover any differences from customers. In the 2015 rate case settlement approved by the PUC in November 2015, it was determined that reportable storm damage expenses to be recovered annually through base rates will be set at $15$20 million. The SDER will recover from or refund to customers as appropriate, onlythe applicable expenses from reportable storms that are greater than or less than $15as compared to the $20 million recovered annually through base rates. Beginning January 1, 2018, the amortized 2011 storm expense of $5 million will be included in the base rate component of the SDER.
Act 129 Compliance Rider
In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase IIV of PPL Electric'sthe energy efficiency and conservation plan which was approved by a PUC order in October 2009. The order allowed PPL Electric to recover the maximum $250 million cost of the program ratably over the life of the plan, from January 1, 2010 through May 31, 2013.March 2021. Phase II of PPL's energy efficiency and conservation plan allowed PPL Electric to recover the maximum $185 million cost of the program over the three year period June 1, 2013 through May 31, 2016. Phase III of PPL's energy efficiency and conservation planIV allows PPL Electric to recover the maximum $313 million over the next five year-year period, June 1, 20162021 through May 31, 2021.2026. The plan includes programs intended to reduce electricity consumption. The recoverable costs include direct and indirect charges, including design and development costs, general and administrative costs and applicable state evaluator costs. The rates are applied to customers who receive distribution service through the Act 129 Compliance Rider. The Phase II program costs were reconciled at the end of the program and any remaining over- or under-recovery was rolled into Phase III. The actual Phase IIIIV program costs are reconcilable after each 12 month period, and any over- or under-recovery from customers will be refunded or recovered over the next rate filing period. See below under "Regulatory Matters - Pennsylvania Activities" for additional information onPPL Electric's Act 129.129 Phase III plan ended May 31, 2021 and any over-or under-recovery from customers related to Phase III will be refunded or recovered over the next rate filing period.
Smart Meter Rider (SMR)
Act 129 which became effective November 14, 2008, requires each electric distribution company (EDC) with more than 100,000 customers to have a PUC approved Smart Meter Technology Procurement and Installation Plan (SMP). As of December 31, 2019, PPL Electric filedreplaced substantially all of its initial SMP in 2009. However, in 2010, the PUC found that PPL Electric's "Advanced Metering Infrastructure" (AMI) system did not fully meet the standards of Act 129. In 2014, PPL Electric filed its current SMP, which was approved by the PUC in 2015. Under its SMP, PPL Electric will replace its currentold meters with new meters that meet the Act 129 requirements by the end of 2019. Underunder its SMP. In accordance with Act 129, EDCs are able to recover the costs and earn a return on capital of providing smart metering technology. PPL Electric uses a mechanism known as the Smart Meter Rider (SMR)SMR to recover the costs to implement its SMP on a full and current basis.SMP. The SMR is a reconciliation mechanism whereby any over-orover- or under-recovery from prior years is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent quarters.
Universal Service Rider (USR)
The USR provides for recovery of costs associated with universal service programs, OnTrack and Winter Relief Assistance Program (WRAP), provided by PPL Electric to residential customers. OnTrack is a special payment program for low-income households and WRAP provides low-income customers a means to reduce electric bills through energy saving methods. The USR rate is applied to residential customers who receive distribution service. The actual program costs are reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year.
TCJA Customer Refund
As a result of the reduced U.S federal corporate income tax rate as enacted by the TCJA, the PUC ruled that these tax benefits should be refunded to customers. Timing differences between the recognition of these tax benefits and the refund of the benefit to the customer creates a regulatory liability. PPL Electric's liability is being credited back to distribution customers through a temporary negative surcharge and remains in place until PPL Electric files and the PUC approves new base rates. The TCJA is reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year.
(PPL, LKE, LG&E and KU)
Environmental Cost Recovery
Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements, which apply to coal combustion wastes and by-products from coal-fired electricity generating facilities. The KPSC requires reviews of the past operations of the environmental surcharge for six-month and two-year billing periods to evaluate the related charges, credits and rates of return, as well as to provide for the roll-in of ECR amounts to base rates each two-year period. In December 2017, theThe KPSC issued orders continuing the use of anhas authorized return on equity of 9.7%9.35% for all existing approved ECR plans and projects. The ECR regulatory asset or liability represents
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the amount that has been under- or over-recovered due to timing or adjustments to the mechanism and is typically recovered or refunded within 12 months.
Fuel Adjustment Clauses
LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in power purchases and the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires public hearingsformal reviews at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, may conduct public hearings and reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months.
KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs.costs and load for the fuel year (12 months ending March 31). The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the comingfuel year plus an adjustment for any under- or over-recovery of fuel expenses from the prior fuel year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered or refunded within 12 months.
AROs
As discussed in Note 1, for LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset.asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory assetdeferred accretion and depreciation expense is offset against the associatedrecovered through cost of removal regulatory liability, PP&E and ARO liability.removal.
Power Purchase Agreement - OVEC
As a result of purchase accounting associated with PPL's acquisition of LKE,LG&E and KU, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LKE, LG&E and KU with offsets to regulatory liabilities. The regulatory liabilities are being amortized using the units-of-production method until March 2026, the expiration date of the agreement at the date of the acquisition. LG&E's and KU's customer rates continue to reflect the original contracts. See Notes 1, 1314 and 1819 for additional discussion of the power purchase agreement.
Interest Rate Swaps
LG&E's unrealized gains and losses are recorded as regulatory assets or regulatory liabilities until they are realized as interest expense. Interest expense from existing swaps is realized and recovered over the terms of the associated debt, which matures throughin 2033.
Terminated Interest Rate Swaps
Net realized gains and losses on all interest rate swaps are probable of recoveryrecovered through regulated rates; asrates. As such, any gains and losses on these derivatives are included in regulatory assets or liabilities and are primarily recognized in "Interest Expense" on the Statements of Income over the life of the associated debt.
Plant Outage Costs
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Gas Supply Clause(PPL and LG&E)
LG&E's natural gas rates contain a gas supply clause, whereby the expected cost of natural gas supply and variances between actual and expected costs and customer usage from prior periods are adjusted quarterly in LG&E's rates, subject to approval by the KPSC. The gas supply clause also includes a separate natural gas procurement incentive mechanism, which allows LG&E's rates to be adjusted annually to share savings between the actual cost of gas purchases and market indices, with the shareholders and the customers during each performance-based rate year (12 months ending October 31). The regulatory assets or liabilities represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered or refunded within 18 months.
Regulatory Matters
(PPL, LKE, LG&E and KU)
Rate Case Proceedings
LG&E’s and KU’s applications also included a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky.
The applications were based on a forecasted test year of July 1, 2021 through June 30, 2022 and requested an authorized return on equity of 10.0%.
On April 19, 2021, LG&E and KU entered into an agreement with all intervening parties to the proceeding, filedproceedings resolving all matters in their applications, with the explicit exception of LG&E's and KU's net metering proposals.
On June 30, 2021 and December 6, 2021, the KPSC stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things,issued orders approving the proposed stipulationsagreement filed in April 2021, with certain modifications. The orders provided for increases in annual revenue requirements associated withrevenues of $207 million ($74 million and $110 million in electricity revenues at LG&E base electricity rates of $59 million, LG&E base gas rates of $8 million and KU base electricity rates of $55and $23 million reflecting a returnin gas revenues at LG&E) based on equity of 9.75%, the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates.
Pennsylvania Activities(PPL and PPL Electric)
Act 129
Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet, by specified dates, specified goals for reduction in customer electricity usage and peak demand. EDCs not meeting the requirements of Act 129 are subject to significant penalties. In November 2015, PPL Electric filed with the PUC its Act 129 Phase IIIIV Energy Efficiency and Conservation Plan on November 30, 2020, for the five-year period starting June 1, 2016 through2021 and ending on May 31, 2021. In June 2016, the PUC approved2026. PPL Electric's Phase IIIIV Act 129 Plan was approved by the PUC at its March 25, 2021, public meeting.
Act 129 also requires Default Service ProvidersEDCs to act as a default service provider (DSP) to provide, which provides electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan through auctions, requests for proposal and bilateral contracts at the sole discretion of the DSP. PPL Electric is a DSP. Act 129 requires a mix of spot market purchases, short-term contracts and long-term contracts (4 to 20 years), with long-term contracts limited to 25% of load unless otherwise approved by the PUC.plan. A DSP is able to recover the costs associated with its default service procurement plan.
Federal Matters
On August 20, 2021, PPL Electric entered into a settlement agreement (the Settlement) with PPLICA and all other parties, including intervenors, with respect to the complaint filed by PPLICA on May 21, 2020.
The time period for any challengeskey aspects of the Settlement include:
•changes to PPL Electric's annual update has expired. No formal challengesElectric’s base ROE:
◦beginning as of May 21, 2020 and continuing through May 31, 2022, the ROE shall be 9.90%;
◦beginning on June 1, 2022 and continuing through May 31, 2023, the ROE shall be 9.95%;
◦beginning on June 1, 2023, the ROE shall be 10.00%, which shall continue in effect unless and until changed as permitted by the terms of the Settlement;
•changes the equity component of PPL Electric’s capital structure to be the lower of (i) PPL Electric’s actual equity component, calculated in accordance with the formula rate template, or (ii) 56.00%;
•allows modification of the current rate year of June 1 to May 31 to a calendar year of January 1 to December 31; and
•allows modification of the current formula rate based on a historic test year to a projected test year.
In 2021, PPL Electric recorded a revenue reduction of $78 million ($55 million after-tax), of which $73 million ($52 million after-tax) represents revenue subject to refund for the period May 21, 2020 through November 30, 2021. The reduction recorded includes $28 million ($20 million after-tax) related to the period from May 21, 2020 to December 31, 2020. The $73 million of revenue to be refunded will be returned to customers from January 1, 2022 through May 31, 2022 and is based on the difference between charges that were submitted.calculated using the ROE in effect at the time and charges calculated using the revised ROE provided for the Settlement, plus interest at the FERC interest rate.
The FERC approved the Settlement on November 5, 2021. Interim rates reflecting the agreed-to-base ROE in the Settlement were effective December 1, 2021.
(PPL, LG&E and KU)
FERC Transmission Rate Filing
In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going 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 FERC's orders on the elimination of the mitigation and required transition mechanism. Oral arguments in the appellate proceeding occurred on February 14, 2022.LG&E and KU cannot predict the outcome of the respective appellate and FERC proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms and such rate recovery would be anticipated to be adjusted consistent with potential changes or terminations of the waivers and credits, as such become effective.
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Other
Purchase of Receivables Program
(PPL and PPL Electric)
In accordance with a PUC-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 2017, 20162021, 2020 and 2015,2019, PPL Electric purchased $1.3$1.2 billion, $1.4$1.1 billion and $1.3$1.2 billion of accounts receivable from unaffiliated third parties. During 2015, PPL Electric purchased $146 million of accounts receivable from PPL EnergyPlus. PPL Electric's purchases from PPL EnergyPlus for 2015 included purchases through May 31, 2015, which is the period during which PPL Electric and PPL EnergyPlus were affiliated entities. As a result of the June 1, 2015 spinoff of PPL Energy Supply and creation of Talen Energy, PPL EnergyPlus (renamed Talen Energy Marketing) is no longer an affiliate of PPL Electric. PPL Electric's purchases from Talen Energy Marketing subsequent to May 31, 2015 are included as purchases from unaffiliated third parties.alternative suppliers.
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, LKE, LG&E and KU also apply to PPL and the credit facilities and commercial paper programs of LG&E and KU also apply to LKE.PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets except for
borrowings under LG&E's Term Loan FacilityPPL Capital Funding's term loan agreement due March 2022, which are recorded asreflected in "Long-term debt" on the Balance Sheets.at December 31, 2020. The following credit facilities were in place at:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||||||||||||||||||||
| Expiration Date | Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | Unused Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | |||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||
| PPL Capital Funding | |||||||||||||||||||||||||||||||||||||||||
| Syndicated Credit Facility (a) (b) | Dec 2026 | $ | 1,250 | $ | — | $ | — | $ | 1,250 | $ | — | $ | 402 | ||||||||||||||||||||||||||||
| Bilateral Credit Facility (a) (b) | Mar 2022 | 50 | — | — | 50 | — | — | ||||||||||||||||||||||||||||||||||
| Bilateral Credit Facility (a) (b) | Mar 2022 | 50 | — | 15 | 35 | — | 15 | ||||||||||||||||||||||||||||||||||
| Term Loan Credit Facility (a) (b) | Mar 2021 | — | — | — | — | 200 | — | ||||||||||||||||||||||||||||||||||
| Term Loan Credit Facility (a) (b) | Mar 2021 | — | — | — | — | 100 | — | ||||||||||||||||||||||||||||||||||
| Term Loan Credit Facility (a) (b) | Mar 2022 | — | — | — | — | 100 | — | ||||||||||||||||||||||||||||||||||
| Total PPL Capital Funding Credit Facilities | $ | 1,350 | $ | — | $ | 15 | $ | 1,335 | $ | 400 | $ | 417 | |||||||||||||||||||||||||||||
| PPL Electric | |||||||||||||||||||||||||||||||||||||||||
| Syndicated Credit Facility (a) (b) | Dec 2026 | $ | 650 | $ | — | $ | 1 | $ | 649 | $ | — | $ | 1 | ||||||||||||||||||||||||||||
| LG&E | |||||||||||||||||||||||||||||||||||||||||
| Syndicated Credit Facility (a) (b) | Dec 2026 | $ | 500 | $ | — | $ | 69 | $ | 431 | $ | — | $ | 262 | ||||||||||||||||||||||||||||
| KU | |||||||||||||||||||||||||||||||||||||||||
| Syndicated Credit Facility (a) (b) | Dec 2026 | $ | 400 | $ | — | $ | — | $ | 400 | $ | — | $ | 203 | ||||||||||||||||||||||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||||||||||||
Expiration Date | Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | Unused Capacity | Borrowed | Letters of Credit and Commercial Paper Issued | |||||||||||||||||||
| PPL | |||||||||||||||||||||||||
| U.K. | |||||||||||||||||||||||||
| WPD plc | |||||||||||||||||||||||||
| Syndicated Credit Facility (a) (c) | Jan. 2022 | £ | 210 | £ | 148 | £ | — | £ | 60 | £ | 160 | £ | — | ||||||||||||
| WPD (South West) | |||||||||||||||||||||||||
| Syndicated Credit Facility (a) (c) | July 2021 | 245 | — | — | 245 | 110 | — | ||||||||||||||||||
| WPD (East Midlands) | |||||||||||||||||||||||||
| Syndicated Credit Facility (a) (c) | July 2021 | 300 | 180 | — | 120 | 9 | — | ||||||||||||||||||
| WPD (West Midlands) | |||||||||||||||||||||||||
| Syndicated Credit Facility (a) (c) | July 2021 | 300 | 120 | — | 180 | — | — | ||||||||||||||||||
| Uncommitted Credit Facilities | 100 | — | 4 | 96 | 60 | 4 | |||||||||||||||||||
| Total U.K. Credit Facilities (b) | £ | 1,155 | £ | 448 | £ | 4 | £ | 701 | £ | 339 | £ | 4 | |||||||||||||
| U.S. | |||||||||||||||||||||||||
| PPL Capital Funding | |||||||||||||||||||||||||
| Syndicated Credit Facility (c) (d) | Jan. 2022 | $ | 950 | $ | — | $ | 230 | $ | 720 | $ | — | $ | 20 | ||||||||||||
| Syndicated Credit Facility (c) (d) | Nov. 2018 | 300 | — | — | 300 | — | — | ||||||||||||||||||
| Bilateral Credit Facility (c) (d) | Mar. 2018 | 150 | — | 18 | 132 | — | 17 | ||||||||||||||||||
| Total PPL Capital Funding Credit Facilities | $ | 1,400 | $ | — | $ | 248 | $ | 1,152 | $ | — | $ | 37 | |||||||||||||
| PPL Electric | |||||||||||||||||||||||||
| Syndicated Credit Facility (c) (d) | Jan. 2022 | $ | 650 | $ | — | $ | 1 | $ | 649 | $ | — | $ | 296 | ||||||||||||
| LKE | |||||||||||||||||||||||||
| Syndicated Credit Facility (c) (d) | Oct. 2018 | $ | 75 | $ | — | $ | — | $ | 75 | $ | — | $ | — | ||||||||||||
| LG&E | |||||||||||||||||||||||||
| Syndicated Credit Facility (c) (d) | Jan. 2022 | $ | 500 | $ | — | $ | 199 | $ | 301 | $ | — | $ | 169 | ||||||||||||
| Term Loan Credit Facility (c) (e) | Oct. 2019 | 200 | 100 | — | 100 | — | — | ||||||||||||||||||
| Total LG&E Credit Facilities | $ | 700 | $ | 100 | $ | 199 | $ | 401 | $ | — | $ | 169 | |||||||||||||
| KU | |||||||||||||||||||||||||
| Syndicated Credit Facility (c) (d) | Jan. 2022 | $ | 400 | $ | — | $ | 45 | $ | 355 | $ | — | $ | 16 | ||||||||||||
| Letter of Credit Facility (c) (d) (f) | Oct. 2020 | 198 | — | 198 | — | — | 198 | ||||||||||||||||||
| Total KU Credit Facilities | $ | 598 | $ | — | $ | 243 | $ | 355 | $ | — | $ | 214 | |||||||||||||
(a)Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin.
(b)The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for |
(PPL)
In December 2021, PPL Capital Funding amended and restated its existing $1.450 billion revolving credit facility to extend the termination date from January 2022 were extended26, 2024 to December 6, 2026, to decrease the borrowing capacity to $1.250 billion and to
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provide for the option to add Narragansett Electric as an additional borrower upon acquisition by PPL Rhode Island Holdings, LLC.
(PPL and PPL Electric)
In December 2021, PPL Electric Utilities Corporation amended and restated its existing $650 million revolving credit facility to extend the termination date from January 2023.26, 2024 to December 6, 2026.
(PPL and LG&E)
In December 2021, LG&E amended and restated its existing $500 million revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026.
(PPL and KU)
In December 2021, KU amended and restated its existing $400 million revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026.
(All Registrants)
PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary.needs. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's Syndicated Credit Facility.credit facilities. The following commercial paper programs were in place at:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||||||||||||||
| Weighted - Average Interest Rate | Capacity | Commercial Paper Issuances | Unused Capacity | Weighted - Average Interest Rate | Commercial Paper Issuances | ||||||||||||||||||||||||||||||
| PPL Capital Funding | 0 | $ | 1,500 | $ | — | $ | 1,500 | 0.25% | $ | 402 | |||||||||||||||||||||||||
| PPL Electric | 00 | 650 | — | 650 | 00 | — | |||||||||||||||||||||||||||||
| LG&E (a) | 0.31% | 425 | 69 | 356 | 0.28% | 262 | |||||||||||||||||||||||||||||
| KU | 00 | 350 | — | 350 | 0.28% | 203 | |||||||||||||||||||||||||||||
| Total | $ | 2,925 | $ | 69 | $ | 2,856 | $ | 867 | |||||||||||||||||||||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||||||
| Weighted - Average Interest Rate | Capacity | Commercial Paper Issuances | Unused Capacity | Weighted - Average Interest Rate | Commercial Paper Issuances | ||||||||||||||
| PPL Capital Funding | 1.64% | $ | 1,000 | $ | 230 | $ | 770 | 1.10% | $ | 20 | |||||||||
| PPL Electric | 650 | — | 650 | 1.05% | 295 | ||||||||||||||
| LG&E | 1.83% | 350 | 199 | 151 | 0.94% | 169 | |||||||||||||
| KU | 1.97% | 350 | 45 | 305 | 0.87% | 16 | |||||||||||||
| Total | $ | 2,350 | $ | 474 | $ | 1,876 | $ | 500 | |||||||||||
(PPL Electric, LKE, LG&E and KU)
See Note 1415 for a discussion of intercompany borrowings.
Long-term Debt(All Registrants)
| December 31, | |||||||||||||||||||||||
| Weighted-Average Rate (d) | Maturities (d) | 2021 | 2020 | ||||||||||||||||||||
| PPL | |||||||||||||||||||||||
| Senior Unsecured Notes | 3.81 | % | 2026 - 2047 | $ | 1,566 | $ | 4,850 | ||||||||||||||||
| Senior Secured Notes/First Mortgage Bonds (a) (b) (c) | 3.59 | % | 2022 - 2050 | 9,205 | 8,955 | ||||||||||||||||||
| Junior Subordinated Notes | 2.89 | % | 2067 | 480 | 930 | ||||||||||||||||||
| Term Loan Credit Facility | — | 100 | |||||||||||||||||||||
| Total Long-term Debt before adjustments | 11,251 | 14,835 | |||||||||||||||||||||
| Unamortized premium and (discount), net | (34) | (40) | |||||||||||||||||||||
| Unamortized debt issuance costs | (77) | (106) | |||||||||||||||||||||
| Total Long-term Debt | 11,140 | 14,689 | |||||||||||||||||||||
| Less current portion of Long-term Debt | 474 | 1,074 | |||||||||||||||||||||
| Total Long-term Debt, noncurrent | $ | 10,666 | $ | 13,615 | |||||||||||||||||||
| December 31, | ||||||||||||
| Weighted-Average Rate (g) | Maturities (g) | 2017 | 2016 | |||||||||
| PPL | ||||||||||||
| U.S. | ||||||||||||
| Senior Unsecured Notes | 3.78 | % | 2020 - 2047 | $ | 4,575 | $ | 4,075 | |||||
| Senior Secured Notes/First Mortgage Bonds (a) (b) (c) | 3.96 | % | 2018 - 2047 | 7,314 | 6,849 | |||||||
| Junior Subordinated Notes | 5.10 | % | 2067 - 2073 | 930 | 930 | |||||||
| Term Loan Credit Facility | 2.06 | % | 2019 | 100 | — | |||||||
| Total U.S. Long-term Debt | 12,919 | 11,854 | ||||||||||
| U.K. | ||||||||||||
| Senior Unsecured Notes (d) | 5.24 | % | 2020 - 2040 | 6,351 | 5,707 | |||||||
| Index-linked Senior Unsecured Notes (e) | 1.56 | % | 2026 - 2056 | 1,012 | 838 | |||||||
| Total U.K. Long-term Debt (f) | 7,363 | 6,545 | ||||||||||
| Total Long-term Debt Before Adjustments | 20,282 | 18,399 | ||||||||||
| Fair market value adjustments | 21 | 22 | ||||||||||
| Unamortized premium and (discount), net (e) | 14 | 20 | ||||||||||
| Unamortized debt issuance costs | (122 | ) | (115 | ) | ||||||||
| Total Long-term Debt | 20,195 | 18,326 | ||||||||||
| Less current portion of Long-term Debt | 348 | 518 | ||||||||||
| Total Long-term Debt, noncurrent | $ | 19,847 | $ | 17,808 | ||||||||
| December 31, | |||||||||||||||||||||||
| Weighted-Average Rate (d) | Maturities (d) | 2021 | 2020 | ||||||||||||||||||||
| PPL Electric | |||||||||||||||||||||||
| Senior Secured Notes/First Mortgage Bonds (a) (b) | 3.37 | % | 2022 - 2049 | $ | 4,539 | $ | 4,289 | ||||||||||||||||
| Total Long-term Debt Before Adjustments | 4,539 | 4,289 | |||||||||||||||||||||
| Unamortized discount | (22) | (23) | |||||||||||||||||||||
| Unamortized debt issuance costs | (33) | (30) | |||||||||||||||||||||
| Total Long-term Debt | 4,484 | 4,236 | |||||||||||||||||||||
| Less current portion of Long-term Debt | 474 | 400 | |||||||||||||||||||||
| Total Long-term Debt, noncurrent | $ | 4,010 | $ | 3,836 | |||||||||||||||||||
| LG&E | |||||||||||||||||||||||
| First Mortgage Bonds (a) (c) | 3.59 | % | 2025 - 2049 | $ | 2,024 | $ | 2,024 | ||||||||||||||||
| Total Long-term Debt Before Adjustments | 2,024 | 2,024 | |||||||||||||||||||||
| Unamortized discount | (4) | (4) | |||||||||||||||||||||
| Unamortized debt issuance costs | (14) | (13) | |||||||||||||||||||||
| Total Long-term Debt | 2,006 | 2,007 | |||||||||||||||||||||
| Less current portion of Long-term Debt | — | 292 | |||||||||||||||||||||
| Total Long-term Debt, noncurrent | $ | 2,006 | $ | 1,715 | |||||||||||||||||||
| KU | |||||||||||||||||||||||
| First Mortgage Bonds (a) (c) | 3.97 | % | 2023 - 2050 | $ | 2,642 | $ | 2,642 | ||||||||||||||||
| Total Long-term Debt Before Adjustments | 2,642 | 2,642 | |||||||||||||||||||||
| Unamortized premium | 5 | 5 | |||||||||||||||||||||
| Unamortized discount | (9) | (9) | |||||||||||||||||||||
| Unamortized debt issuance costs | (20) | (20) | |||||||||||||||||||||
| Total Long-term Debt | 2,618 | 2,618 | |||||||||||||||||||||
| Less current portion of Long-term Debt | — | 132 | |||||||||||||||||||||
| Total Long-term Debt, noncurrent | $ | 2,618 | $ | 2,486 | |||||||||||||||||||
| December 31, | ||||||||||||
| Weighted-Average Rate (g) | Maturities (g) | 2017 | 2016 | |||||||||
| PPL Electric | ||||||||||||
| Senior Secured Notes/First Mortgage Bonds (a) (b) | 4.23 | % | 2020 - 2047 | $ | 3,339 | $ | 2,864 | |||||
| Total Long-term Debt Before Adjustments | 3,339 | 2,864 | ||||||||||
| Unamortized discount | (16 | ) | (12 | ) | ||||||||
| Unamortized debt issuance costs | (25 | ) | (21 | ) | ||||||||
| Total Long-term Debt | 3,298 | 2,831 | ||||||||||
| Less current portion of Long-term Debt | — | 224 | ||||||||||
| Total Long-term Debt, noncurrent | $ | 3,298 | $ | 2,607 | ||||||||
| LKE | ||||||||||||
| Senior Unsecured Notes | 3.97 | % | 2020 - 2021 | $ | 725 | $ | 725 | |||||
| Term Loan Credit Facility | 2.06 | % | 2019 | 100 | — | |||||||
| First Mortgage Bonds (a) (c) | 3.73 | % | 2018 - 2045 | 3,975 | 3,985 | |||||||
| Long-term debt to affiliate | 3.50 | % | 2026 | 400 | 400 | |||||||
| Total Long-term Debt Before Adjustments | 5,200 | 5,110 | ||||||||||
| Fair market value adjustments | — | (1 | ) | |||||||||
| Unamortized discount | (14 | ) | (15 | ) | ||||||||
| Unamortized debt issuance costs | (27 | ) | (29 | ) | ||||||||
| Total Long-term Debt | 5,159 | 5,065 | ||||||||||
| Less current portion of Long-term Debt | 98 | 194 | ||||||||||
| Total Long-term Debt, noncurrent | $ | 5,061 | $ | 4,871 | ||||||||
| LG&E | ||||||||||||
| Term Loan Credit Facility | 2.06 | % | 2019 | $ | 100 | $ | — | |||||
| First Mortgage Bonds (a) (c) | 3.48 | % | 2018 - 2045 | 1,624 | 1,634 | |||||||
| Total Long-term Debt Before Adjustments | 1,724 | 1,634 | ||||||||||
| Fair market value adjustments | — | (1 | ) | |||||||||
| Unamortized discount | (4 | ) | (4 | ) | ||||||||
| Unamortized debt issuance costs | (11 | ) | (12 | ) | ||||||||
| Total Long-term Debt | 1,709 | 1,617 | ||||||||||
| Less current portion of Long-term Debt | 98 | 194 | ||||||||||
| Total Long-term Debt, noncurrent | $ | 1,611 | $ | 1,423 | ||||||||
| KU | ||||||||||||
| First Mortgage Bonds (a) (c) | 3.91 | % | 2019 - 2045 | $ | 2,351 | $ | 2,351 | |||||
| Total Long-term Debt Before Adjustments | 2,351 | 2,351 | ||||||||||
| Unamortized discount | (9 | ) | (9 | ) | ||||||||
| Unamortized debt issuance costs | (14 | ) | (15 | ) | ||||||||
| Total Long-term Debt | 2,328 | 2,327 | ||||||||||
| Less current portion of Long-term Debt | — | — | ||||||||||
| Total Long-term Debt, noncurrent | $ | 2,328 | $ | 2,327 | ||||||||
Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection
with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $4.7$5.7 billion and $4.4$5.5 billion at December 31, 20172021 and 2016.2020.
Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $6.0$6.9 billion and $5.8$6.7 billion at December 31, 20172021 and 2016.2020.
(b)Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. This amount includes $224 million of which PPL Electric is allowed to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, or term rate of at least one year and $90 million which is subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes.
Includes $250 million of notes that may be called on or after September 28, 2021 and $650 million of notes that may be called on or after June 24, 2022, at a redemption price equal to 100% of the principal amount of the bonds, plus accrued and unpaid interest to, but excluding, such redemption date.
(c)Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in (a) above. The related tax-exempt revenue
132
bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate.
At December 31, 2017,2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $514$782 million for LKE,PPL, comprised of $391$473 million and $123$309 million for LG&E and KU. At December 31, 2017,2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $375 million for LKE, comprised of $147$66 million and $228$33 million for LG&E and KU. These variable rate tax-exempt revenue bonds are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events.
(d)The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2021.
None of the outstanding debt securities noted above have sinking fund requirements. The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 20182022 through 20222026 and thereafter are as follows:
| PPL | PPL Electric | LG&E | KU | ||||||||||||||||||||||||||
| 2022 | $ | 474 | $ | 474 | $ | — | $ | — | |||||||||||||||||||||
| 2023 | 353 | 340 | — | 13 | |||||||||||||||||||||||||
| 2024 | 650 | 650 | — | — | |||||||||||||||||||||||||
| 2025 | 550 | — | 300 | 250 | |||||||||||||||||||||||||
| 2026 | 904 | — | 90 | 164 | |||||||||||||||||||||||||
| Thereafter | 8,320 | 3,075 | 1,634 | 2,215 | |||||||||||||||||||||||||
| Total | $ | 11,251 | $ | 4,539 | $ | 2,024 | $ | 2,642 | |||||||||||||||||||||
| PPL | PPL Electric | LKE | LG&E | KU | |||||||||||||||
| 2018 | $ | 348 | $ | — | $ | 98 | $ | 98 | $ | — | |||||||||
| 2019 | 430 | — | 430 | 334 | 96 | ||||||||||||||
| 2020 | 1,278 | 100 | 975 | — | 500 | ||||||||||||||
| 2021 | 1,150 | 400 | 250 | — | — | ||||||||||||||
| 2022 | 1,274 | 474 | — | — | — | ||||||||||||||
| Thereafter | 15,802 | 2,365 | 3,447 | 1,292 | 1,755 | ||||||||||||||
| Total | $ | 20,282 | $ | 3,339 | $ | 5,200 | $ | 1,724 | $ | 2,351 | |||||||||
(PPL)
In April 2021, PPL Capital Funding repaid its $100 million term loan expiring in March 2017, WPD (South Wales) issued £50 million2022.
In June 2021, PPL Capital Funding commenced a tender offer to purchase for cash and retire (1) any and all of 0.01% Index-linkedits outstanding 4.20% Senior Notes due 2029. WPD (South Wales) received proceeds2022, 3.50% Senior Notes due 2022, 3.40% Senior Notes due 2023 and 3.95% Senior Notes due 2024 and (2) up to $1 billion aggregate purchase price of £53 million, which equated to $64 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes.
In June 2021, in connection with the tender offer, PPL Capital Funding retired $1,962 million combined aggregate principal amount of its outstanding Senior Notes for $2,293 million aggregate cash purchase price that included the tender premium and accrued interest. These Senior Notes had a weighted average interest rate of 4.14%. The loss on extinguishment associated with the transaction was $322 million, which included the tender premium, bank fees and unamortized fees, hedges and discounts. This loss on extinguishment was recorded to "Interest Expense" on the Statements of Income.
In July 2021, PPL Capital Funding redeemed the remaining $1,072 million combined aggregate principal amount of its outstanding 4.20% Senior Notes due 2022, 3.50% Senior Notes due 2022, 3.40% Senior Notes due 2023 and 3.95% Senior Notes due 2024 that had not been validly tendered for an aggregate cash purchase price of $1,133 million, which included make-whole premiums and accrued interest. These Senior Notes had a weighted average interest rate of 3.71%. The loss on extinguishment associated with the transaction was $58 million, which included make-whole premiums, unamortized fees, hedges and discounts. PPL Capital Funding also redeemed its $450 million of 5.90% Junior Subordinated Notes due in 2073 at par. The loss on extinguishment associated with this transaction was $15 million, which included unamortized fees.
In July 2021, LKE redeemed at par the $250 million 4.375% Senior Notes due 2021.
PPL has guaranteed PPL Capital Funding's obligations under the credit agreement and notes.
(PPL and PPL Electric)
In June 2021, PPL Electric issued $650 million of First Mortgage Bonds, Floating Rate Series due 2024. PPL Electric received proceeds of $490$647 million, net of a discount and underwriting fees, which were used to repay short-term debt obligationsredeem its $400 million outstanding First Mortgage Bonds, 3% Series due 2021 in July 2021 and for general corporate purposes.
(PPL and PPL Electric)
In April 2017,2021, the Louisville/Jefferson County Metro Government of Kentucky remarketed $128 million of Pollution Control Revenue Bonds, 2003 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.50%2.00% through their mandatory purchasematurity date of AprilOctober 1, 2019.2033.
In June 2017,May 2021, the County of Trimble, Kentucky issued $60remarketed $35 million of Environmental FacilitiesPollution Control Revenue Refunding Bonds, 20172001 Series A (Louisville Gas and Electric Company Project)B due 2033 on behalf of LG&E. The bonds were issued bearing interest at a rate of 3.75% through their maturity and are subject to an optional redemption on or after June 1, 2027. The proceeds of the bonds were used to redeem $60 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued by the County of Trimble, Kentucky on behalf of LG&E.
In June 2017,May 2021, the Louisville/Jefferson County Metro Government of Kentucky remarketed $35 million of Environmental FacilitiesPollution Control Revenue Refunding Bonds, 20072001 Series B (Louisville Gas and Electric Company Project) due 20332027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25%1.35% through their mandatory purchasematurity date of June 3, 2019.November 1, 2027.
In October 2017,June 2021, LG&E entered into a $200converted the $31 million term loan credit facility with a term expiring in October 2019. As of December 31, 2017, LG&E had outstanding borrowings of $100 million under this agreement at a rate of 2.06%. In January 2018, LG&E borrowed the remaining $100 million available under this facility.
In June 2021, LG&E converted the $35 million of Louisville/Jefferson County Metro Government, of Kentucky Environmental Facilities Revenue Refunding Bonds, 2007 Series B issued on its behalf to a weekly interest rate. The bonds mature on June 1, 2033.
In September 2021, the County of Trimble, Kentucky remarketed $28 million of Pollution Control Revenue Bonds, 2001 Series A (Louisville Gasdue 2026, previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and Electric Company Project)will bear interest at 0.625% through their maturity date of September 1, 2026.
(PPL and KU)
In June 2021, the County of Carroll, Kentucky remarketed $54 million of Environmental Facilities Revenue Refunding Bonds, 2006 Series B due 2027.2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 2.125% though their maturity date of October 1, 2034.
In June 2021, the County of Carroll, Kentucky remarketed $78 million of Environmental Facilities Revenue Bonds 2008 Series A due 2032 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 2.00% through their maturity date of February 1, 2032.
See Note 15 for additional information related to intercompany borrowings.
Legal Separateness(All Registrants)
The subsidiaries of PPL are separate legal entities. PPL's subsidiaries are not liable for the debts of PPL. Accordingly, creditors of PPL may not satisfy their debts from the assets of PPL's subsidiaries absent a specific contractual undertaking by a subsidiary to pay PPL's creditors or as required by applicable law or regulation. Similarly, PPL is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of PPL's subsidiaries may not satisfy their debts from the assets of PPL or its other subsidiaries absent a specific contractual undertaking by PPL or its other subsidiaries to pay the creditors or as required by applicable law or regulation.
Similarly, the subsidiaries of PPL Electric and LKE are each separate legal entities. These subsidiaries are not liable for the debts of PPL Electric and LKE.Electric. Accordingly, creditors of PPL Electric and LKE may not satisfy theirits debts from the assets of
134
(PPL)
Equity Securities
Share Repurchases
In August 2021, PPL's Board of Directors authorized share repurchases of up to $3 billion of PPL common shares. The actual amount repurchased will depend on various factors, including PPL’s share price, market conditions, and the determination of other uses for the proceeds from the sale of the U.K. utility business, including for incremental capital expenditures. PPL may purchase shares on each trading day subject to market conditions and principles of best execution.
During the year ended December 31, 2021, PPL repurchased 34.8 million shares at a cost of $1.0 billion. Commission fees incurred, which have been included in the cost of repurchases above, were insignificant through December 31, 2021.
ATM Program
In February 2015,2018, PPL entered into two separatean equity distribution agreements,agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $500 million$1.0 billion of its common stock.stock through an at-the-market offering program, including a forward sales component. The compensation paid to the selling agents by PPL may be up to 1%2% of the gross offering proceeds of the shares sold with respect to each equity distribution agreement. PPL issuedshares. There were no issuances under the followingATM program for the yearstwelve months ended December 31:31, 2021 and 2020. The ATM program expired in February 2021.
| 2017 | 2016 | 2015 | |||||||||
| Number of shares (in thousands) | 10,373 | 710 | 1,477 | ||||||||
| Net Proceeds | $ | 377 | $ | 25 | $ | 49 | |||||
Distributions and Related Restrictions
In November 2017,2021, PPL declared its quarterly common stock dividend, payable January 2, 2018,3, 2022, at 39.541.50 cents per share (equivalent to $1.58$1.66 per annum). On February 22, 2018,18, 2022, PPL announced that the company is increasing itsa quarterly common stock dividend to 41.0of 20.00 cents per share, on a quarterly basis (equivalentpayable April 1, 2022, to $1.64 per annum).shareowners of record as of March 10, 2022. Future dividends will be declared at the discretion of the Board of Directors and will depend upon future earnings, cash flows, financial and legal requirements and other factors.
Neither PPL Capital Funding nor PPL may declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067 or 2013 Series B Junior Subordinated Notes due 2073.2067. At December 31, 2017,2021, no interest payments were deferred.
(All Registrants)
PPL relies on dividends or loans from its subsidiaries to fund PPL's dividends to its common shareholders. The net assets of certain PPL subsidiaries are subject to legal restrictions. LKE primarily relies on dividends from its subsidiaries to fund its distributions to PPL. LG&E, KU and PPL Electric are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in capital account." The meaning of this limitation has never been clarified under the Federal Power Act. LG&E, KU and PPL Electric believe, however, that this statutory restriction, as applied to their circumstances, would not be construed or applied by the FERC to prohibit the payment from retained earnings of dividends that are not excessive and are for lawful and legitimate business purposes. In February 2012, LG&E and KU petitioned the FERC requesting authorization to pay dividends in the future based on retained earnings balances calculated without giving effect to the impact of purchase accounting adjustments for thePPL's 2010 acquisition of LKE by PPL.LG&E and KU. In May 2012, the FERC approved the petitions with the further condition that each utility may not pay dividends if such payment would cause its adjusted equity ratio to fall below 30% of total capitalization. Accordingly, at December 31, 2017,2021, net assets of $2.7 billion ($1.1$1.4 billion for LG&E and $1.6$1.9 billion for KU)KU were restricted for purposes of paying dividends to LKE, and net assets of $3.1 billion ($1.4$1.7 billion for LG&E and $1.7$2.0 billion for KU)KU were available for payment of dividends to LKE. LG&E and KU believe they will not be required to change their current dividend practices as a result of the foregoing requirement. In addition, under Virginia law, KU is prohibited from making loans to affiliates without the prior approval of the VSCC. There are no comparable statutes under Kentucky law applicable to LG&E and KU, or under Pennsylvania law applicable to PPL Electric. However, orders from the KPSC require LG&E and KU to obtain prior consent or approval before lending amounts to PPL.
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(PPL)
Discontinued Operations
On March 17, 2021, PPL Energy Supply and all of the common stock of Talen Energy.
On June 14, 2021, the sale of the U.K. utility business was completed.The transaction resulted in cash proceeds of $10.7 billion inclusive of foreign currency hedges executed by PPL. PPL common stock they owned on May 20, 2015. Followingreceived net proceeds, after taxes and fees, of $10.4 billion.
WPD Limited and National Grid U.K. each made customary representations and warranties in the WPD SPA. National Grid U.K., at its expense, purchased warranty and indemnity insurance. WPD Limited agreed to indemnify National Grid U.K. for certain tax related matters. See Note 14 for additional information. PPL has not had and will not have any significant involvement with the U.K. utility business after completion of these transactions, PPL shareowners owned 65% of Talen Energy and affiliates of Riverstone owned 35%. The spinoff had no effect on the number of PPL common shares owned by PPL shareowners or the number of shares of PPL common stock outstanding. The transaction is intended to be tax-free to PPL and its shareowners for U.S. federal income tax purposes.sale.
Loss on SpinoffSale
The following table summarizes PPL's fair value analysis:
| Approach | Weighting | Weighted Fair Value (in billions) | ||||
| Talen Energy Market Value | 50% | $ | 1.4 | |||
| Income/Discounted Cash Flow | 30% | 1.1 | ||||
| Alternative Market (Comparable Company) | 20% | 0.7 | ||||
| Estimated Fair Value | $ | 3.2 | ||||
| Loss on sale for the year ended December 31, 2021 | |||||
| Sales proceeds, net of realized foreign currency hedge losses (a) | $ | 10,732 | |||
| Unrealized foreign currency hedge losses recognized in 2020 | 125 | ||||
| Less: Costs to sell (b) | 69 | ||||
| Less: Carrying value (c) | 12,397 | ||||
| Loss on sale | $ | (1,609) | |||
(a)Includes the fixed and estimated charges for employee separation benefits were recordedadditional consideration of £7,881 million specified in 2014. In 2015, the organizational structures were finalized for both PPL and Talen Energy, which resulted in an additional chargeWPD SPA, converted at a spot rate of $10 million for employee separation benefits. Of this amount, $2 million related to Energy Supply positions and is reflected in discontinued operations. The remaining $8 million is reflected in "Other operation and maintenance" on the 2015 PPL Consolidated Statement of Income. The separation benefits include cash severance compensation, lump sum COBRA reimbursement payments and outplacement services.
(c)Represents the formationcarrying value of the Talen Energy organizationU.K. utility business at the time of sale and to reconfigureincludes the remaining PPL service functions. These costs are recordedrealization of AOCI of $3.6 billion, which arose primarily in "Other operationfrom currency translation adjustments and maintenance" ondefined benefit plans associated with the 2015 Statement of Income.U.K. utility business.
Summarized Results of Discontinued Operations
The operations of the Supply segmentU.K. utility business are included in "Loss"Income (Loss) from Discontinued Operations (net of income taxes)" on the StatementStatements of Income. Following are the components of Discontinued Operationsdiscontinued operations in the StatementStatements of Income for the periodyears ended December 31:
| 2021 | 2020 | 2019 | |||||||||||||||
| Operating Revenues | $ | 1,344 | $ | 2,133 | $ | 2,167 | |||||||||||
| Operating Expenses | 467 | 916 | 853 | ||||||||||||||
| Other Income (Expense) - net | 202 | 167 | 295 | ||||||||||||||
| Interest Expense (a) | 209 | 367 | 373 | ||||||||||||||
| Income before income taxes | 870 | 1,017 | 1,236 | ||||||||||||||
| Loss on sale | (1,609) | — | — | ||||||||||||||
| Income Taxes | 759 | 188 | 226 | ||||||||||||||
| Income (Loss) from Discontinued Operations (net of income taxes) | $ | (1,498) | $ | 829 | $ | 1,010 | |||||||||||
(a)No interest from corporate level debt was allocated to discontinued operations.
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| 2015 | |||
| Operating revenues | $ | 1,427 | |
| Operating expenses | 1,328 | ||
| Other Income (Expense) - net | (21 | ) | |
| Interest expense (a) | 150 | ||
| Income tax expense (benefit) | (30 | ) | |
| Loss on spinoff | (879 | ) | |
| Loss from Discontinued Operations (net of income taxes) | $ | (921 | ) |
The following major classes of assets and liabilities of the U.K. utility business were reclassified on PPL's Balance Sheet to "Current assets held for sale" and "Current liabilities held for sale" as of December 31, 2020:
| Held for Sale at December 31, 2020 | |||||||||||
| Cash and cash equivalents | $ | 266 | |||||||||
| Accounts receivable and unbilled revenues | 389 | ||||||||||
| Price risk management assets | 146 | ||||||||||
| Property, plant and equipment, net (a) | 14,392 | ||||||||||
| Goodwill | 2,558 | ||||||||||
| Other intangibles | 413 | ||||||||||
| Pension benefit asset | 682 | ||||||||||
| Other assets | 137 | ||||||||||
| Total Assets | $ | 18,983 | |||||||||
| Short-term debt and long-term debt due within one year | $ | 994 | |||||||||
| Accounts payable | 220 | ||||||||||
| Customer deposits | 217 | ||||||||||
| Accrued interest | 190 | ||||||||||
| Long-term debt | 7,938 | ||||||||||
| Total deferred income taxes | 1,032 | ||||||||||
| Price risk management liabilities | 137 | ||||||||||
| Other deferred credits and liabilities | 295 | ||||||||||
| Total Liabilities | $ | 11,023 | |||||||||
| Net assets (b) | $ | 7,960 | |||||||||
(a)Depreciation of fixed assets after recognitionceased upon classification as held for sale in the first quarter of 2021.
(b)The net assets and liabilities held for sale exclude $4.0 billion of AOCI related to the U.K. utility business that is required to be included in the carrying value of an entity classified as held for sale when assessing impairment and determining the gain or loss on sale. Prior to the sale, AOCI related to the U.K. utility business was reported as a component of PPL’s equity.
Acquisitions
Share Purchase Agreement to Acquire Narragansett Electric
On March 17, 2021, PPL and its subsidiary, PPL Energy Holdings, entered into a share purchase agreement (Narragansett SPA) with National Grid USA (National Grid U.S.), a subsidiary of National Grid plc, to acquire 100% of the loss on the spinoff,outstanding shares of $3.2common stock of Narragansett Electric for approximately $3.8 billion were distributed toin cash. On May 3, 2021, an Assignment and Assumption Agreement was entered into by PPL, shareowners in the June 1, 2015, spinoffPPL Energy Holdings, PPL Rhode Island Holdings and National Grid U.S. whereby certain interests of PPL Energy Supply.
final MDPU order. That request remains pending. If a stay is issued, PPL would not be able to close the acquisition until any stay is lifted or the appeal is resolved. On September 23, 2021, the FERC issued an order authorizing, as consistent with the public interest, the disposition of jurisdictional facilities that will result in responsePPL Rhode Island Holdings, LLC, acquiring 100% of the outstanding shares of common stock of Narragansett Electric. The regulatory approvals remain subject to any applicable appeal periods. PPL Electric's December 2011 request for ratemaking incentives for the Northeast/Pocono Reliability project (a new 58-mile, 230 kV transmission line that includes three new substations and upgrades to adjacent facilities). The FERC granted the incentive for inclusion in rate base of all prudently incurred construction work in progress costs but denied the requested incentive for a 100 basis point adder to the return on equity.
PPL Energy Holdings and PPL Rhode Island Holdings and National Grid U.S. have each made customary representations, warranties and covenants in the Narragansett SPA, including, among others, customary indemnification provisions and covenants by National Grid U.S. to conduct the Narragansett Electric business in the ordinary course between the execution of the Narragansett SPA and the closing of the acquisition. The line was energizedconsummation of the transaction is not subject to a financing condition.
In connection with the acquisition, National Grid U.S. and one or more of its subsidiaries and Narragansett Electric will enter into a transition services agreement, pursuant to which National Grid U.S. and/or one or more of its affiliates will agree to provide certain transition services to Narragansett Electric and its affiliates to facilitate the operation of Narragansett Electric following the consummation of the acquisition and the transition of operations to PPL, as agreed upon in April 2016, completing the approximately $350 million project,Narragansett SPA.
10. Leases
(All Registrants)
The Registrants determine whether contractual arrangements contain a lease by evaluating whether those arrangements either implicitly or explicitly identify an asset, whether the Registrants have the right to obtain substantially all of the economic benefits from use of the asset throughout the term of the arrangement, and whether the Registrants have the right to direct the use of the asset. Renewal options are included in the lease term if it is reasonably certain the Registrants will exercise those options. Periods for which includes additional substation security enhancements. Coststhe Registrants are reasonably certain not to exercise termination options are also included in the lease term. The Registrants have certain agreements with lease and non-lease components, such as office space leases, which are generally accounted for separately.
LG&E and KU have entered into various operating leases primarily for office space, vehicles and railcars. The leases generally have fixed payments with expiration dates ranging from 2022 to 2033, some of which have options to extend the leases from one year to ten years and some have options to terminate at LG&E's and KU's discretion.
PPL has also entered into various operating leases primarily for office and warehouse space. These leases generally have fixed payments with expiration dates ranging from 2024 through 2030.
PPL Electric also has operating leases which do not have a significant impact to its operations.
Short-term Leases
Short-term leases are leases with a term that is 12 months or less and do not include a purchase option or option to extend the initial term of the lease to greater than 12 months that the Registrants are reasonably certain to exercise. The Registrants have made an accounting policy election to not recognize the right-of-use asset and the lease liability arising from leases classified as short-term. Expenses related to the projectshort-term leases are included in the tables below.
Discount Rate
The discount rate for a lease is the rate implicit in the lease unless that rate cannot be readily determined. In that case, the Registrants are required to use their incremental borrowing rate, which is the rate the Registrants would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the Balance Sheets, primarilylease payments in "Regulated utility plant."a similar economic environment.
The Registrants receive secured borrowing rates from financial institutions based on their applicable credit profiles. The Registrants use the secured rate which corresponds with the term of the applicable lease.
(PPL, LKE, LG&E and KU)
The following table provides the components of lease cost for the lease of office space, vehicles, land, gas storage and other equipment.
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | |||||||||||||||||
| Lease cost: | |||||||||||||||||
| Operating lease cost | $ | 24 | $ | 28 | $ | 30 | |||||||||||
| Short-term lease cost | 6 | 7 | 5 | ||||||||||||||
| Total lease cost | $ | 30 | $ | 35 | $ | 35 | |||||||||||
| LG&E | |||||||||||||||||
| Lease cost: | |||||||||||||||||
| Operating lease cost | $ | 6 | $ | 8 | $ | 12 | |||||||||||
| Short-term lease cost | 1 | 1 | 1 | ||||||||||||||
| Total lease cost | $ | 7 | $ | 9 | $ | 13 | |||||||||||
| KU | |||||||||||||||||
| Lease cost: | |||||||||||||||||
| Operating lease cost | $ | 10 | $ | 13 | $ | 13 | |||||||||||
| Short-term lease cost | 1 | 1 | 1 | ||||||||||||||
| Total lease cost | $ | 11 | $ | 14 | $ | 14 | |||||||||||
The following table provides other key information related to the Registrants' operating leases was as follows:at December 31:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | |||||||||||||||||
| Cash paid for amounts included in the measurement of lease liabilities: | |||||||||||||||||
| Operating cash flows from operating leases | $ | 23 | $ | 24 | $ | 26 | |||||||||||
| Right-of-use asset obtained in exchange for new operating lease liabilities | 12 | 17 | 45 | ||||||||||||||
| LG&E | |||||||||||||||||
| Cash paid for amounts included in the measurement of lease liabilities: | |||||||||||||||||
| Operating cash flows from operating leases | $ | 6 | $ | 7 | $ | 9 | |||||||||||
| Right-of-use asset obtained in exchange for new operating lease liabilities | 4 | 6 | 5 | ||||||||||||||
| KU | |||||||||||||||||
| Cash paid for amounts included in the measurement of lease liabilities: | |||||||||||||||||
| Operating cash flows from operating leases | $ | 10 | $ | 11 | $ | 11 | |||||||||||
| Right-of-use asset obtained in exchange for new operating lease liabilities | 7 | 9 | 11 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 45 | $ | 50 | $ | 49 | |||||
| LKE | 26 | 26 | 24 | ||||||||
| LG&E | 15 | 15 | 12 | ||||||||
| KU | 11 | 11 | 11 | ||||||||
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| PPL | LKE | LG&E | KU | ||||||||||||
| 2018 | $ | 32 | $ | 26 | $ | 15 | $ | 10 | |||||||
| 2019 | 19 | 16 | 8 | 8 | |||||||||||
| 2020 | 13 | 11 | 5 | 6 | |||||||||||
| 2021 | 10 | 8 | 3 | 5 | |||||||||||
| 2022 | 8 | 6 | 2 | 4 | |||||||||||
| Thereafter | 22 | 15 | 6 | 8 | |||||||||||
| Total | $ | 104 | $ | 82 | $ | 39 | $ | 41 | |||||||
| PPL | LG&E | KU | |||||||||||||||
| 2022 | $ | 23 | $ | 6 | $ | 10 | |||||||||||
| 2023 | 20 | 5 | 8 | ||||||||||||||
| 2024 | 15 | 4 | 6 | ||||||||||||||
| 2025 | 8 | 3 | 4 | ||||||||||||||
| 2026 | 3 | 1 | 1 | ||||||||||||||
| Thereafter | 5 | 1 | 1 | ||||||||||||||
| Total | $ | 74 | $ | 20 | $ | 30 | |||||||||||
Weighted-average discount rate | 3.38% | 3.48% | 3.67% | ||||||||||||||
Weighted-average remaining lease term (in years) | 4 | 4 | 4 | ||||||||||||||
| Current lease liabilities (a) | $ | 22 | $ | 6 | $ | 9 | |||||||||||
| Non-current lease liabilities (a) | 47 | 12 | 17 | ||||||||||||||
| Right-of-use assets (b) | 62 | 15 | 24 | ||||||||||||||
(a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting.
Lessor Transactions
Third parties leased land from LG&E and KU at certain generation plants to produce refined coal used to generate electricity. The leases were operating leases and expired in 2021. Payments were allocated among lease and non-lease components as stated in the agreements. Lease payments were fixed or determined based on the amount of refined coal used in electricity generation at the facility. Payments received were primarily recorded as a regulatory liability and amortized in accordance with regulatory approvals.
The following table shows the lease income recognized for the years ended December 31:
| PPL | LG&E | KU | |||||||||||||||
| Lease income recognized for the twelve months ended December 31, 2021 | $ | 11 | $ | 5 | $ | 5 | |||||||||||
| Lease income recognized for the twelve months ended December 31, 2020 | 16 | 6 | 9 | ||||||||||||||
| Lease income recognized for the twelve months ended December 31, 2019 | 14 | 5 | 8 | ||||||||||||||
11. Stock-Based Compensation
(PPL and PPL Electric and LKE)Electric)
Under the ICP, SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Electric LKE and other affiliated companies. Awards under the Plans are made by the Compensation Governance and Nominating Committee (CGNC) of the PPL Board of Directors, in the case of the ICP and SIP, and by the PPL Corporate Leadership Council (CLC), in the case of the ICPKE.
The following table details the award limits under each of the Plans.
| Total Plan | Annual Grant Limit Total As % of Outstanding | Annual Grant | Annual Grant Limit For Individual Participants - Performance Based Awards | |||||||||||||||||||||||||||||
| Award Limit | PPL Common Stock On First Day of | Limit Options | For awards denominated in | For awards denominated in | ||||||||||||||||||||||||||||
| Plan | (Shares) | Each Calendar Year | (Shares) | shares (Shares) | cash (in dollars) | |||||||||||||||||||||||||||
| SIP | 15,000,000 | 2,000,000 | 750,000 | $ | 15,000,000 | |||||||||||||||||||||||||||
| ICPKE | 14,199,796 | 2 | % | 3,000,000 | ||||||||||||||||||||||||||||
Any portion of these awards that has not been granted may be carried over and used in any subsequent year. If any award lapses, is forfeited or the rights of the participant terminate, or, with respect to certain awards, is forfeited, and the shares of PPL common stock underlying such an award are again available for grant. Shares delivered under the Plans may be in the form of authorized
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and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws.
Restricted Stock Units
Restricted stock units are awardsrepresent the right to receive shares of PPL common stock in the future, generally three years after the date of grant, in an amount based on the fair value of PPL common stock on the date of grant. Actual PPL common shares will be issued upon completion of a restriction period, generally three years.
Under the SIP, each restricted stock unit entitles the executivegrant recipient to accrue additional restricted stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICPKE are currently paid in cash when dividends are declared by PPL.
The fair value of restricted stock units granted is recognized on a straight-line basis over the servicerestriction period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restrictions lapse on restricted stock units fully, in certain situations, as defined by each of the Plans.
The weighted-average grant date fair value of restricted stock units granted was:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 28.00 | $ | 35.30 | $ | 31.95 | |||||||||||
| PPL Electric | 27.96 | 35.37 | 32.33 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 35.30 | $ | 33.84 | $ | 34.50 | |||||
| PPL Electric | 35.45 | 34.32 | 34.41 | ||||||||
| LKE | 35.25 | 33.73 | 34.89 | ||||||||
Restricted stock unit activity for 20172021 was:
| Restricted Shares/Units | Weighted- Average Grant Date Fair Value Per Share | ||||||||||
| PPL | |||||||||||
| Nonvested, beginning of period | 896,336 | $ | 32.56 | ||||||||
| Granted | 458,610 | 28.00 | |||||||||
| Vested | (303,890) | 30.57 | |||||||||
| Forfeited | (46,473) | 30.23 | |||||||||
| Nonvested, end of period | 1,004,583 | 31.19 | |||||||||
| PPL Electric | |||||||||||
| Nonvested, beginning of period | 210,720 | $ | 32.73 | ||||||||
| Transfer between registrants | (92,596) | 32.99 | |||||||||
| Granted | 51,587 | 27.96 | |||||||||
| Vested | (32,266) | 29.98 | |||||||||
| Forfeited | (6,158) | 32.16 | |||||||||
| Nonvested, end of period | 131,287 | 31.50 | |||||||||
Restricted Shares/Units | Weighted- Average Grant Date Fair Value Per Share | |||||
| PPL | ||||||
| Nonvested, beginning of period | 1,337,025 | $ | 31.57 | |||
| Granted | 538,441 | 35.30 | ||||
| Vested | (567,001 | ) | 29.28 | |||
| Forfeited | (16,816 | ) | 34.28 | |||
| Nonvested, end of period (a) | 1,291,649 | 34.10 | ||||
Restricted Shares/Units | Weighted- Average Grant Date Fair Value Per Share | |||||
| PPL Electric | ||||||
| Nonvested, beginning of period | 204,570 | $ | 31.27 | |||
| Transfer between registrants | (5,250 | ) | 32.05 | |||
| Granted | 79,321 | 35.45 | ||||
| Vested | (91,117 | ) | 28.83 | |||
| Forfeited | (3,108 | ) | 34.68 | |||
| Nonvested, end of period | 184,416 | 34.20 | ||||
| LKE | ||||||
| Nonvested, beginning of period | 243,281 | $ | 31.53 | |||
| Transfer between registrants | 25,337 | 31.61 | ||||
| Granted | 97,775 | 35.25 | ||||
| Vested | (125,612 | ) | 29.68 | |||
| Forfeited | (9,224 | ) | 34.04 | |||
| Nonvested, end of period | 231,557 | 34.01 | ||||
Substantially all restricted stock unit awards are expected to vest.
The total fair value of restricted stock units vesting for the years ended December 31 was:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 8 | $ | 19 | $ | 13 | |||||||||||
| PPL Electric | 1 | 3 | 2 | ||||||||||||||
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Performance Units - Total Shareowner Return
Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three-yearthree-year performance period. At the end of the period, payout is determined by comparing PPL's performance to the TSR of the companies included in the Philadelphia Stock ExchangePHLX Utility Sector Index. Awards are payable on a graduated basis based on thresholds that measure PPL's performance relative to peers that comprise the applicable index on which each years'year's awards are measured. Awards can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the Compensation Committee's determination of the CGNCachievement of whether the performance goals have been achieved.goals. Under the plan provisions, TSR performance units are subject to forfeiture upon termination of employment except forother than retirement, one year or more from commencement of the performance period, disability or death of an employee.
The fair value of TSR performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one-yearone-year period, the minimum vesting period required for an employee to be entitled to payout of the awards with no proration. For employees who are not retirement-eligible, compensation expense is recognized over the shorter of the three-yearthree-year performance period or the period until the employee is retirement-eligible, with a minimum vesting and recognition period of one-year.one-year. If an employee retires before the one-year vesting period, the performance units are forfeited. Performance units vest on a pro rata basis, in certain situations, as defined by each of the Plans.
The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a
U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards.
The weighted-average assumptions used in the model were:
| 2021 | 2020 | 2019 | |||||||||||||||
| Expected stock volatility | 27.81% | 15.64% | 17.57% | ||||||||||||||
| Expected life | 3 years | 3 years | 3 years | ||||||||||||||
| 2017 | 2016 | 2015 | ||||||
| Expected stock volatility | 17.40 | % | 19.60 | % | 15.90 | % | ||
| Expected life | 3 years | 3 years | 3 years | |||||
The weighted-average grant date fair value of TSR performance units granted was:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 32.44 | $ | 37.63 | $ | 35.83 | |||||||||||
| PPL Electric | 32.92 | 38.64 | 35.68 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 38.38 | $ | 35.74 | $ | 36.76 | |||||
| PPL Electric | 38.37 | 35.68 | 37.93 | ||||||||
| LKE | 38.24 | 35.28 | 37.10 | ||||||||
TSR performance unit activity for 20172021 was:
| TSR Performance Units | Weighted- Average Grant Date Fair Value Per Share | ||||||||||
| PPL | |||||||||||
| Nonvested, beginning of period | 626,254 | $ | 36.98 | ||||||||
| Granted | 306,009 | 32.44 | |||||||||
| Vested | (53,340) | 34.47 | |||||||||
| Forfeited (a) | (245,150) | 37.75 | |||||||||
| Nonvested, end of period | 633,773 | 34.68 | |||||||||
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| TSR Performance Units | Weighted- Average Grant Date Fair Value Per Share | ||||||||||||||||
| TSR Performance Units | Weighted- Average Grant Date Fair Value Per Share | ||||||||||||||||
| PPL | |||||||||||||||||
| Nonvested, beginning of period | 1,070,536 | $ | 34.65 | ||||||||||||||
| Granted | 293,642 | 38.38 | |||||||||||||||
| Vested | (243,983 | ) | 32.42 | ||||||||||||||
| Forfeited | (141,964 | ) | 32.27 | ||||||||||||||
| Nonvested, end of period (a) | 978,231 | 36.67 | |||||||||||||||
| PPL Electric | PPL Electric | ||||||||||||||||
| Nonvested, beginning of period | 76,726 | $ | 34.68 | ||||||||||||||
| Granted | 26,086 | 38.37 | |||||||||||||||
| Vested | (14,713 | ) | 32.14 | ||||||||||||||
| Forfeited | (12,586 | ) | 35.45 | ||||||||||||||
| Nonvested, end of period | 75,513 | 37.00 | |||||||||||||||
| LKE | |||||||||||||||||
| Nonvested, beginning of period | 191,601 | $ | 34.34 | Nonvested, beginning of period | 61,807 | $ | 37.44 | ||||||||||
| Transfer between registrants | 8,307 | 35.96 | Transfer between registrants | (53,663) | 37.42 | ||||||||||||
| Granted | 64,555 | 38.24 | Granted | 10,010 | 32.92 | ||||||||||||
| Vested | (48,980 | ) | 32.09 | ||||||||||||||
| Forfeited | (35,194 | ) | 35.25 | ||||||||||||||
| Forfeited (a) | Forfeited (a) | (2,800) | 38.47 | ||||||||||||||
| Nonvested, end of period | 180,289 | 36.69 | Nonvested, end of period | 15,354 | 34.36 | ||||||||||||
For the year ended December 31, 2017, 20162021, $2 million of TSR performance units vested. All awards vested were associated with the sale of the U.K. utility business. See Note 9 for additional information on the sale of the U.K. utility business. No TSR performance units vested for the years ended December 31, 2020 and 2015 was $8 million, $12 million and $6 million for PPL and insignificant2019. Amounts for PPL Electric and LKE.are insignificant.
Performance Units - Return on Equity
Beginning in 2017, PPL changed its executive compensation mix to add performance units based on achievement of a corporate Return on Equity (ROE). ROE performance units are intended to further align compensation with the company’s strategy and reward for future corporate performance.
Payout of these performance units will be based on the calculated average of the annual corporate ROE for each year of the three-yearthree-year performance period for PPL Corporation. In light of the transformational nature of the potential sale of the U.K. utility business in 2021, PPL’s ROE-based performance units issued for 2021 were based on a one-year performance period from January 1, 2021 to December 31, 2021; however, these units retained the three year vesting schedule and other characteristics. ROE performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable ROE performance goal. ROE performance units can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the Compensation Committee's determination of the CGNCachievement of whether the performance goals have been achieved.goals. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment except forother than retirement, disability or death of an employee.
The fair value of each ROE performance unit is based on the closing price of PPL Common Stock on the date of grant. The fair value of ROE performance units is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value awards granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. As these awards are based on performance conditions, the level of attainment is monitored each reporting period and compensation expense is adjusted based on the expected attainment level.
The weighted-average grant date fair value of ROE performance units granted was:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 30.08 | $ | 34.95 | $ | 30.89 | |||||||||||
| PPL Electric | 29.39 | 35.59 | 30.76 | ||||||||||||||
143
ROE performance unit activity for 20172021 was:
| ROE Performance Unit | Weighted- Average Grant Date Fair Value Per Share | ||||||||||
| PPL | |||||||||||
| Nonvested, beginning of period | 728,664 | $ | 32.81 | ||||||||
| Granted | 572,571 | 30.08 | |||||||||
| Vested | (570,722) | 32.02 | |||||||||
| Forfeited | (8,160) | 30.44 | |||||||||
| Nonvested, end of period | 722,353 | 31.28 | |||||||||
| PPL Electric | |||||||||||
| Nonvested, beginning of period | 61,807 | $ | 33.01 | ||||||||
| Transfer between registrants | (53,663) | 33.00 | |||||||||
| Granted | 12,895 | 29.39 | |||||||||
| Vested | (5,685) | 32.27 | |||||||||
| Nonvested, end of period | 15,354 | 30.27 | |||||||||
| ROE Performance Unit | Weighted- Average Grant Date Fair Value Per Share | |||||
| PPL | ||||||
| Granted | 97,925 | $ | 34.42 | |||
| Forfeited | (997 | ) | 34.41 | |||
| Nonvested, end of period | 96,928 | 34.42 | ||||
| PPL Electric | ||||||
| Granted | 8,696 | $ | 34.41 | |||
| Nonvested, end of period | 8,696 | 34.41 | ||||
| LKE | ||||||
| Granted | 21,536 | $ | 34.29 | |||
| Forfeited | (997 | ) | 34.41 | |||
| Nonvested, end of period | 20,539 | 34.29 | ||||
The total fair value of ROE performance units vesting for the years ended December 31 was:
| 2021 | 2020 | ||||||||||||||||
| PPL | $ | 16 | $ | 8 | |||||||||||||
| PPL Electric | — | 1 | |||||||||||||||
Stock Options
PPL's CGNCCompensation, Governance and Nominating Committee, now known as the Compensation Committee, eliminated the use of stock options due to changes in its long-term incentive mix beginning in January 2014.
Under the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2017,2021, are fully vested. All options expire no later than 10 years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans.
Stock option activity for 20172021 was:
| Number of Options | Weighted Average Exercise Price Per Share | Weighted- Average Remaining Contractual Term (years) | Aggregate Total Intrinsic Value | ||||||||||||||||||||
| PPL | |||||||||||||||||||||||
| Outstanding at beginning of period | 1,103,016 | $ | 26.22 | ||||||||||||||||||||
| Exercised | (337,014) | 25.42 | |||||||||||||||||||||
| Outstanding and exercisable at end of period | 766,002 | 26.57 | 1 | $ | 3 | ||||||||||||||||||
Number of Options | Weighted Average Exercise Price Per Share | Weighted- Average Remaining Contractual Term (years) | Aggregate Total Intrinsic Value | |||||||||
| PPL | ||||||||||||
| Outstanding at beginning of period | 4,481,160 | $ | 28.98 | |||||||||
| Exercised | (718,977 | ) | 26.67 | |||||||||
| Outstanding and exercisable at end of period | 3,762,183 | 29.42 | 3.5 | $ | 14 | |||||||
| PPL Electric | ||||||||||||
| Outstanding at beginning of period | 240,939 | $ | 27.48 | |||||||||
| Exercised | (42,659 | ) | 26.99 | |||||||||
| Outstanding and exercisable at end of period | 198,280 | 27.58 | 3.8 | $ | 1 | |||||||
Number of Options | Weighted Average Exercise Price Per Share | Weighted- Average Remaining Contractual Term (years) | Aggregate Total Intrinsic Value | |||||||||
| LKE | ||||||||||||
| Outstanding at beginning of period | 61,896 | $ | 25.81 | |||||||||
| Exercised | (28,164 | ) | 26.59 | |||||||||
| Outstanding and exercisable at end of period | 33,732 | 25.15 | 4.1 | $ | — | |||||||
For 2017, 20162021, 2020 and 2015,2019, PPL received $19$10 million, $52$8 million and $97$53 million in cash from stock options exercised. The total intrinsic value of stock options exercised was insignificant in 2021 and 2020 and $11 million in 2019. The related income tax benefits realized were not significant.
Compensation Expense
Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric and LKE includes an allocation of PPL Services' expense, was:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 34 | $ | 28 | $ | 35 | |||||||||||
| PPL Electric | 11 | 10 | 12 | ||||||||||||||
144
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 32 | $ | 27 | $ | 33 | |||||
| PPL Electric | 18 | 16 | 14 | ||||||||
| LKE | 8 | 7 | 8 | ||||||||
The income tax benefit related to above compensation expense was as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 10 | $ | 8 | $ | 10 | |||||||||||
| PPL Electric | 3 | 3 | 3 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 13 | $ | 12 | $ | 14 | |||||
| PPL Electric | 8 | 7 | 6 | ||||||||
| LKE | 3 | 3 | 3 | ||||||||
At December 31, 2017,2021, unrecognized compensation expense related to nonvested stock awards was:
| Unrecognized Compensation Expense | Weighted- Average Period for Recognition | ||||||||||
| PPL | $ | 19 | 1.7 | ||||||||
| PPL Electric | 2 | 1.8 | |||||||||
Unrecognized Compensation Expense | Weighted- Average Period for Recognition | ||||
| PPL | $ | 10 | 1.7 | ||
| PPL Electric | 2 | 1.7 | |||
| LKE | 1 | 1.6 | |||
(All Registrants)
Defined Benefits
The defined benefit pension plans of LKE and its subsidiaries were closed to new salaried and bargaining unit employees hired after December 31, 2005. Employees hired after December 31, 2005 receive additional company contributions above the standard matching contributions to their savings plans.
PPL and certain of its subsidiaries also provide supplemental retirement benefits to executives and other key management employees through unfunded nonqualified retirement plans.
145
(PPL)
The following table provides the components of net periodic defined benefit costs (credits) for PPL's domestic (U.S.) and WPD's (U.K.) pension and other postretirement benefit plans for the years ended December 31.
| Pension Benefits | |||||||||||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | |||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | |||||||||||||||||||||||||||
| Net periodic defined benefit costs (credits): | |||||||||||||||||||||||||||||||||||
| Service cost | $ | 65 | $ | 66 | $ | 96 | $ | 76 | $ | 69 | $ | 79 | $ | 7 | $ | 7 | $ | 11 | |||||||||||||||||
| Interest cost | 168 | 174 | 194 | 178 | 235 | 314 | 23 | 26 | 26 | ||||||||||||||||||||||||||
| Expected return on plan assets | (231 | ) | (228 | ) | (258 | ) | (514 | ) | (504 | ) | (523 | ) | (22 | ) | (22 | ) | (26 | ) | |||||||||||||||||
| Amortization of: | |||||||||||||||||||||||||||||||||||
| Prior service cost (credit) | 10 | 8 | 7 | — | — | — | (1 | ) | — | 1 | |||||||||||||||||||||||||
| Actuarial (gain) loss | 69 | 50 | 84 | 144 | 138 | 158 | 1 | 1 | — | ||||||||||||||||||||||||||
Net periodic defined benefit costs (credits) prior to settlements and termination benefits | 81 | 70 | 123 | (116 | ) | (62 | ) | 28 | 8 | 12 | 12 | ||||||||||||||||||||||||
| Settlements | 1 | 3 | — | — | — | — | — | — | — | ||||||||||||||||||||||||||
| Termination benefits | 1 | — | — | — | — | — | — | — | — | ||||||||||||||||||||||||||
Net periodic defined benefit costs (credits) | $ | 83 | $ | 73 | $ | 123 | $ | (116 | ) | $ | (62 | ) | $ | 28 | $ | 8 | $ | 12 | $ | 12 | |||||||||||||||
| Pension Benefits | |||||||||||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | |||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | |||||||||||||||||||||||||||
| Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: | |||||||||||||||||||||||||||||||||||
| Divestiture (a) | $ | — | $ | — | $ | (353 | ) | $ | — | $ | — | $ | — | $ | — | $ | — | $ | (6 | ) | |||||||||||||||
| Settlement | (1 | ) | (3 | ) | — | — | — | — | — | — | — | ||||||||||||||||||||||||
| Net (gain) loss | 27 | 253 | 63 | 346 | 7 | 508 | (28 | ) | 9 | (9 | ) | ||||||||||||||||||||||||
Prior service cost (credit) | (1 | ) | 15 | 18 | — | — | — | 8 | — | — | |||||||||||||||||||||||||
| Amortization of: | |||||||||||||||||||||||||||||||||||
| Prior service (cost) credit | (10 | ) | (8 | ) | (7 | ) | — | — | — | 1 | (1 | ) | (1 | ) | |||||||||||||||||||||
| Actuarial gain (loss) | (69 | ) | (50 | ) | (85 | ) | (144 | ) | (138 | ) | (158 | ) | (1 | ) | (1 | ) | — | ||||||||||||||||||
Total recognized in OCI and regulatory assets/liabilities (b) | (54 | ) | 207 | (364 | ) | 202 | (131 | ) | 350 | (20 | ) | 7 | (16 | ) | |||||||||||||||||||||
Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities (b) | $ | 29 | $ | 280 | $ | (241 | ) | $ | 86 | $ | (193 | ) | $ | 378 | $ | (12 | ) | $ | 19 | $ | (4 | ) | |||||||||||||
| U.S. Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | ||||||||||||||||||
| OCI | $ | (53 | ) | $ | 236 | $ | (269 | ) | $ | (25 | ) | $ | 7 | $ | 12 | ||||||||
| Regulatory assets/liabilities | (1 | ) | (29 | ) | (95 | ) | 5 | — | (28 | ) | |||||||||||||
Total recognized in OCI and regulatory assets/liabilities | $ | (54 | ) | $ | 207 | $ | (364 | ) | $ | (20 | ) | $ | 7 | $ | (16 | ) | |||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||
| Net periodic defined benefit costs (credits): | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| Service cost | $ | 56 | $ | 56 | $ | 50 | $ | 6 | $ | 6 | $ | 6 | |||||||||||||||||||||||||||||||||||||||||
| Interest cost | 121 | 146 | 164 | 16 | 19 | 22 | |||||||||||||||||||||||||||||||||||||||||||||||
| Expected return on plan assets | (255) | (246) | (245) | (23) | (21) | (18) | |||||||||||||||||||||||||||||||||||||||||||||||
| Amortization of: | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| Prior service cost (credit) | 8 | 9 | 8 | 1 | 1 | (1) | |||||||||||||||||||||||||||||||||||||||||||||||
| Actuarial (gain) loss | 93 | 89 | 56 | (1) | — | 1 | |||||||||||||||||||||||||||||||||||||||||||||||
| Net periodic defined benefit costs (credits) prior to settlements and termination benefits | 23 | 54 | 33 | (1) | 5 | 10 | |||||||||||||||||||||||||||||||||||||||||||||||
| Settlements (a) | 18 | 23 | 1 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||
| Net periodic defined benefit costs (credits) | $ | 41 | $ | 77 | $ | 34 | $ | (1) | $ | 5 | $ | 10 | |||||||||||||||||||||||||||||||||||||||||
| Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| Settlement | (18) | (23) | (1) | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||
| Net (gain) loss | 42 | (221) | (121) | (53) | (6) | (18) | |||||||||||||||||||||||||||||||||||||||||||||||
| Prior service cost (credit) | 3 | 1 | 2 | — | 5 | — | |||||||||||||||||||||||||||||||||||||||||||||||
| Amortization of: | |||||||||||||||||||||||||||||||||||||||||||||||||||||
| Prior service (cost) credit | (8) | (9) | (8) | (1) | (1) | 1 | |||||||||||||||||||||||||||||||||||||||||||||||
| Actuarial gain (loss) | (93) | (89) | (56) | 1 | — | (1) | |||||||||||||||||||||||||||||||||||||||||||||||
| Total recognized in OCI and regulatory assets/liabilities | (74) | (341) | (184) | (53) | (2) | (18) | |||||||||||||||||||||||||||||||||||||||||||||||
| Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities | $ | (33) | $ | (264) | $ | (150) | $ | (54) | $ | 3 | $ | (8) | |||||||||||||||||||||||||||||||||||||||||
| Pension Benefits | |||||||
| U.S. | U.K. | ||||||
| Prior service cost (credit) | $ | 10 | $ | — | |||
| Actuarial (gain) loss | 86 | 152 | |||||
| Total | $ | 96 | $ | 152 | |||
| Amortization from Balance Sheet: | |||||||
| AOCI | $ | 28 | $ | 152 | |||
| Regulatory assets/liabilities | 68 | — | |||||
| Total | $ | 96 | $ | 152 | |||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | ||||||||||||||||||
| Net periodic defined benefit costs (credits): | |||||||||||||||||||||||
| Service cost | $ | 24 | $ | 23 | $ | 26 | $ | 4 | $ | 5 | $ | 5 | |||||||||||
| Interest cost | 68 | 71 | 68 | 9 | 9 | 9 | |||||||||||||||||
| Expected return on plan assets | (92 | ) | (91 | ) | (88 | ) | (7 | ) | (6 | ) | (6 | ) | |||||||||||
| Amortization of: | |||||||||||||||||||||||
| Prior service cost | 8 | 8 | 7 | 1 | 3 | 3 | |||||||||||||||||
| Actuarial (gain) loss (a) | 31 | 21 | 37 | — | (1 | ) | — | ||||||||||||||||
| Net periodic defined benefit costs (b) | $ | 39 | $ | 32 | $ | 50 | $ | 7 | $ | 10 | $ | 11 | |||||||||||
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: | |||||||||||||||||||||||
| Net (gain) loss | $ | 30 | $ | 119 | $ | 20 | $ | (14 | ) | $ | 6 | $ | (15 | ) | |||||||||
| Prior service cost | 7 | — | 19 | 8 | — | — | |||||||||||||||||
| Amortization of: | |||||||||||||||||||||||
| Prior service credit | (8 | ) | (8 | ) | (7 | ) | (1 | ) | (3 | ) | (3 | ) | |||||||||||
| Actuarial gain (loss) | (32 | ) | (21 | ) | (37 | ) | — | 1 | — | ||||||||||||||
Total recognized in OCI and regulatory assets/liabilities | (3 | ) | 90 | (5 | ) | (7 | ) | 4 | (18 | ) | |||||||||||||
Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities | $ | 36 | $ | 122 | $ | 45 | $ | — | $ | 14 | $ | (7 | ) | ||||||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | ||||||||||||||||||
| OCI | $ | 33 | $ | 42 | $ | 4 | $ | (2 | ) | $ | 2 | $ | (2 | ) | |||||||||
| Regulatory assets/liabilities | (36 | ) | 48 | (9 | ) | (5 | ) | 2 | (16 | ) | |||||||||||||
Total recognized in OCI and regulatory assets/liabilities | $ | (3 | ) | $ | 90 | $ | (5 | ) | $ | (7 | ) | $ | 4 | $ | (18 | ) | |||||||
Pension Benefits | Other Postretirement Benefits | ||||||
| Prior service cost | $ | 9 | $ | 1 | |||
| Actuarial Loss | 39 | — | |||||
| Total | $ | 48 | $ | 1 | |||
| Amortization from Balance Sheet: | |||||||
| AOCI | $ | 11 | $ | — | |||
| Regulatory assets/liabilities | 37 | 1 | |||||
| Total | $ | 48 | $ | 1 | |||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||
| OCI | $ | (70) | $ | (428) | $ | (194) | $ | (42) | $ | (12) | $ | (13) | |||||||||||||||||||||||
| Regulatory assets/liabilities | (4) | 87 | 10 | (11) | 10 | (5) | |||||||||||||||||||||||||||||
| Total recognized in OCI and regulatory assets/liabilities | $ | (74) | $ | (341) | $ | (184) | $ | (53) | $ | (2) | $ | (18) | |||||||||||||||||||||||
(LG&E)
The following table provides the components of net periodic defined benefit costs for LG&E's pension benefit plan for the yearsyear ended December 31.
146
| Pension Benefits | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Net periodic defined benefit costs (credits): | |||||||||||
| Service cost | $ | 1 | $ | 1 | $ | 1 | |||||
| Interest cost | 13 | 15 | 14 | ||||||||
| Expected return on plan assets | (22 | ) | (21 | ) | (20 | ) | |||||
| Amortization of: | |||||||||||
| Prior service cost | 5 | 4 | 3 | ||||||||
| Actuarial loss (a) | 9 | 7 | 11 | ||||||||
| Net periodic defined benefit costs (b) | $ | 6 | $ | 6 | $ | 9 | |||||
Other Changes in Plan Assets and Benefit Obligations Recognized in Regulatory Assets - Gross: | |||||||||||
| Net (gain) loss | $ | (9 | ) | $ | 22 | $ | 8 | ||||
| Prior service cost | 7 | — | 10 | ||||||||
| Amortization of: | |||||||||||
| Prior service credit | (5 | ) | (4 | ) | (3 | ) | |||||
| Actuarial gain | (9 | ) | (7 | ) | (11 | ) | |||||
| Total recognized in regulatory assets/liabilities | (16 | ) | 11 | 4 | |||||||
| Total recognized in net periodic defined benefit costs and regulatory assets | $ | (10 | ) | $ | 17 | $ | 13 | ||||
| Pension Benefits | |||||
| 2019 (a) | |||||
| Net periodic defined benefit costs (credits): | |||||
| Service cost | $ | 1 | |||
| Interest cost | 11 | ||||
| Expected return on plan assets | (21) | ||||
| Amortization of: | |||||
| Prior service cost (credit) | 5 | ||||
| Actuarial loss (b) | 9 | ||||
| Net periodic defined benefit costs (credits) (c) | $ | 5 | |||
Recognized in Regulatory Assets - Gross: | |||||
| Net (gain) loss | $ | (19) | |||
| Amortization of: | |||||
| Prior service credit | (5) | ||||
| Actuarial gain | (9) | ||||
| Total recognized in regulatory assets/liabilities | (33) | ||||
| Total recognized in net periodic defined benefit costs and regulatory assets | $ | (28) | |||
(a)The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan, sponsored by LKE.
(b)As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $3 million in 2019.
(c)Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.
The estimated amounts to be amortized fromin accordance with existing regulatory assets into net periodic defined benefit costs for LG&E in 2018 are as follows.
Pension Benefits | |||
| Prior service cost | $ | 5 | |
| Actuarial loss | 9 | ||
| Total | $ | 14 | |
(All Registrants)
The following net periodic defined benefit costs (credits) were charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts. The U.K. pension benefits apply to PPL only.
| Pension Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| PPL | $ | 59 | $ | 53 | $ | 71 | $ | (151 | ) | $ | (95 | ) | $ | (21 | ) | $ | 5 | $ | 7 | $ | 8 | PPL | $ | 12 | $ | 40 | $ | 18 | $ | (1) | $ | 4 | $ | 8 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| PPL Electric (a) | 12 | 10 | 15 | — | 1 | — | PPL Electric (a) | (9) | (2) | (4) | (1) | 2 | 4 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| LKE (b) | 28 | 24 | 37 | 5 | 6 | 8 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| LG&E (b) | 8 | 8 | 12 | 3 | 3 | 4 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| LG&E (a) (b) | LG&E (a) (b) | (1) | 4 | 3 | 2 | 2 | 2 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| KU (a) (b) | 4 | 5 | 9 | 1 | 2 | 2 | KU (a) (b) | (3) | 1 | (1) | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(a)PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these |
(b)As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in accordance with LG&E's participationand KU's pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charged to Other operation and maintenance, Other Income (Expense) - net or regulatory assets, excluding amounts charged to construction and other non-expense accounts, insignificant amounts for LG&E and KU were recorded as regulatory assets in those plans, which management believes are reasonable:2021, $3 million for LG&E and $1 million for KU were recorded as regulatory assets in 2020 and $2 million for LG&E and $1 million for KU were recorded as regulatory assets in 2019.
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | ||||||||||||||||||
| LG&E Non-Union Only | $ | 5 | $ | 4 | $ | 5 | $ | 3 | $ | 3 | $ | 4 | |||||||||||
(PPL LKE and LG&E)
PPL LKE and LG&E adopted the newuse base mortality tables issued by the Society of Actuaries in October 2014 (RP-2014 base tables with collar and factor adjustments, where applicable) for all U.S. defined benefit pension and other postretirement benefit plans. In addition, in 2014,2019, PPL LKE and LG&E updated the basis for estimating projected mortality improvementsused RP-2014 base tables with collar and selected the IRS BB-2D two-dimensional improvement scale on a generational basis for all U.S. defined benefit pensionfactor adjustments, where applicable, and other postretirement benefit plans. In 2017, PPL, LKE and LG&E updated to the MP-2017 mortality improvement scale from 2006 on a generational basis. This new mortality assumption reflectsIn 2020, PPL updated to the expectationPri-2012 base table and the MP-2020 projection scale with varying adjustment factors based on the underlying demographic and geographic differences and experience of lower ongoing improvements in life expectancies.the plan participants.
147
The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. The U.K. pension benefits apply to PPL only.
| Pension Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | 2021 | 2020 | 2021 | 2020 | |||||||||||||||||||||||||||||||||||||||||||
| PPL | PPL | |||||||||||||||||||||||||||||||||||||||||||||||||||
| Discount rate | 3.70 | % | 4.21 | % | 2.65 | % | 2.87 | % | 3.64 | % | 4.11 | % | Discount rate | 3.15 | % | 2.92 | % | 3.13 | % | 2.84 | % | |||||||||||||||||||||||||||||||
| Rate of compensation increase | 3.78 | % | 3.95 | % | 3.50 | % | 3.50 | % | 3.75 | % | 3.92 | % | Rate of compensation increase | 3.76 | % | 3.76 | % | 3.77 | % | 3.75 | % | |||||||||||||||||||||||||||||||
| LKE | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Discount rate | 3.69 | % | 4.19 | % | 3.65 | % | 4.12 | % | ||||||||||||||||||||||||||||||||||||||||||||
| Rate of compensation increase | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | ||||||||||||||||||||||||||||||||||||||||||||
| LG&E | ||||||||||||||||||||||||||||||||||||||||||||||||||||
| Discount rate | 3.65 | % | 4.13 | % | ||||||||||||||||||||||||||||||||||||||||||||||||
The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only.
| Pension Benefits | ||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | ||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | ||||||||||||||||||
| PPL | ||||||||||||||||||||||||||
| Discount rate service cost (b) | 4.21 | % | 4.59 | % | 4.25 | % | 2.99 | % | 3.90 | % | 3.85 | % | 4.11 | % | 4.48 | % | 4.09 | % | ||||||||
| Discount rate interest cost (b) | 4.21 | % | 4.59 | % | 4.25 | % | 2.41 | % | 3.14 | % | 3.85 | % | 4.11 | % | 4.48 | % | 4.09 | % | ||||||||
| Rate of compensation increase | 3.95 | % | 3.93 | % | 3.91 | % | 3.50 | % | 4.00 | % | 4.00 | % | 3.92 | % | 3.91 | % | 3.86 | % | ||||||||
| Expected return on plan assets (a) | 7.00 | % | 7.00 | % | 7.00 | % | 7.22 | % | 7.20 | % | 7.19 | % | 6.21 | % | 6.11 | % | 6.06 | % | ||||||||
| LKE | ||||||||||||||||||||||||||
| Discount rate | 4.19 | % | 4.56 | % | 4.25 | % | 4.12 | % | 4.49 | % | 4.06 | % | ||||||||||||||
| Rate of compensation increase | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | 3.50 | % | ||||||||||||||
| Expected return on plan assets (a) | 7.00 | % | 7.00 | % | 7.00 | % | 6.82 | % | 6.82 | % | 6.82 | % | ||||||||||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2019 | 2021 | 2020 | 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| PPL | PPL | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Discount rate | Discount rate | 2.92 | % | 3.64 | % | 4.35 | % | 2.84 | % | 3.60 | % | 4.31 | % | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Rate of compensation increase | Rate of compensation increase | 3.76 | % | 3.79 | % | 3.79 | % | 3.75 | % | 3.76 | % | 3.76 | % | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Expected return on plan assets | Expected return on plan assets | 7.25 | % | 7.25 | % | 7.25 | % | 6.48 | % | 6.44 | % | 6.46 | % | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Pension Benefits | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | 2017 | 2016 | 2015 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| LG&E | LG&E | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Discount rate | 4.13 | % | 4.49 | % | 4.20 | % | Discount rate | — | % | — | % | 4.33 | % | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Expected return on plan assets (a) | 7.00 | % | 7.00 | % | 7.00 | % | Expected return on plan assets (a) | — | % | — | % | 7.25 | % | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(a)The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
(PPL)
The following table provides the assumed health care cost trend rates for the years ended December 31:
| 2017 | 2016 | 2015 | ||||||
| PPL and LKE | ||||||||
| Health care cost trend rate assumed for next year | ||||||||
| – obligations | 6.6 | % | 7.0 | % | 6.8 | % | ||
| – cost | 7.0 | % | 6.8 | % | 7.2 | % | ||
| Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) | ||||||||
| – obligations | 5.0 | % | 5.0 | % | 5.0 | % | ||
| – cost | 5.0 | % | 5.0 | % | 5.0 | % | ||
| Year that the rate reaches the ultimate trend rate | ||||||||
| – obligations | 2022 | 2022 | 2020 | |||||
| – cost | 2022 | 2020 | 2020 | |||||
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | |||||||||||||||||
| Health care cost trend rate assumed for next year | |||||||||||||||||
| – obligations | 6.25 | % | 6.50 | % | 6.60 | % | |||||||||||
| – cost | 6.50 | % | 6.60 | % | 6.60 | % | |||||||||||
| Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) | |||||||||||||||||
| – obligations | 5.00 | % | 5.00 | % | 5.00 | % | |||||||||||
| – cost | 5.00 | % | 5.00 | % | 5.00 | % | |||||||||||
| Year that the rate reaches the ultimate trend rate | |||||||||||||||||
| – obligations | 2027 | 2027 | 2024 | ||||||||||||||
| – cost | 2027 | 2024 | 2023 | ||||||||||||||
| One Percentage Point | |||||||
| Increase | Decrease | ||||||
| Effect on accumulated postretirement benefit obligation | |||||||
| PPL | $ | 4 | $ | (4 | ) | ||
| LKE | 3 | (3 | ) | ||||
The funded status of PPL's plans at December 31 was as follows:
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||||||||||||||
| Change in Benefit Obligation | |||||||||||||||||||||||||||||||||||
| Benefit Obligation, beginning of period | $ | 4,251 | $ | 4,146 | $ | 573 | $ | 557 | |||||||||||||||||||||||||||
| Service cost | 56 | 56 | 6 | 6 | |||||||||||||||||||||||||||||||
| Interest cost | 121 | 146 | 16 | 19 | |||||||||||||||||||||||||||||||
| Participant contributions | — | — | 14 | 15 | |||||||||||||||||||||||||||||||
| Plan amendments | 2 | 2 | — | 5 | |||||||||||||||||||||||||||||||
| Actuarial (gain) loss | (88) | 256 | (50) | 29 | |||||||||||||||||||||||||||||||
| Settlements | (106) | (114) | — | — | |||||||||||||||||||||||||||||||
| Gross benefits paid | (247) | (241) | (55) | (58) | |||||||||||||||||||||||||||||||
| Benefit Obligation, end of period | 3,989 | 4,251 | 504 | 573 | |||||||||||||||||||||||||||||||
| Change in Plan Assets | |||||||||||||||||||||||||||||||||||
| Plan assets at fair value, beginning of period | 4,068 | 3,585 | 367 | 340 | |||||||||||||||||||||||||||||||
| Actual return on plan assets | 125 | 723 | 25 | 56 | |||||||||||||||||||||||||||||||
| Employer contributions | 47 | 115 | 18 | 18 | |||||||||||||||||||||||||||||||
| Participant contributions | — | — | 11 | 11 | |||||||||||||||||||||||||||||||
| Settlements | (106) | (114) | — | — | |||||||||||||||||||||||||||||||
| Gross benefits paid | (247) | (241) | (54) | (58) | |||||||||||||||||||||||||||||||
| Plan assets at fair value, end of period | 3,887 | 4,068 | 367 | 367 | |||||||||||||||||||||||||||||||
| Funded Status, end of period | $ | (102) | $ | (183) | $ | (137) | $ | (206) | |||||||||||||||||||||||||||
| Amounts recognized in the Balance Sheets consist of: | |||||||||||||||||||||||||||||||||||
| Noncurrent asset | $ | 91 | $ | 24 | $ | — | $ | — | |||||||||||||||||||||||||||
| Current liability | (10) | (18) | (15) | (22) | |||||||||||||||||||||||||||||||
| Noncurrent liability | (183) | (189) | (122) | (184) | |||||||||||||||||||||||||||||||
| Net amount recognized, end of period | $ | (102) | $ | (183) | $ | (137) | $ | (206) | |||||||||||||||||||||||||||
| Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: | |||||||||||||||||||||||||||||||||||
| Prior service cost (credit) | $ | 22 | $ | 27 | $ | 12 | $ | 14 | |||||||||||||||||||||||||||
| Net actuarial (gain) loss | 626 | 695 | (51) | — | |||||||||||||||||||||||||||||||
| Total | $ | 648 | $ | 722 | $ | (39) | $ | 14 | |||||||||||||||||||||||||||
| Total accumulated benefit obligation for defined benefit pension plans | $ | 3,786 | $ | 4,024 | |||||||||||||||||||||||||||||||
| Pension Benefits | |||||||||||||||||||||||
| U.S. | U.K. | Other Postretirement Benefits | |||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||
| Change in Benefit Obligation | |||||||||||||||||||||||
| Benefit Obligation, beginning of period | $ | 4,079 | $ | 3,863 | $ | 7,383 | $ | 8,404 | $ | 591 | $ | 596 | |||||||||||
| Service cost | 65 | 66 | 76 | 69 | 7 | 7 | |||||||||||||||||
| Interest cost | 168 | 174 | 178 | 235 | 23 | 26 | |||||||||||||||||
| Participant contributions | — | — | 13 | 14 | 14 | 14 | |||||||||||||||||
| Plan amendments | (1 | ) | 14 | — | — | 8 | — | ||||||||||||||||
| Actuarial (gain) loss | 233 | 214 | 293 | 484 | 4 | 11 | |||||||||||||||||
| Settlements | (6 | ) | (9 | ) | (1 | ) | — | — | — | ||||||||||||||
| Termination benefits | 1 | — | — | — | — | — | |||||||||||||||||
| Gross benefits paid | (251 | ) | (243 | ) | (345 | ) | (357 | ) | (59 | ) | (64 | ) | |||||||||||
| Federal subsidy | — | — | — | — | 1 | 1 | |||||||||||||||||
| Currency conversion | — | — | 622 | (1,466 | ) | — | — | ||||||||||||||||
| Benefit Obligation, end of period | 4,288 | 4,079 | 8,219 | 7,383 | 589 | 591 | |||||||||||||||||
| Change in Plan Assets | |||||||||||||||||||||||
| Plan assets at fair value, beginning of period | 3,243 | 3,227 | 7,211 | 7,625 | 378 | 379 | |||||||||||||||||
| Actual return on plan assets | 437 | 189 | 480 | 979 | 54 | 25 | |||||||||||||||||
| Employer contributions | 65 | 79 | 486 | 330 | 15 | 19 | |||||||||||||||||
| Participant contributions | — | — | 13 | 14 | 13 | 14 | |||||||||||||||||
| Settlements | (6 | ) | (9 | ) | (1 | ) | — | — | — | ||||||||||||||
| Gross benefits paid | (251 | ) | (243 | ) | (345 | ) | (357 | ) | (55 | ) | (59 | ) | |||||||||||
| Currency conversion | — | — | 646 | (1,380 | ) | — | — | ||||||||||||||||
| Plan assets at fair value, end of period | 3,488 | 3,243 | 8,490 | 7,211 | 405 | 378 | |||||||||||||||||
| Funded Status, end of period | $ | (800 | ) | $ | (836 | ) | $ | 271 | $ | (172 | ) | $ | (184 | ) | $ | (213 | ) | ||||||
| Amounts recognized in the Balance Sheets consist of: | |||||||||||||||||||||||
| Noncurrent asset | $ | — | $ | — | $ | 284 | $ | 10 | $ | 2 | $ | 2 | |||||||||||
| Current liability | (13 | ) | (17 | ) | — | — | (3 | ) | (3 | ) | |||||||||||||
| Noncurrent liability | (787 | ) | (819 | ) | (13 | ) | (182 | ) | (183 | ) | (212 | ) | |||||||||||
| Net amount recognized, end of period | $ | (800 | ) | $ | (836 | ) | $ | 271 | $ | (172 | ) | $ | (184 | ) | $ | (213 | ) | ||||||
| Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: | |||||||||||||||||||||||
| Prior service cost (credit) | $ | 49 | $ | 59 | $ | — | $ | — | $ | 9 | $ | — | |||||||||||
| Net actuarial (gain) loss | 1,134 | 1,178 | 2,755 | 2,553 | 16 | 45 | |||||||||||||||||
| Total (a) | $ | 1,183 | $ | 1,237 | $ | 2,755 | $ | 2,553 | $ | 25 | $ | 45 | |||||||||||
Total accumulated benefit obligation for defined benefit pension plans | $ | 4,000 | $ | 3,807 | $ | 7,542 | $ | 6,780 | |||||||||||||||
For PPL's U.S. pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows:
| U.S. Pension Benefits | Other Postretirement Benefits | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| AOCI | $ | 374 | $ | 357 | $ | 15 | $ | 20 | |||||||
| Regulatory assets/liabilities | 809 | 880 | 10 | 25 | |||||||||||
| Total | $ | 1,183 | $ | 1,237 | $ | 25 | $ | 45 | |||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| AOCI | $ | 239 | $ | 270 | $ | (2) | $ | 10 | |||||||||||||||
| Regulatory assets/liabilities | 409 | 452 | (37) | 4 | |||||||||||||||||||
| Total | $ | 648 | $ | 722 | $ | (39) | $ | 14 | |||||||||||||||
The actuarial gain for pension plans in 2021 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. The actuarial loss for pension plans in 2020 was related to a change in the discount rate used to measure the benefit obligations of those plans offset by gains resulting from the updated mortality assumptions noted above and other demographic assumption changes resulting from the completion of a tri-annual demographic experience study.
The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets:
| U.S. | U.K. | ||||||||||||||
| PBO in excess of plan assets | PBO in excess of plan assets | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| Projected benefit obligation | $ | 4,288 | $ | 4,079 | $ | 3,083 | $ | 3,403 | |||||||
| Fair value of plan assets | 3,488 | 3,243 | 3,070 | 3,221 | |||||||||||
| U.S. | U.K. | ||||||||||||||
| ABO in excess of plan assets | ABO in excess of plan assets | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| Accumulated benefit obligation | $ | 4,000 | $ | 3,807 | $ | 10 | $ | 657 | |||||||
| Fair value of plan assets | 3,488 | 3,243 | — | 643 | |||||||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| Change in Benefit Obligation | |||||||||||||||
| Benefit Obligation, beginning of period | $ | 1,669 | $ | 1,588 | $ | 220 | $ | 216 | |||||||
| Service cost | 24 | 23 | 4 | 5 | |||||||||||
| Interest cost | 68 | 71 | 9 | 9 | |||||||||||
| Participant contributions | — | — | 8 | 7 | |||||||||||
| Plan amendments (a) | 6 | — | 8 | — | |||||||||||
| Actuarial (gain) loss | 113 | 96 | (7 | ) | 4 | ||||||||||
| Gross benefits paid (a) | (109 | ) | (109 | ) | (19 | ) | (21 | ) | |||||||
| Benefit Obligation, end of period | 1,771 | 1,669 | 223 | 220 | |||||||||||
| Change in Plan Assets | |||||||||||||||
| Plan assets at fair value, beginning of period | 1,315 | 1,289 | 98 | 88 | |||||||||||
| Actual return on plan assets | 175 | 69 | 14 | 4 | |||||||||||
| Employer contributions | 21 | 66 | 15 | 20 | |||||||||||
| Participant contributions | — | — | 8 | 7 | |||||||||||
| Gross benefits paid | (109 | ) | (109 | ) | (19 | ) | (21 | ) | |||||||
| Plan assets at fair value, end of period | 1,402 | 1,315 | 116 | 98 | |||||||||||
| Funded Status, end of period | $ | (369 | ) | $ | (354 | ) | $ | (107 | ) | $ | (122 | ) | |||
| Amounts recognized in the Balance Sheets consist of: | |||||||||||||||
| Noncurrent asset | $ | — | $ | — | $ | 2 | $ | 2 | |||||||
| Current liability | (4 | ) | (4 | ) | (3 | ) | (3 | ) | |||||||
| Noncurrent liability | (365 | ) | (350 | ) | (106 | ) | (121 | ) | |||||||
| Net amount recognized, end of period | $ | (369 | ) | $ | (354 | ) | $ | (107 | ) | $ | (122 | ) | |||
| Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: | |||||||||||||||
| Prior service cost | $ | 44 | $ | 45 | $ | 13 | $ | 6 | |||||||
| Net actuarial (gain) loss | 434 | 436 | (26 | ) | (13 | ) | |||||||||
| Total | $ | 478 | $ | 481 | $ | (13 | ) | $ | (7 | ) | |||||
Total accumulated benefit obligation for defined benefit pension plans | $ | 1,616 | $ | 1,531 | |||||||||||
| Pension Benefits | Other Postretirement Benefits | ||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||
| AOCI | $ | 144 | $ | 111 | $ | 6 | $ | 8 | |||||||
| Regulatory assets/liabilities | 334 | 370 | (19 | ) | (15 | ) | |||||||||
| Total | $ | 478 | $ | 481 | $ | (13 | ) | $ | (7 | ) | |||||
| PBO in excess of plan assets | |||||||
| 2017 | 2016 | ||||||
| Projected benefit obligation | $ | 1,771 | $ | 1,669 | |||
| Fair value of plan assets | 1,402 | 1,315 | |||||
| ABO in excess of plan assets | |||||||
| 2017 | 2016 | ||||||
| Accumulated benefit obligation | $ | 1,616 | $ | 1,531 | |||
| Fair value of plan assets | 1,402 | 1,315 | |||||
| Pension Benefits | |||||||
| 2017 | 2016 | ||||||
| Change in Benefit Obligation | |||||||
| Benefit Obligation, beginning of period | $ | 329 | $ | 326 | |||
| Service cost | 1 | 1 | |||||
| Interest cost | 13 | 15 | |||||
| Plan amendments (a) | 6 | — | |||||
| Actuarial (gain) loss | 11 | 15 | |||||
| Gross benefits paid (a) | (34 | ) | (28 | ) | |||
| Benefit Obligation, end of period | 326 | 329 | |||||
| Change in Plan Assets | |||||||
| Plan assets at fair value, beginning of period | 318 | 297 | |||||
| Actual return on plan assets | 41 | 14 | |||||
| Employer contributions | — | 35 | |||||
| Gross benefits paid | (34 | ) | (28 | ) | |||
| Plan assets at fair value, end of period | 325 | 318 | |||||
| Funded Status, end of period | $ | (1 | ) | $ | (11 | ) | |
| Amounts recognized in the Balance Sheets consist of: | |||||||
| Noncurrent liability | $ | (1 | ) | $ | (11 | ) | |
| Net amount recognized, end of period | $ | (1 | ) | $ | (11 | ) | |
| Amounts recognized in regulatory assets (pre-tax) consist of: | |||||||
| Prior service cost | $ | 27 | $ | 25 | |||
| Net actuarial loss | 92 | 110 | |||||
| Total | $ | 119 | $ | 135 | |||
| Total accumulated benefit obligation for defined benefit pension plan | $ | 326 | $ | 329 | |||
| 2017 | 2016 | ||||||
| Pension | $ | 44 | $ | 42 | |||
| Other postretirement benefits | 74 | 76 | |||||
| PBO in excess of plan assets | |||||||||||||||||||||||
| 2021 | 2020 | ||||||||||||||||||||||
| Projected benefit obligation | $ | 193 | $ | 1,875 | |||||||||||||||||||
| Fair value of plan assets | — | 1,668 | |||||||||||||||||||||
| ABO in excess of plan assets | |||||||||||||||||||||||
| 2021 | 2020 | ||||||||||||||||||||||
| Accumulated benefit obligation | $ | 177 | $ | 184 | |||||||||||||||||||
| Fair value of plan assets | — | — | |||||||||||||||||||||
(PPL Electric)
Although PPL Electric does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by PPL Services based on its participation in those plans, which management believes are reasonable. As a result of the spinoff of PPL Energy Supply in 2015, pension and other postretirement plans were remeasured resulting in adjustments to PPL Electric's allocated balances of $56 million, reflected as a non-cash contribution on the Statement of Equity. The actuarially determined obligations of current active employees and retirees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to PPL Electric resulted in liabilitiesassets/(liabilities) at December 31 as follows:
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Pension | $ | 246 | $ | 281 | Pension | $ | 42 | $ | 4 | |||||||||
| Other postretirement benefits | 62 | 72 | Other postretirement benefits | (78) | (99) | |||||||||||||
(LG&E)
Although LG&E does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. LG&E is also allocated costs of defined benefits plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to LG&E from LKS. These allocations are based on LG&E's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of LG&E are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows:
| 2021 | 2020 | ||||||||||
| Pension | $ | 85 | $ | 78 | |||||||
| Other postretirement benefits | (51) | (68) | |||||||||
(KU)
Although KU does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 1415 for additional information on costs allocated to KU from LKS. These allocations are based on KU's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of KU are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to KU resulted in liabilitiesassets/(liabilities) at December 31 as follows.
| 2017 | 2016 | 2021 | 2020 | |||||||||||||||
| Pension | $ | 36 | $ | 62 | Pension | $ | 75 | $ | 62 | |||||||||
| Other postretirement benefits | 32 | 40 | Other postretirement benefits | (6) | (16) | |||||||||||||
Plan Assets - U.S. Pension Plans
PPL's primary legacy pension plan and the pension plansplan sponsored by LKE are invested in the PPL Services Corporation Master Trust (the Master Trust) that also includes 401(h) accounts that are restricted for certain other postretirement benefit obligations of PPL and LKE. The investment strategy for the Master Trust is to achieve a risk-adjusted return on a mix of assets that, in combination with PPL's funding policy, will ensure that sufficient assets are available to provide long-term growth and liquidity for benefit payments, while also managing the duration of the assets to complement the duration of the liabilities. The Master Trust benefits from a wide diversification of asset types, investment fund strategies and external investment fund managers, and therefore has no significant concentration of risk.
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The investment policy of the Master Trust outlines investment objectives and defines the responsibilities of the EBPB, external investment managers, investment advisor and trustee and custodian. The investment policy is reviewed annually by PPL's Board of Directors.
The EBPB created a risk management framework around the trust assets and pension liabilities. This framework considers the trust assets as being composed of three sub-portfolios: growth, immunizing and liquidity portfolios. The growth portfolio is comprised of investments that generate a return at a reasonable risk, including equity securities, certain debt securities and alternative investments. The immunizing portfolio consists of debt securities, generally with long durations, and derivative positions. The immunizing portfolio is designed to offset a portion of the change in the pension liabilities due to changes in interest rates. The liquidity portfolio consists primarily of cash and cash equivalents.
Target allocation ranges have been developed for each portfolio based on input from external consultants with a goal of limiting funded status volatility. The EBPB monitors the investments in each portfolio, and seeks to obtain a target portfolio that emphasizes reduction of risk of loss from market volatility. In pursuing that goal, the EBPB establishes revised guidelines from time to time. EBPB investment guidelines as of the end of 20172021 are presented below.
The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows:
| Percentage of trust assets | 2017 | |||||||
| 2017 (a) | 2016 | Target Asset Allocation (a) | ||||||
| Growth Portfolio | 56 | % | 52 | % | 55 | % | ||
| Equity securities | 32 | % | 30 | % | ||||
| Debt securities (b) | 14 | % | 12 | % | ||||
| Alternative investments | 10 | % | 10 | % | ||||
| Immunizing Portfolio | 43 | % | 46 | % | 43 | % | ||
| Debt securities (b) | 39 | % | 43 | % | ||||
| Derivatives | 4 | % | 3 | % | ||||
| Liquidity Portfolio | 1 | % | 2 | % | 2 | % | ||
| Total | 100 | % | 100 | % | 100 | % | ||
| Percentage of trust assets | 2021 | ||||||||||||||||
| 2021 | 2020 | Target Asset Allocation | |||||||||||||||
| Growth Portfolio | 55 | % | 56 | % | 55 | % | |||||||||||
| Equity securities | 32 | % | 34 | % | |||||||||||||
| Debt securities (a) | 13 | % | 13 | % | |||||||||||||
| Alternative investments | 10 | % | 9 | % | |||||||||||||
| Immunizing Portfolio | 43 | % | 43 | % | 43 | % | |||||||||||
| Debt securities (a) | 35 | % | 33 | % | |||||||||||||
| Derivatives | 8 | % | 10 | % | |||||||||||||
| Liquidity Portfolio | 2 | % | 1 | % | 2 | % | |||||||||||
| Total | 100 | % | 100 | % | 100 | % | |||||||||||
The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was:
| December 31, 2017 | December 31, 2016 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value Measurements Using | Fair Value Measurements Using | Fair Value Measurements Using | Fair Value Measurements Using | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 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 Services Corporation Master Trust | PPL Services Corporation Master Trust | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 301 | $ | 301 | $ | — | $ | — | $ | 181 | $ | 181 | $ | — | $ | — | Cash and cash equivalents | $ | 266 | $ | 266 | $ | — | $ | — | $ | 300 | $ | 300 | $ | — | $ | — | |||||||||||||||||||||||||||||||||||||||||||||
| Equity securities: | Equity securities: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. Equity | 229 | 229 | — | — | 152 | 152 | — | — | U.S. Equity | 41 | 41 | — | — | 60 | 60 | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. Equity fund measured at NAV (a) | 364 | — | — | — | 272 | — | — | — | U.S. Equity fund measured at NAV (a) | 754 | — | — | — | 742 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| International equity fund at NAV (a) | 538 | — | — | — | 551 | — | — | — | International equity fund at NAV (a) | 511 | — | — | — | 566 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commingled debt measured at NAV (a) | 611 | — | — | — | 546 | — | — | — | Commingled debt measured at NAV (a) | 677 | — | — | — | 712 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| December 31, 2017 | December 31, 2016 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value Measurements Using | Fair Value Measurements Using | Fair Value Measurements Using | Fair Value Measurements Using | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 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 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Debt securities: | Debt securities: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
U.S. Treasury and U.S. government sponsored agency | 186 | 186 | — | — | 381 | 381 | — | — | U.S. Treasury and U.S. government sponsored agency | 281 | 280 | 1 | — | 336 | 335 | 1 | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Corporate | 883 | — | 870 | 13 | 850 | — | 837 | 13 | Corporate | 1,039 | — | 1,019 | 20 | 1,045 | — | 1,030 | 15 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other | 10 | — | 10 | — | 8 | — | 8 | — | Other | 14 | — | 14 | — | 13 | — | 13 | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Alternative investments: | Alternative investments: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Real estate measured at NAV (a) | 109 | — | — | — | 102 | — | — | — | Real estate measured at NAV (a) | 69 | — | — | — | 76 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Private equity measured at NAV (a) | 80 | — | — | — | 80 | — | — | — | Private equity measured at NAV (a) | 94 | — | — | — | 68 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Hedge funds measured at NAV (a) | 175 | — | — | — | 167 | — | — | — | Hedge funds measured at NAV (a) | 236 | — | — | — | 223 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivatives: | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps and swaptions | 50 | — | 50 | — | 61 | — | 61 | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Other | 1 | — | 1 | — | 3 | — | 3 | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Insurance contracts | 24 | — | — | 24 | 27 | — | — | 27 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Limited Partnerships at NAV (a) | Limited Partnerships at NAV (a) | — | — | — | — | 6 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Derivatives | Derivatives | 35 | — | 35 | — | (37) | — | (37) | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
PPL Services Corporation Master Trust assets, at fair value | 3,561 | $ | 716 | $ | 931 | $ | 37 | 3,381 | $ | 714 | $ | 909 | $ | 40 | PPL Services Corporation Master Trust assets, at fair value | 4,017 | $ | 587 | $ | 1,069 | $ | 20 | 4,110 | $ | 695 | $ | 1,007 | $ | 15 | |||||||||||||||||||||||||||||||||||||||||||||||||
| Receivables and payables, net (b) | 72 | (15 | ) | Receivables and payables, net (b) | 25 | 116 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
401(h) accounts restricted for other postretirement benefit obligations | (145 | ) | (123 | ) | 401(h) accounts restricted for other postretirement benefit obligations | (155) | (158) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Total PPL Services Corporation Master Trust pension assets | $ | 3,488 | $ | 3,243 | Total PPL Services Corporation Master Trust pension assets | $ | 3,887 | $ | 4,068 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(a)In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient 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 statement of financial position.
(b)Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
A reconciliation of the Master Trust assets classified as Level 3 at December 31, 20172021 is as follows:
| Corporate debt | Total | |||||||||||||||||||||||||||||||||
| Balance at beginning of period | Balance at beginning of period | $ | 15 | $ | 15 | |||||||||||||||||||||||||||||
Corporate debt | Insurance contracts | Total | ||||||||||||||||||||||||||||||||
| Balance at beginning of period | $ | 13 | $ | 27 | $ | 40 | ||||||||||||||||||||||||||||
| Actual return on plan assets | ||||||||||||||||||||||||||||||||||
| Relating to assets still held at the reporting date | — | 1 | 1 | |||||||||||||||||||||||||||||||
| Purchases, sales and settlements | — | (4 | ) | (4 | ) | Purchases, sales and settlements | 5 | 5 | ||||||||||||||||||||||||||
| Balance at end of period | $ | 13 | $ | 24 | $ | 37 | Balance at end of period | $ | 20 | $ | 20 | |||||||||||||||||||||||
A reconciliation of the Master Trust assets classified as Level 3 at December 31, 20162020 is as follows:
| Corporate debt | Insurance contracts | Total | ||||||||||||||||||||||||||||||||
| Balance at beginning of period | Balance at beginning of period | $ | 20 | $ | 4 | $ | 24 | |||||||||||||||||||||||||||
Corporate debt | Insurance contracts | Total | ||||||||||||||||||||||||||||||||
| Balance at beginning of period | $ | 10 | $ | 32 | $ | 42 | ||||||||||||||||||||||||||||
| Actual return on plan assets | ||||||||||||||||||||||||||||||||||
| Relating to assets still held at the reporting date | — | 1 | 1 | |||||||||||||||||||||||||||||||
| Purchases, sales and settlements | 3 | (6 | ) | (3 | ) | Purchases, sales and settlements | (5) | (4) | (9) | |||||||||||||||||||||||||
| Balance at end of period | $ | 13 | $ | 27 | $ | 40 | Balance at end of period | $ | 15 | $ | — | $ | 15 | |||||||||||||||||||||
The fair value measurements of cash and cash equivalents are based on the amounts on deposit.
The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices.
Investments in commingled equity and debt funds are categorized as equity securities. Investments in commingled equity funds include funds that invest in U.S. and international equity securities. Investments in commingled debt funds include funds that invest in a diversified portfolio of emerging market debt obligations, as well as funds that invest in investment grade long-duration fixed-income securities.
The fair value measurements of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. The fair value of debt securities is generally measured using a market approach, including the use of pricing models, which incorporate observable inputs. Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral
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performance and new issue data. For the Master Trust, these securities represent investments in securities issued by U.S. Treasury and U.S. government sponsored agencies; investments securitized by residential mortgages, auto loans, credit cards and other pooled loans; investments in investment grade and non-investment grade bonds issued by U.S. companies across several industries; investments in debt securities issued by foreign governments and corporations.
Investments in real estate represent an investment in a partnership whose purpose is to manage investments in core U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). The managerstrategy is focused on properties with high occupancy rates with quality tenants. This results in a focus on high income and stable cash flows with appreciation being a secondary factor. Core real estate generally has a lower degree of leverage when compared with more speculative real estate investing strategies. The partnership has limitations on the amounts that may be redeemed based on available cash to fund redemptions. Additionally, the general partner may decline to accept redemptions when necessary to avoid adverse consequences for the partnership, including legal and tax implications, among others. The fair value of the investment is based upon a partnership unit value.
Investments in private equity represent interests in partnerships in multiple early-stage venture capital funds and private equity fund of funds that use a number of diverse investment strategies. The partnerships have limited lives of at least 10 years, after which liquidating distributions will be received. Prior to the end of each partnership's life, the investment cannot be redeemed with the partnership; however, the interest may be sold to other parties, subject to the general partner's approval. TheAt December 31, 2021, the Master Trust hashad unfunded commitments of $28$111 million that may be required during the lives of the partnerships. Fair value is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed.
Investments in limited partnerships include Term Asset-Backed Securities Loan Facility (TALF) funds. The Master Trust received notice that the TALF funds are liquidating in an orderly manner and distributing capital back to the partners. Therefore, the Master Trust has no unfunded commitment related to the TALF funds. Fair value of the funds is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed.
Investments in hedge funds represent investments in a fund of hedge funds. Hedge funds seek a return utilizing a number of diverse investment strategies. The strategies, when combined aim to reduce volatility and risk while attempting to deliver positive returns under most market conditions. Major investment strategies for the fund of hedge funds include long/short equity, tactical trading, event driven, and relative value. Shares may be redeemed withinwith 45 days prior written notice. The fund is subject to short term lockups and other restrictions. The fair value for the fund has been estimated using the net asset value per share.
The fair value measurements of derivative instruments utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these instruments may be valued using models, including standard option valuation models and standard industry models. These securities primarily represent investments in treasury futures, total return swaps, interest rate swaps and swaptions (the option to enter into an interest rate swap), which are valued based on quoted prices, changes in the value of the underlying exposure or on the swap details, such as swap curves, notional amount, index and term of index, reset frequency, volatility and payer/receiver credit ratings.
Plan Assets - U.S. Other Postretirement Benefit Plans
The investment strategy with respect to other postretirement benefit obligations is to fund VEBA trusts and/or 401(h) accounts with voluntary contributions and to invest in a tax efficient manner. Excluding the 401(h) accounts included in the Master Trust, other postretirement benefit plans are invested in a mix of assets for long-term growth with an objective of earning returns that provide liquidity as required for benefit payments. These plans benefit from diversification of asset types, investment fund strategies and investment fund managers and, therefore, have no significant concentration of risk. Equity securities include investments in domestic large-cap commingled funds. Ownership interests in commingled funds that invest entirely in debt securities are classified as equity securities, but treated as debt securities for asset allocation and target allocation purposes. Ownership interests in money market funds are treated as cash and cash equivalents for asset allocation and target allocation purposes. The asset allocation for the PPL VEBA trusts excluding LKE, and the target allocation, by asset class, at December 31 are detailed below.
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| Percentage of plan assets | Target Asset Allocation | ||||||||||||||||
| 2021 | 2020 | 2021 | |||||||||||||||
| Asset Class | |||||||||||||||||
| U.S. Equity securities | 45 | % | 42 | % | 45 | % | |||||||||||
| Debt securities (a) | 52 | % | 55 | % | 50 | % | |||||||||||
| Cash and cash equivalents (b) | 3 | % | 3 | % | 5 | % | |||||||||||
| Total | 100 | % | 100 | % | 100 | % | |||||||||||
| Percentage of plan assets | Target Asset Allocation | |||||||
| 2017 | 2016 | 2017 | ||||||
| Asset Class | ||||||||
| U.S. Equity securities | 47 | % | 48 | % | 45 | % | ||
| Debt securities (a) | 49 | % | 50 | % | 50 | % | ||
| Cash and cash equivalents (b) | 4 | % | 2 | % | 5 | % | ||
| Total | 100 | % | 100 | % | 100 | % | ||
| (b)Includes |
The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was:
| December 31, 2017 | December 31, 2016 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Fair Value Measurement Using | Fair Value Measurement Using | Fair Value Measurement Using | Fair Value Measurement Using | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 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 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Money market funds | $ | 10 | $ | 10 | $ | — | $ | — | $ | 5 | $ | 5 | $ | — | $ | — | Money market funds | $ | 6 | $ | 6 | $ | — | $ | — | $ | 5 | $ | 5 | $ | — | $ | — | |||||||||||||||||||||||||||||||||||||||||||||
| U.S. Equity securities: | U.S. Equity securities: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Large-cap equity fund measure at NAV (a) | 123 | — | — | — | 123 | — | — | — | Large-cap equity fund measure at NAV (a) | 96 | — | — | — | 89 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Commingled debt fund measured at NAV (a) | 96 | — | — | — | 114 | — | — | — | Commingled debt fund measured at NAV (a) | 75 | — | — | — | 77 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Debt securities: | Debt securities: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Corporate bonds | 30 | — | 30 | — | — | — | — | — | Corporate bonds | 38 | — | 38 | — | 37 | — | 37 | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Municipalities | — | — | — | — | 12 | — | 12 | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| U.S. Treasury and U.S. government sponsored agency | U.S. Treasury and U.S. government sponsored agency | — | — | — | — | 2 | — | 2 | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total VEBA trust assets, at fair value | 259 | $ | 10 | $ | 30 | $ | — | 254 | $ | 5 | $ | 12 | $ | — | Total VEBA trust assets, at fair value | 215 | $ | 6 | $ | 38 | $ | — | 210 | $ | 5 | $ | 39 | $ | — | |||||||||||||||||||||||||||||||||||||||||||||||||
| Receivables and payables, net (b) | 1 | 1 | Receivables and payables, net (b) | (3) | (1) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| 401(h) account assets | 145 | 123 | 401(h) account assets | 155 | 158 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total other postretirement benefit plan assets | $ | 405 | $ | 378 | Total other postretirement benefit plan assets | $ | 367 | $ | 367 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(a)In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient 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 statement of financial position.
(b)Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Investments in money market funds represent investments in funds that invest primarily in a diversified portfolio of investment grade money market instruments, including, but not limited to, commercial paper, notes, repurchase agreements and other evidences of indebtedness with a maturity not exceeding 13 months from the date of purchase. The primary objective of the fund is a level of current income consistent with stability of principal and liquidity. Redemptions can be made daily on this fund.
Investments in large-cap equity securities represent investments in a passively managed equity index fund that invests in securities and a combination of other collective funds. Fair value measurements are not obtained from a quoted price in an active market but are based on firm quotes of net asset values per share as provided by the trustee of the fund. Redemptions can be made daily on this fund.
Investments in commingled debt securities represent investments in a fund that invests in a diversified portfolio of investment grade long-duration fixed income securities. Redemptions can be made daily on these funds.
Investments in corporate bonds represent investment in a diversified portfolio of investment grade long-duration fixed income securities. The fair value of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences.
Investments in municipalitiesU.S. Treasury and U.S. government sponsored agencies represent investmentssecurities included in a diverse mixportfolio of tax-exempt municipal securities. investment-grade long-duration fixed income.The fair value measurements for theseof debt securities are generally based on recently executed transactionsevaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities.securities, adjusted for observable differences.
| Target Asset | ||||||||
| Percentage of plan assets | Allocation | |||||||
| 2017 | 2016 | 2017 | ||||||
| Asset Class | ||||||||
| Cash and cash equivalents | 2 | % | 1 | % | — | % | ||
| Equity securities | ||||||||
| U.K. | 2 | % | 3 | % | 2 | % | ||
| European (excluding the U.K.) | 1 | % | 2 | % | 1 | % | ||
| Asian-Pacific | 1 | % | 2 | % | 1 | % | ||
| North American | 1 | % | 3 | % | 1 | % | ||
| Emerging markets | 1 | % | 3 | % | 1 | % | ||
| Global equities | 16 | % | 6 | % | 10 | % | ||
| Global Tactical Asset Allocation | 33 | % | 33 | % | 41 | % | ||
| Debt securities (a) | 37 | % | 41 | % | 38 | % | ||
| Alternative investments | 6 | % | 6 | % | 5 | % | ||
| Total | 100 | % | 100 | % | 100 | % | ||
| December 31, 2017 | December 31, 2016 | ||||||||||||||||||||||||||||||
| Fair Value Measurement Using | Fair Value Measurement Using | ||||||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||
| Cash and cash equivalents | $ | 216 | $ | 216 | $ | — | $ | — | $ | 42 | $ | 42 | $ | — | $ | — | |||||||||||||||
| Equity securities measured at NAV (a) : | |||||||||||||||||||||||||||||||
| U.K. companies | 157 | — | — | — | 210 | — | — | — | |||||||||||||||||||||||
| European companies (excluding the U.K.) | 98 | — | — | — | 177 | — | — | — | |||||||||||||||||||||||
| Asian-Pacific companies | 60 | — | — | — | 140 | — | — | — | |||||||||||||||||||||||
| North American companies | 123 | — | — | — | 227 | — | — | — | |||||||||||||||||||||||
| Emerging markets companies | 62 | — | — | — | 209 | — | — | — | |||||||||||||||||||||||
| Global Equities | 1,335 | — | — | — | 466 | — | — | — | |||||||||||||||||||||||
| Other | 2,807 | — | — | — | 2,363 | — | — | — | |||||||||||||||||||||||
| Debt Securities: | |||||||||||||||||||||||||||||||
| U.K. corporate bonds | 3 | — | 3 | — | 2 | — | 2 | — | |||||||||||||||||||||||
| U.K. gilts | 3,137 | — | 3,137 | — | 2,940 | — | 2,940 | — | |||||||||||||||||||||||
| Alternative investments: | |||||||||||||||||||||||||||||||
| Real estate measured at NAV (a) | 492 | — | — | — | 435 | — | — | — | |||||||||||||||||||||||
| Fair value - U.K. pension plans | $ | 8,490 | $ | 216 | $ | 3,140 | $ | — | $ | 7,211 | $ | 42 | $ | 2,942 | $ | — | |||||||||||||||
Expected Cash Flows - U.S. Defined Benefit Plans(PPL)
PPL sponsors various non-qualified supplemental pension plans for which no assets are segregated from corporate assets. PPL expects to make approximately $13$10 million of benefit payments under these plans in 2018.2022.
PPL is not required to make contributions to its other postretirement benefit plans but has historically funded these plans in amounts equal to the postretirement benefit costs recognized. Continuation of this past practice would cause PPL to contribute $14$22 million to its other postretirement benefit plans in 2018.2022.
The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL.
| Other Postretirement | |||||||||||
| Pension | Benefit Payment | Expected Federal Subsidy | |||||||||
| 2018 | $ | 260 | $ | 51 | $ | 1 | |||||
| 2019 | 269 | 51 | — | ||||||||
| 2020 | 268 | 50 | 1 | ||||||||
| 2021 | 270 | 49 | — | ||||||||
| 2022 | 272 | 48 | — | ||||||||
| 2023-2027 | 1,328 | 218 | 2 | ||||||||
| Other Postretirement | |||||||||||||||||
| Pension | Benefit Payment | Expected Federal Subsidy | |||||||||||||||
| 2022 | $ | 207 | $ | 44 | $ | 1 | |||||||||||
| 2023 | 207 | 42 | — | ||||||||||||||
| 2024 | 204 | 41 | — | ||||||||||||||
| 2025 | 204 | 40 | — | ||||||||||||||
| 2026 | 202 | 38 | — | ||||||||||||||
| 2027-2030 | 946 | 176 | 1 | ||||||||||||||
| Other Postretirement | |||||||||||
| Pension | Benefit Payment | Expected Federal Subsidy | |||||||||
| 2018 | $ | 109 | $ | 14 | $ | — | |||||
| 2019 | 113 | 15 | — | ||||||||
| 2020 | 114 | 16 | 1 | ||||||||
| 2021 | 115 | 16 | — | ||||||||
| 2022 | 116 | 16 | — | ||||||||
| 2023-2027 | 573 | 79 | 2 | ||||||||
| Pension | |||
| 2018 | $ | 26 | |
| 2019 | 26 | ||
| 2020 | 26 | ||
| 2021 | 25 | ||
| 2022 | 24 | ||
| 2023-2027 | 104 | ||
| Pension | |||
| 2018 | $ | 343 | |
| 2019 | 349 | ||
| 2020 | 353 | ||
| 2021 | 356 | ||
| 2022 | 362 | ||
| 2023-2027 | 1,843 | ||
Savings Plans(All Registrants)
Substantially all employees of PPL's subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were:
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL | $ | 29 | $ | 29 | $ | 30 | |||||||||||
| PPL Electric | 5 | 6 | 6 | ||||||||||||||
| LG&E | 7 | 6 | 6 | ||||||||||||||
| KU | 5 | 5 | 5 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL | $ | 36 | $ | 35 | $ | 34 | |||||
| PPL Electric | 6 | 6 | 6 | ||||||||
| LKE | 18 | 17 | 16 | ||||||||
| LG&E | 5 | 5 | 5 | ||||||||
| KU | 4 | 4 | 4 | ||||||||
(PPL, LKE, LG&E and KU)
At December 31, 20172021 and 2016,2020, the Balance Sheets reflect the owned interests in the facilitiesgenerating plants listed below.
Ownership Interest | Electric Plant | Accumulated Depreciation | Construction Work in Progress | ||||||||||||
| PPL and LKE | |||||||||||||||
| December 31, 2017 | |||||||||||||||
| Generating Plants | |||||||||||||||
| Trimble County Unit 1 | 75.00 | % | $ | 427 | $ | 69 | $ | 1 | |||||||
| Trimble County Unit 2 | 75.00 | % | 1,032 | 176 | 198 | ||||||||||
| December 31, 2016 | |||||||||||||||
| Generating Plants | |||||||||||||||
| Trimble County Unit 1 | 75.00 | % | $ | 407 | $ | 55 | $ | 1 | |||||||
| Trimble County Unit 2 | 75.00 | % | 1,026 | 161 | 83 | ||||||||||
| LG&E | |||||||||||||||
| December 31, 2017 | |||||||||||||||
| Generating Plants | |||||||||||||||
| E.W. Brown Units 6-7 | 38.00 | % | $ | 41 | $ | 17 | $ | — | |||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 53.00 | % | 52 | 15 | — | ||||||||||
| Trimble County Unit 1 | 75.00 | % | 427 | 69 | 1 | ||||||||||
| Trimble County Unit 2 | 14.25 | % | 215 | 36 | 102 | ||||||||||
| Trimble County Units 5-6 | 29.00 | % | 32 | 9 | — | ||||||||||
| Trimble County Units 7-10 | 37.00 | % | 73 | 21 | — | ||||||||||
| Cane Run Unit 7 | 22.00 | % | 120 | 8 | 1 | ||||||||||
| E.W. Brown Solar Unit | 39.00 | % | 10 | 1 | — | ||||||||||
| December 31, 2016 | |||||||||||||||
| Generating Plants | |||||||||||||||
| E.W. Brown Units 6-7 | 38.00 | % | $ | 40 | $ | 15 | $ | — | |||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 53.00 | % | 55 | 12 | 1 | ||||||||||
| Trimble County Unit 1 | 75.00 | % | 407 | 55 | 1 | ||||||||||
| Trimble County Unit 2 | 14.25 | % | 214 | 32 | 43 | ||||||||||
| Trimble County Units 5-6 | 29.00 | % | 30 | 8 | 1 | ||||||||||
| Trimble County Units 7-10 | 37.00 | % | 71 | 17 | 1 | ||||||||||
| Cane Run Unit 7 | 22.00 | % | 114 | 5 | 2 | ||||||||||
| E.W. Brown Solar Unit | 39.00 | % | 10 | — | — | ||||||||||
| Ownership Interest | Electric Plant | Accumulated Depreciation | Construction Work in Progress | |||||||||||||||||||||||
| PPL | ||||||||||||||||||||||||||
| December 31, 2021 | ||||||||||||||||||||||||||
| Trimble County Unit 1 | 75.00 | % | $ | 457 | $ | 79 | $ | — | ||||||||||||||||||
| Trimble County Unit 2 | 75.00 | % | 1,360 | 247 | 121 | |||||||||||||||||||||
| December 31, 2020 | ||||||||||||||||||||||||||
| Trimble County Unit 1 | 75.00 | % | $ | 440 | $ | 64 | $ | 2 | ||||||||||||||||||
| Trimble County Unit 2 | 75.00 | % | 1,340 | 227 | 106 | |||||||||||||||||||||
| Ownership Interest | Electric Plant | Accumulated Depreciation | Construction Work in Progress | |||||||||||||||||||||||
| LG&E | ||||||||||||||||||||||||||
| December 31, 2021 | ||||||||||||||||||||||||||
| E.W. Brown Units 6-7 | 38.00 | % | $ | 53 | $ | 24 | $ | — | ||||||||||||||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 53.00 | % | 51 | 25 | — | |||||||||||||||||||||
| Trimble County Unit 1 | 75.00 | % | 457 | 79 | — | |||||||||||||||||||||
| Trimble County Unit 2 | 14.25 | % | 379 | 57 | 64 | |||||||||||||||||||||
| Trimble County Units 5-6 | 29.00 | % | 36 | 15 | — | |||||||||||||||||||||
| Trimble County Units 7-10 | 37.00 | % | 81 | 34 | — | |||||||||||||||||||||
| Cane Run Unit 7 | 22.00 | % | 125 | 19 | — | |||||||||||||||||||||
| E.W. Brown Solar Unit | 39.00 | % | 10 | 2 | — | |||||||||||||||||||||
| Solar Share | 44.00 | % | 2 | — | — | |||||||||||||||||||||
| December 31, 2020 | ||||||||||||||||||||||||||
| E.W. Brown Units 6-7 | 38.00 | % | $ | 46 | $ | 22 | $ | — | ||||||||||||||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 53.00 | % | 51 | 22 | — | |||||||||||||||||||||
| Trimble County Unit 1 | 75.00 | % | 440 | 64 | 2 | |||||||||||||||||||||
| Trimble County Unit 2 | 14.25 | % | 370 | 51 | 54 | |||||||||||||||||||||
| Trimble County Units 5-6 | 29.00 | % | 33 | 14 | 1 | |||||||||||||||||||||
| Trimble County Units 7-10 | 37.00 | % | 77 | 31 | 1 | |||||||||||||||||||||
| Cane Run Unit 7 | 22.00 | % | 123 | 15 | — | |||||||||||||||||||||
| E.W. Brown Solar Unit | 39.00 | % | 10 | 2 | — | |||||||||||||||||||||
| Solar Share | 44.00 | % | 2 | — | — | |||||||||||||||||||||
| KU | ||||||||||||||||||||||||||
| December 31, 2021 | ||||||||||||||||||||||||||
| E.W. Brown Units 6-7 | 62.00 | % | $ | 88 | $ | 40 | $ | — | ||||||||||||||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 47.00 | % | 45 | 22 | — | |||||||||||||||||||||
| Trimble County Unit 2 | 60.75 | % | 981 | 190 | 57 | |||||||||||||||||||||
| Trimble County Units 5-6 | 71.00 | % | 84 | 36 | — | |||||||||||||||||||||
| Trimble County Units 7-10 | 63.00 | % | 133 | 57 | — | |||||||||||||||||||||
| Cane Run Unit 7 | 78.00 | % | 444 | 70 | — | |||||||||||||||||||||
| E.W. Brown Solar Unit | 61.00 | % | 16 | 4 | — | |||||||||||||||||||||
| Solar Share | 56.00 | % | 3 | — | — | |||||||||||||||||||||
| December 31, 2020 | ||||||||||||||||||||||||||
| E.W. Brown Units 6-7 | 62.00 | % | $ | 76 | $ | 37 | $ | — | ||||||||||||||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 47.00 | % | 45 | 20 | — | |||||||||||||||||||||
| Trimble County Unit 2 | 60.75 | % | 970 | 176 | 52 | |||||||||||||||||||||
| Trimble County Units 5-6 | 71.00 | % | 77 | 33 | 4 | |||||||||||||||||||||
| Trimble County Units 7-10 | 63.00 | % | 129 | 53 | 2 | |||||||||||||||||||||
| Cane Run Unit 7 | 78.00 | % | 443 | 57 | 2 | |||||||||||||||||||||
| E.W. Brown Solar Unit | 61.00 | % | 16 | 3 | — | |||||||||||||||||||||
| Solar Share | 56.00 | % | 2 | — | — | |||||||||||||||||||||
Ownership Interest | Electric Plant | Accumulated Depreciation | Construction Work in Progress | ||||||||||||
| KU | |||||||||||||||
| December 31, 2017 | |||||||||||||||
| Generating Plants | |||||||||||||||
| E.W. Brown Units 6-7 | 62.00 | % | $ | 66 | $ | 27 | $ | — | |||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 47.00 | % | 46 | 13 | — | ||||||||||
| Trimble County Unit 2 | 60.75 | % | 817 | 140 | 96 | ||||||||||
| Trimble County Units 5-6 | 71.00 | % | 76 | 20 | — | ||||||||||
| Trimble County Units 7-10 | 63.00 | % | 120 | 34 | — | ||||||||||
| Cane Run Unit 7 | 78.00 | % | 431 | 31 | 4 | ||||||||||
| E.W. Brown Solar Unit | 61.00 | % | 16 | 1 | — | ||||||||||
| December 31, 2016 | |||||||||||||||
| Generating Plants | |||||||||||||||
| E.W. Brown Units 6-7 | 62.00 | % | $ | 65 | $ | 23 | $ | — | |||||||
| Paddy's Run Unit 13 & E.W. Brown Unit 5 | 47.00 | % | 50 | 11 | 1 | ||||||||||
| Trimble County Unit 2 | 60.75 | % | 812 | 129 | 40 | ||||||||||
| Trimble County Units 5-6 | 71.00 | % | 74 | 19 | — | ||||||||||
| Trimble County Units 7-10 | 63.00 | % | 121 | 29 | 1 | ||||||||||
| Cane Run Unit 7 | 78.00 | % | 412 | 18 | 4 | ||||||||||
| E.W. Brown Solar Unit | 61.00 | % | 15 | — | — | ||||||||||
Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
Energy Purchase Commitments(PPL, LKE, LG&E and KU)
LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments:
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| Contract Type | Maximum Maturity Date | ||||
| Natural Gas Fuel | |||||
| Natural Gas Retail Supply | |||||
| Coal | |||||
| Coal Transportation and Fleeting Services | |||||
| Natural Gas Transportation | 2026 | ||||
LG&E and KU have a power purchase agreement with OVEC expiring in June 2040. See footnote (f)(c) to the table in "Guarantees and Other Assurances" below for information on the OVEC power purchase contract, including recent developments in credit or debt conditions relating to OVEC. Future obligations for power purchases from OVEC are unconditional demand payments, comprised of debt-service payments and contractually-required reimbursements of plant operating, maintenance and other expenses, and are projected as follows:
| LG&E | KU | Total | |||||||||||||||
| 2022 | $ | 23 | $ | 10 | $ | 33 | |||||||||||
| 2023 | 23 | 10 | 33 | ||||||||||||||
| 2024 | 22 | 10 | 32 | ||||||||||||||
| 2025 | 22 | 10 | 32 | ||||||||||||||
| 2026 | 22 | 10 | 32 | ||||||||||||||
| Thereafter | 218 | 96 | 314 | ||||||||||||||
| Total | $ | 330 | $ | 146 | $ | 476 | |||||||||||
| LG&E | KU | Total | |||||||||
| 2018 | $ | 20 | $ | 9 | $ | 29 | |||||
| 2019 | 19 | 8 | 27 | ||||||||
| 2020 | 18 | 8 | 26 | ||||||||
| 2021 | 19 | 8 | 27 | ||||||||
| 2022 | 19 | 8 | 27 | ||||||||
| Thereafter | 316 | 141 | 457 | ||||||||
| Total | $ | 411 | $ | 182 | $ | 593 | |||||
LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| LG&E | $ | 13 | $ | 12 | $ | 15 | |||||||||||
| KU | 6 | 6 | 7 | ||||||||||||||
| Total | $ | 19 | $ | 18 | $ | 22 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| LG&E | $ | 14 | $ | 16 | $ | 15 | |||||
| KU | 6 | 7 | 7 | ||||||||
| Total | $ | 20 | $ | 23 | $ | 22 | |||||
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.
Background
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 LKE)
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Talen Montana Retirement Plan and Talen Energy Marketing, LLC, Individually and on Behalf of All Others Similarly Situated v. PPL Corporation et al.
On October 29, 2018, Talen Montana Retirement Plan and Talen Energy Marketing filed a putative class action complaint on behalf of current and contingent creditors of Talen Montana who allegedly suffered harm or allegedly will suffer reasonably foreseeable harm as a result of the November 2014 distribution of proceeds from the sale of then-PPL Montana's hydroelectric generating facilities. The action was filed in the Sixteenth Judicial District of the State of Montana, Rosebud County, against PPL and certain of its affiliates and current and former officers and directors (Talen Putative Class Action). Plaintiff asserts claims for, among other things, fraudulent transfer, both actual and constructive; recovery against subsequent transferees; civil conspiracy; aiding and abetting tortious conduct; and unjust enrichment.Plaintiff is seeking avoidance of the purportedly fraudulent transfer, unspecified damages, including punitive damages, the imposition of a constructive trust, and other relief. In December 2018, PPL removed the Talen Putative Class Action from the Sixteenth Judicial District of the State of Montana to the United States District Court for the District of Montana, Billings Division (MT Federal Court). In January 2019, the plaintiff moved to remand the Talen Putative Class Action back to state court, and dismissed without prejudice all current and former PPL Corporation directors from the case. In September 2019, the MT Federal Court granted plaintiff's motion to remand the case back to state court. Although, the PPL defendants petitioned the Ninth Circuit Court of Appeals to grant an appeal of the remand decision, in November 2019, the Ninth Circuit Court of Appeals denied that request and in December 2019, Talen Montana Retirement Plan filed a Second Amended Complaint in the Sixteenth Judicial District of the State of Montana, Rosebud County, which removed Talen Energy Marketing as a plaintiff. In January 2020, PPL defendants filed a motion to dismiss the Second Amended Complaint or, in the alternative, to stay the proceedings pending the resolution of the below mentioned Delaware Action. The Court held a hearing on June 24, 2020 regarding the motions. On September 11, 2020, the Court granted PPL defendants' alternative Motion for informationa Stay of the proceedings.
PPL Corporation et al. vs. Riverstone Holdings LLC, Talen Energy Corporation et al.
On November 30, 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 (Delaware Action), in response to and as part of the defense strategy for an action filed by Talen Montana, LLC (the Talen Direct Action, since dismissed) and the Talen Putative Class Action described above (together, the Montana Actions) originally filed in Montana state court in October 2018. In the complaint, the PPL plaintiffs ask the Delaware Court of Chancery for declaratory and injunctive relief. This includes a declaratory judgment that, under the separation agreement governing the spinoff of PPL Energy Supply, all related claims that arise must be heard in Delaware; that the statute of limitations in Delaware and the spinoff agreement bar these claims at this time; that PPL is not liable for the claims in either the Talen Direct Action or the Talen Putative Class Action as PPL Montana was solvent at all relevant times; and that the separation agreement requires that Talen Energy indemnify PPL for all losses arising from the debts of Talen Montana, among other things. PPL's complaint also seeks damages against Riverstone for interfering with the separation agreement and against Riverstone affiliates for breach of the implied covenant of good faith and fair dealing. The complaint was subsequently amended on January 11, 2019 and March 20, 2019, to include, among other things, claims related to indemnification with respect to the Montana Actions, request a declaration that the Montana Actions are time-barred under the spinoff agreements, and allege additional facts to support the tortious interference claim. In April 2019, the defendants filed motions to dismiss the amended complaint. In July 2019, the Court heard oral arguments from the parties regarding the motions to dismiss, and in October 2019, the Delaware Court of Chancery issued an LKE indemnity relatingopinion sustaining all of the PPL plaintiffs' claims except for the claim for breach of implied covenant of good faith and fair dealing. As a result of the dismissal of the Talen Direct Action in December 2019, in January 2020, Talen Energy filed a new motion to dismiss five of the remaining eight claims in the amended complaint. The Court heard oral argument on the motion to dismiss on May 28, 2020, and on June 22, 2020, issued an opinion denying the motion in its former WKE lease, including related legal proceedings.entirety. Discovery is proceeding, and the parties have filed certain motions and cross-motions for summary judgment, which are not yet scheduled for hearing. The trial was previously scheduled for February 2022, but has been rescheduled for July 2022.
PPL believes that it has meritorious defenses to the claims made in the Talen Putative Class Action and intends to continue to vigorously defend against this action. The Talen Putative Class Action was stayed at an early stage of litigation. While the
158
Delaware Action is progressing, at this time PPL cannot predict the outcome of either of these matters or estimate the range of possible losses, if any, that PPL might incur as a result of the claims, although they could be material.
Cane Run Environmental Claims(PPL and LG&E)
In December 2013, six6 residents, on behalf of themselves and others similarly situated, filed a class action complaint against LG&E and PPL in the U.S. District Court for the Western District of Kentucky (U.S. District Court) alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In July 2014, the courtU.S. District Court dismissed the RCRA claims and all but one1 Clean Air Act claim, but declined to dismiss the common law tort claims. In November 2016, the plaintiffs filed an amended complaint removing the personal injury claims and removing certain previously named plaintiffs. In February 2017, the U.S. District Court issued an order dismissingdismissed PPL as a defendant and dismissingdismissed the final federal claim against LG&E. On&E, and in April 13, 2017, the federal District Court issued an orderOrder declining to exercise supplemental jurisdiction on the state law claims and dismisseddismissing the case in its entirety. OnIn June 16, 2017, the plaintiffs filed a class action complaint in Jefferson County, Kentucky Circuit Court, Kentucky, against LG&E alleging state law nuisance, negligence and trespass tort claims. The plaintiffs seeksought compensatory and punitive damages for alleged property damage due to purported plant emissions on behalf of a class of residents within one1 to three3 miles of the plant. Proceedings are currently underway regarding potentialOn January 8, 2020, the Jefferson Circuit Court issued an order denying the plaintiffs’ request for class certification,certification. On January 14, 2020, the plaintiffs filed a notice of appeal in the Kentucky Court of Appeals. On December 11, 2020, the Court of Appeals issued an order affirming the lower court’s denial of class certification. In December 2020, plaintiffs filed a petition for whichdiscretionary review with the Kentucky Supreme Court. On April 20, 2021, the Kentucky Supreme Court denied further review of the lower court order. The case was remanded to the Jefferson Circuit Court for the claims of the three remaining petitioners. Settlements with two of the three remaining petitioners were reached with none of the settlements having or expected to have a decision may occur in late 2018significant impact on LG&E's operations or in 2019. PPL, LKE and LG&E cannot predict the outcome of this matter. LG&E retired one coal-fired unit at the Cane Run plant in March 2015 and the remaining two coal-fired units at the plant in June 2015.financial condition.
E.W. Brown Environmental Claims(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. PPL, LKEThe aquatic study and KU cannot predict the outcome of these matters.
159
Air(PPL and LG&E)
Sulfuric Acid Mist Emissions
In June 2016, the EPA issued a notice of violation under the Clean Air Act alleging that LG&E violated applicable rules relating to sulfuric acid mist emissions at its Mill Creek plant. The notice alleges failure to install proper controls, failure to operate the facility consistent with good air pollution control practice and causing emissions exceeding applicable requirements or constituting a nuisance or endangerment. LG&E believes it has complied with applicable regulations during the relevant time period. On July 31, 2020, the U.S. Department of Justice and Louisville Metro Air Pollution Control District filed a complaint in the U.S. District Court for the Western District of Kentucky alleging violations specified in the EPA notice of violation and seeking civil penalties and injunctive relief. In November 2010,October 2020, LG&E filed a motion to dismiss the KEECcomplaint. In December 2020, the U.S. Department of Justice and the Louisville Metro Air Pollution Control District filed an amended complaint. In February 2021, LG&E filed a renewed motion to dismiss regarding the amended complaint. In September 2021, the parties reached a tentative agreement providing for dismissal of the court action, the payment by LG&E of a penalty amount and performance of a supplemental environmental project (SEP). The parties have entered a Consent Decree, which is awaiting approval from the U.S. District Court for the Western District of Kentucky. PPL and LG&E are unable to predict the final outcome of this matter but do not believe the matter, including the agreed penalty and SEP, will have a significant impact on LG&E's operations or financial condition.
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 "no 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. On October 13, 2020, the EPA published final revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). The rule is 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. In August 2021, the EPA published a notice of rulemaking announcing that it will propose revisions to the Reconsideration Rule and determine "whether more stringent limitations and standards are appropriate." Compliance with the Reconsideration Rule is required during the pendency of the rulemaking process.
CCRs
In 2015, the EPA issued a final order upholding the permit,rule governing management of CCRs which was subsequently appealed by the environmental groups. In September 2013, the Franklin Circuit Court reversed the KEEC orderinclude fly ash, bottom ash and remanded the permitsulfur 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 agency for further proceedings. LG&E and the KEEC appealed the order to the Kentucky Courtbeneficial use of Appeals.CCRs. In July 2015,2018, 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 upheldvacated and remanded portions of the lowerCCR Rule. In December 2019, the EPA addressed the deficiencies identified by the court ruling. LG&E and proposed amendments to change the KEEC movedclosure deadline. In August 2020, the EPA published a final rule extending the deadline to initiate closure to April 11, 2021, while providing for discretionarycertain extensions. The EPA is conducting ongoing rulemaking actions regarding various other amendments to the rule. Certain ongoing legal challenges to various provisions of the CCR Rule have been held in abeyance pending review by the Kentucky Supreme Court. In February 2016, the Kentucky Supreme Court issued an order granting discretionary review and oral arguments were held in September 2016. On April 27, 2017, the Kentucky Supreme Court issued an order reversing the decision of the appellate court and upholding the permit issued to LG&E by the KEEC.
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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 approvalsdeterminations or potential impacts on current LG&E and KU compliance plans. The Registrants are currently finalizing closure plans and schedules.
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 projectclosure 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. As of April 2021, LG&E and federal laws.KU have commenced closure of all of the subject impoundments and have completed closure of some of their smaller impoundments. LG&E and KU generally expect to complete 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 20 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.
(All Registrants)
Superfund and Other Remediation
PPL Electric, LG&E and KU 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 and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL Electric, LG&E and KU. PPL Electric is potentially responsible for a share of clean-up costs at certain sites including the Columbia Gas Plant site and the Brodhead site. 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.
At December 31, 2021 and December 31, 2020, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites identified above. 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 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.
Regulatory Issues
See Note 67 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.
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PPL Electric, LG&E and KU 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 (including RFC or SERC) 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 cannotan estimate aor range of reasonably possible losses if any.cannot be determined.
Gas - Security Directives(PPL LKE,and LG&E and KU)&E)
In December 2015, 195 nations, includingMay and July of 2021, the U.S., signed the Paris Agreement on Climate, which establishes a comprehensive framework for the reductionDepartment of GHG emissions from both developed and developing nations. Although the agreement does not establish binding reduction requirements, it requires each nation to prepare, communicate, and maintain GHG reduction commitments. Reductions can be achieved in a variety of ways, including energy conservation, power plant efficiency improvements, reduced utilization of coal-fired generation or replacing coal-fired generation with natural gas or renewable generation. Based on the EPA's rules issued in 2015 imposing GHG emission standards for both new and existing power plants, the U.S. committed to an initial reduction target of 26% to 28% below 2005 levels by 2025. However, on June 1, 2017, President Trump announced a plan to withdraw from the Paris Agreement and undertake negotiations to reenter the current agreement or enter a new agreement on terms more favorable to the U.S. Under the terms of the Paris Agreement, any U.S. withdrawal would not be complete until November 2020.
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. SuchExamples of such agreements include, for example,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 securitiesobligations of PPL Capital Funding.
(All Registrants)
The table below details guarantees provided as of December 31, 2017.2021. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote except for "WPD guarantee of pension and other obligations of unconsolidated entities" and "Indemnification of lease termination and other divestitures." The total recorded liability at December 31, 2017 was $17 million for PPL and $11 million for LKE. The $11 million recorded at LKE represents the settlement amount related to WKE's excess power matter. See footnote (e) for additional information. The total recorded liability at December 31, 2016 was $22 million for PPL and $17 million for LKE.remote. For reporting purposes, on a consolidated basis, allthe guarantees of PPL Electric, LKE,include the guarantees of its subsidiary Registrants.
| Exposure at December 31, 2021 | Expiration Date | ||||||||||
| PPL | |||||||||||
| Indemnifications related to the sale of the U.K. utility business | (a) | ||||||||||
| Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business | £ | 50 | (b) | 2028 | |||||||
| LG&E and KU | |||||||||||
| LG&E and KU obligation of shortfall related to OVEC | (c) | ||||||||||
(a)PPL WPD Limited agreed to provide a standard indemnity regarding “leakage” amounts, which included amounts taken out of the sold assets through dividends, return of capital, bonuses or similar method, received or waived by WPD (or its affiliates defined as members of the Sellers Group in the SPA) during the period from April 1, 2020 through June 14, 2021, except such amounts permitted under the WPD SPA. The amount of the cap on this indemnity was £7,881 million, the amount paid to PPL WPD Limited at closing. This indemnification expired in December 2021 and no claims have been made.
(b)PPL WPD Limited entered into a Tax Deed dated June 9, 2021 in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings
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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.
(c)Pursuant to the OVEC power purchase contract, LG&E and KU also applyare obligated to PPL,pay for their share of OVEC's excess debt service, post-retirement and all guaranteesdecommissioning 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 $92 million at December 31, 2021, consisting of LG&E&E's share of $64 million and KU also apply to LKE.KU's share of $28 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract.
| Exposure at December 31, 2017 | Expiration Date | ||||
| PPL | |||||
| Indemnifications related to the WPD Midlands acquisition | (a) | ||||
| WPD indemnifications for entities in liquidation and sales of assets | $ | 11 | (b) | 2020 | |
| WPD guarantee of pension and other obligations of unconsolidated entities | 95 | (c) | |||
| PPL Electric | |||||
| Guarantee of inventory value | 16 | (d) | 2018 | ||
| LKE | |||||
| Indemnification of lease termination and other divestitures | 201 | (e) | 2021-2023 | ||
| LG&E and KU | |||||
| LG&E and KU guarantee of shortfall related to OVEC | (f) | ||||
OVEC obligations filed for bankruptcy under Chapter 11 and, in August 2018, received a rejection order for the OVEC power purchase contract in the bankruptcy proceeding. OVEC and other entities challenged the contract rejection, the bankruptcy plan confirmation and regulatory aspects of the plan in various forums. In connection with their sales of various businesses, WPDMay 2020, OVEC and its affiliates have provided the purchasers with indemnifications that are standard for such transactions,relevant sponsor announced a settlement resolving all disputed matters in the bankruptcy and other proceedings, including indemnifications for certain pre-existing liabilities and environmental and tax matters or have agreed to continue their obligations under existing third-party guarantees, either for a set period of time following the transactions or upon the conditionproviding that the purchasers make reasonable effortssponsor will withdraw its request to terminatereject the guarantees. Additionally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties.power purchase agreement. The settlement was implemented in July 2020.
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 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 million. This insurance may be applicable to obligations under certain of these contractual arrangements.
Risks and Uncertainties(All Registrants)
To date, there has been no material impact on the Registrants’ operations, financial condition, liquidity or on their supply chain as a result of COVID-19; however, the duration and severity of the outbreak and its ultimate effects on the global economy, the financial markets, or the Registrants’ workforce, customers and suppliers are uncertain. A protracted slowdown of broad sectors of the economy, prolonged or pervasive restrictions on businesses and their workforces, or significant changes in legislation or regulatory policy to address the COVID-19 pandemic all present significant risks to the Registrants. These or other unpredictable events resulting from the pandemic could reduce customer demand for electricity and gas, impact the Registrants’ employees and supply chains, result in an increase in certain costs, delay payments or increase bad debts, or result in changes in the fair value of their assets and liabilities, which could materially and adversely affect the Registrants’ business, results of operations, financial condition or liquidity.
Wholesale Sales and Purchases(LG&E and KU)
LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation.
Support Costs(PPL Electric, LKE, LG&E and KU)
PPL Services, PPL EU Services, prior to its merger into PPL Services as of December 31, 2021, and LKS provide PPL, PPL Electric and LKE, their respective subsidiaries, including LG&E and KU,the Registrants and each other with administrative, management and support services. For all serviceservices companies, the costs of thesedirectly 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
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costs. PPL Services and PPL EU Services 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 may also use a ratio of overall direct and indirect costs.costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 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.
| 2021 | 2020 | 2019 | |||||||||||||||
| PPL Electric from PPL Services | $ | 54 | $ | 50 | $ | 59 | |||||||||||
| PPL Electric from PPL EU Services | 222 | 176 | 152 | ||||||||||||||
| LG&E from LKS | 169 | 170 | 160 | ||||||||||||||
| KU from LKS | 179 | 180 | 178 | ||||||||||||||
| 2017 | 2016 | 2015 | |||||||||
| PPL Electric from PPL Services | $ | 182 | $ | 132 | $ | 125 | |||||
| LKE from PPL Services | 20 | 18 | 16 | ||||||||
| PPL Electric from PPL EU Services | 64 | 69 | 60 | ||||||||
| LG&E from LKS | 169 | 178 | 155 | ||||||||
| KU from LKS | 190 | 194 | 185 | ||||||||
In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKEPPL and LG&E and KU are reimbursed through LKS.
Intercompany Borrowings
(PPL Electric)
PPL Energy Funding maintains a $400$1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2021, PPL Energy Funding had borrowings outstanding in the amount of $499 million. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. No balance was outstanding at December 31, 2017 and 2016.2020. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the revolving line of credit was not significant for 2017, 2016 or 2015.Income Statements.
(LG&E)
LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 millionthe difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues.issues and two additional rate options based on LIBOR. LG&E's money pool borrowing limit is $325 million. At December 31, 2021, LG&E had borrowings outstanding from LKE in the amount of $324 million. This balance is reflected in "Notes payable with affiliates" on the LG&E balance sheets. No balances were outstanding at December 31, 2017 and 2016. Interest expense incurred on the money pool agreement with KU was not significant for 2017 or 2016. There was no money pool activity with KU in 2015.2020.
(KU)
KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 millionthe difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues.issues and two additional rate options based on LIBOR. KU's money pool borrowing limit is $300 million. At December 31, 2021, KU had borrowings outstanding from LKE in the amount of $294 million. This balance is reflected in "Notes payable with affiliates" on the KU balance sheets. No balances were outstanding at December 31, 2017 and 2016. Interest income incurred2020.
VEBA Funds Receivable (PPL Electric)
In May 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 the money pool agreementBalance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with LG&Ethese funds was not significant for 2017$11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and 2016. There$1 million was no money pool activityreflected in "Other noncurrent assets" on the Balance Sheets. The intercompany receivable balance associated with LG&Ethese funds was $22 million as of December 31, 2020, of which $10 million was reflected in 2015."Accounts receivable from affiliates" and $12 million was reflected in "Other noncurrent assets" on the Balance Sheets.
Other(LKE,PPL Electric, LG&E and KU)
See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE)Electric). For PPL Electric, LG&E and KU, see Note 1112 for discussions regarding intercompany allocations associated with defined benefits.
(PPL)
The breakdowncomponents of "Other Income (Expense) - net" for the years ended December 31, was:were:
| 2021 | 2020 | 2019 | |||||||||||||||
| Other Income | |||||||||||||||||
| Defined benefit plans - non-service credits (Note 12) | $ | 21 | $ | (2) | $ | 8 | |||||||||||
| Interest income | 12 | 9 | 15 | ||||||||||||||
| AFUDC - equity component | 18 | 20 | 23 | ||||||||||||||
| Miscellaneous | 10 | 7 | 7 | ||||||||||||||
| Total Other Income | 61 | 34 | 53 | ||||||||||||||
| Other Expense | |||||||||||||||||
| Charitable contributions | 14 | 3 | 17 | ||||||||||||||
| Miscellaneous | 32 | 29 | 22 | ||||||||||||||
| Total Other Expense | 46 | 32 | 39 | ||||||||||||||
| Other Income (Expense) - net | $ | 15 | $ | 2 | $ | 14 | |||||||||||
(PPL Electric)
The components of Contents"Other Income (Expense) - net" for the years ended December 31, were:
| 2017 | 2016 | 2015 | 2021 | 2020 | 2019 | |||||||||||||||||||||||
| Other Income | Other Income | |||||||||||||||||||||||||||
| Economic foreign currency exchange contracts (Note 17) | $ | (261 | ) | $ | 384 | $ | 122 | |||||||||||||||||||||
| Defined benefit plans - non-service credits (Note 12) | Defined benefit plans - non-service credits (Note 12) | $ | 9 | $ | 4 | $ | 4 | |||||||||||||||||||||
| Interest income | 2 | 3 | 4 | Interest income | — | 2 | 2 | |||||||||||||||||||||
| AFUDC - equity component | 16 | 19 | 14 | AFUDC - equity component | 18 | 19 | 23 | |||||||||||||||||||||
| Miscellaneous | 17 | 6 | 6 | |||||||||||||||||||||||||
| Total Other Income | (226 | ) | 412 | 146 | Total Other Income | 27 | 25 | 29 | ||||||||||||||||||||
| Other Expense | Other Expense | |||||||||||||||||||||||||||
| Charitable contributions | 8 | 9 | 21 | Charitable contributions | 3 | 3 | 3 | |||||||||||||||||||||
| Miscellaneous | 21 | 13 | 17 | Miscellaneous | 3 | 4 | 1 | |||||||||||||||||||||
| Total Other Expense | 29 | 22 | 38 | Total Other Expense | 6 | 7 | 4 | |||||||||||||||||||||
| Other Income (Expense) - net | $ | (255 | ) | $ | 390 | $ | 108 | Other Income (Expense) - net | $ | 21 | $ | 18 | $ | 25 | ||||||||||||||
(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. Transfers between levels are recognized at end-of-reporting-period values. During 2017 and 2016, there were no transfers between Level 1 and Level 2. See Note 1 for information on the levels in the fair value hierarchy.
Recurring Fair Value Measurements
The assets and liabilities measured at fair value were:
| December 31, 2017 | December 31, 2016 | ||||||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 485 | $ | 485 | $ | — | $ | — | $ | 341 | $ | 341 | $ | — | $ | — | |||||||||||||||
| Restricted cash and cash equivalents (a) | 26 | 26 | — | — | 26 | 26 | — | — | |||||||||||||||||||||||
| Price risk management assets (b): | |||||||||||||||||||||||||||||||
| Foreign currency contracts | 163 | — | 163 | — | 211 | — | 211 | — | |||||||||||||||||||||||
| Cross-currency swaps | 101 | — | 101 | — | 188 | — | 188 | — | |||||||||||||||||||||||
| Total price risk management assets | 264 | — | 264 | — | 399 | — | 399 | — | |||||||||||||||||||||||
| Total assets | $ | 775 | $ | 511 | $ | 264 | $ | — | $ | 766 | $ | 367 | $ | 399 | $ | — | |||||||||||||||
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 3,571 | $ | 3,571 | $ | — | $ | — | $ | 442 | $ | 442 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Restricted cash and cash equivalents (a) | 1 | 1 | — | — | 1 | 1 | — | — | |||||||||||||||||||||||||||||||||||||||
| Special use funds (a): | |||||||||||||||||||||||||||||||||||||||||||||||
| Money market fund | 2 | 2 | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||
| Commingled debt fund measured at NAV (b) | 22 | — | — | — | 26 | — | — | — | |||||||||||||||||||||||||||||||||||||||
| Commingled equity fund measured at NAV (b) | 21 | — | — | — | 25 | — | — | — | |||||||||||||||||||||||||||||||||||||||
| Total special use funds | 45 | 2 | — | — | 51 | — | — | — | |||||||||||||||||||||||||||||||||||||||
| Total assets | $ | 3,617 | $ | 3,574 | $ | — | $ | — | $ | 494 | $ | 443 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Liabilities | |||||||||||||||||||||||||||||||||||||||||||||||
| Price risk management liabilities (c): | |||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps | $ | 18 | $ | — | $ | 18 | $ | — | $ | 23 | $ | — | $ | 23 | $ | — | |||||||||||||||||||||||||||||||
| Total price risk management liabilities | $ | 18 | $ | — | $ | 18 | $ | — | $ | 23 | $ | — | $ | 23 | $ | — | |||||||||||||||||||||||||||||||
| PPL Electric | |||||||||||||||||||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 21 | $ | 21 | $ | — | $ | — | $ | 40 | $ | 40 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Total assets | $ | 21 | $ | 21 | $ | — | $ | — | $ | 40 | $ | 40 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| LG&E | |||||||||||||||||||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 9 | $ | 9 | $ | — | $ | — | $ | 7 | $ | 7 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Total assets | $ | 9 | $ | 9 | $ | — | $ | — | $ | 7 | $ | 7 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Liabilities | |||||||||||||||||||||||||||||||||||||||||||||||
| Price risk management liabilities: | |||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps | $ | 18 | $ | — | $ | 18 | $ | — | $ | 23 | $ | — | $ | 23 | $ | — | |||||||||||||||||||||||||||||||
| Total price risk management liabilities | $ | 18 | $ | — | $ | 18 | $ | — | $ | 23 | $ | — | $ | 23 | $ | — | |||||||||||||||||||||||||||||||
| KU | |||||||||||||||||||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 13 | $ | 13 | $ | — | $ | — | $ | 22 | $ | 22 | $ | — | $ | — | |||||||||||||||||||||||||||||||
| Total assets | $ | 13 | $ | 13 | $ | — | $ | — | $ | 22 | $ | 22 | $ | — | $ | — | |||||||||||||||||||||||||||||||
(a)Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.
(b)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 statement of financial position.
(c)Current portion is included in "Other current liabilities" and noncurrent portion is included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
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 Statement of Income.
166
| December 31, 2017 | December 31, 2016 | ||||||||||||||||||||||||||||||
| Total | Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | ||||||||||||||||||||||||
| Liabilities | |||||||||||||||||||||||||||||||
| Price risk management liabilities (b): | |||||||||||||||||||||||||||||||
| Interest rate swaps | $ | 26 | $ | — | $ | 26 | $ | — | $ | 31 | $ | — | $ | 31 | $ | — | |||||||||||||||
| Foreign currency contracts | 148 | — | 148 | — | 27 | — | 27 | — | |||||||||||||||||||||||
| Total price risk management liabilities | $ | 174 | $ | — | $ | 174 | $ | — | $ | 58 | $ | — | $ | 58 | $ | — | |||||||||||||||
| PPL Electric | |||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 49 | $ | 49 | $ | — | $ | — | $ | 13 | $ | 13 | $ | — | $ | — | |||||||||||||||
| Restricted cash and cash equivalents (a) | 2 | 2 | — | — | 2 | 2 | — | — | |||||||||||||||||||||||
| Total assets | $ | 51 | $ | 51 | $ | — | $ | — | $ | 15 | $ | 15 | $ | — | $ | — | |||||||||||||||
| LKE | |||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 30 | $ | 30 | $ | — | $ | — | $ | 13 | $ | 13 | $ | — | $ | — | |||||||||||||||
| Cash collateral posted to counterparties (c) | — | — | — | — | 3 | 3 | — | — | |||||||||||||||||||||||
| Total assets | $ | 30 | $ | 30 | $ | — | $ | — | $ | 16 | $ | 16 | $ | — | $ | — | |||||||||||||||
| Liabilities | |||||||||||||||||||||||||||||||
| Price risk management liabilities: | |||||||||||||||||||||||||||||||
| Interest rate swaps | $ | 26 | $ | — | $ | 26 | $ | — | $ | 31 | $ | — | $ | 31 | $ | — | |||||||||||||||
| Total price risk management liabilities | $ | 26 | $ | — | $ | 26 | $ | — | $ | 31 | $ | — | $ | 31 | $ | — | |||||||||||||||
| LG&E | |||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 15 | $ | 15 | $ | — | $ | — | $ | 5 | $ | 5 | $ | — | $ | — | |||||||||||||||
| Cash collateral posted to counterparties (c) | — | — | — | — | 3 | 3 | — | — | |||||||||||||||||||||||
| Total assets | $ | 15 | $ | 15 | $ | — | $ | — | $ | 8 | $ | 8 | $ | — | $ | — | |||||||||||||||
| Liabilities | |||||||||||||||||||||||||||||||
| Price risk management liabilities: | |||||||||||||||||||||||||||||||
| Interest rate swaps | $ | 26 | $ | — | $ | 26 | $ | — | $ | 31 | $ | — | $ | 31 | $ | — | |||||||||||||||
| Total price risk management liabilities | $ | 26 | $ | — | $ | 26 | $ | — | $ | 31 | $ | — | $ | 31 | $ | — | |||||||||||||||
| KU | |||||||||||||||||||||||||||||||
| Assets | |||||||||||||||||||||||||||||||
| Cash and cash equivalents | $ | 15 | $ | 15 | $ | — | $ | — | $ | 7 | $ | 7 | $ | — | $ | — | |||||||||||||||
| Total assets | $ | 15 | $ | 15 | $ | — | $ | — | $ | 7 | $ | 7 | $ | — | $ | — | |||||||||||||||
Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps(PPL, LKE, LG&E and KU)
To manage interest rate risk, PPL, LKE, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency exchange risk, PPL uses foreign currency contracts such as forwards, options, and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), 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.
Financial Instruments Not Recorded at Fair Value(All Registrants)
The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. The fair values were estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporate the credit risk of the Registrants. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||
| Carrying Amount (a) | Fair Value | Carrying Amount (a) | Fair Value | ||||||||||||||||||||
| PPL | $ | 11,140 | $ | 12,955 | $ | 14,689 | $ | 17,774 | |||||||||||||||
| PPL Electric | 4,484 | 5,272 | 4,236 | 5,338 | |||||||||||||||||||
| LG&E | 2,006 | 2,363 | 2,007 | 2,499 | |||||||||||||||||||
| KU | 2,618 | 3,120 | 2,618 | 3,334 | |||||||||||||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||
| Carrying Amount (a) | Fair Value | Carrying Amount (a) | Fair Value | ||||||||||||
| PPL | $ | 20,195 | $ | 23,783 | $ | 18,326 | $ | 21,355 | |||||||
| PPL Electric | 3,298 | 3,769 | 2,831 | 3,148 | |||||||||||
| LKE | 5,159 | 5,670 | 5,065 | 5,439 | |||||||||||
| LG&E | 1,709 | 1,865 | 1,617 | 1,710 | |||||||||||
| KU | 2,328 | 2,605 | 2,327 | 2,514 | |||||||||||
(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.
Risk Management Objectives
(All Registrants)
PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances and foreign exchange (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, 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, interest rates and foreign currency exchange 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.
167
Interest Rate Risk
•PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. Prior to the sale of the U.K. utility business on June 14, 2021, PPL and WPD holdheld over-the-counter cross currency swaps to limit exposure to market fluctuations on interest and principal payments from changes in foreign currency exchange rates and interest rates. PPL LKE and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LKE, LG&E
and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuances.
•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 domestic utilities and, prior to the sale of the U.K. utility business on June 14, 2021, for certain plans at WPD due to the recovery methods in place.
Foreign Currency Risk (PPL)
•PPL iswas exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates.
(All Registrants)
Commodity Price Risk
PPL is exposed to commodity price risk through its domestic subsidiaries as described below.
•PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is insignificant and mitigated through its PUC-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 expenses. These mechanisms generally provide for timely recovery of market price fluctuations associated with these expenses.
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.
•WPD iswas exposed to volumetric risk which iswas significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 for additional information on revenue recognition under RIIO-ED1.
•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.
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 at the regulated domestic utilities and for certain plans at WPD 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" interest rate and foreign currency derivativestransactions with financial institutions,counterparties, as well as additional credit risk through certain of its subsidiaries, as discussed below.
In the event a supplier of PPL Electric, LG&E or KU defaults on its 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.
168
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' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit.
Master Netting Arrangements(PPL, LKE, 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 a $20 millionno obligation and $19 millionan immaterial obligation to return cash collateral under master netting arrangements at December 31, 20172021 and 2016.2020.
LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 20172021 and 2016.2020.
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 heldhad no such contracts at December 31, 2017.2021.
$500 million of WPD’sWPD's U.S. dollar-denominated senior notes were repaid uponprior to maturity and $100$500 million notional value of
cross-currency interest rate swap contracts matured. PPL recorded a $19 million gain upon settlement of the cross-currency interest rate swap contracts, which largely offset a loss recorded on the revaluation of U.S. dollar-denominated senior notes.
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 2021, 2020 and 2019, PPL had an insignificant amount ofno cash flow hedges reclassified into earnings associated with discontinued cash flow hedges in 2017 and 2016.hedges.
At December 31, 2017,2021, 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.
169
Economic Activity(PPL LKE and LG&E)
LG&E enters into interest rate swap contracts that economically hedge interest payments on variable rate debt.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. In December 2016, a swap with a notional amount of $32 million was terminated. A cash settlement of $9 million was paid on the terminated swap. The settlement is included in noncurrent regulatory assets on the Balance Sheet and in "Cash Flows from Operating Activities" on the Statement of Cash Flows. At December 31, 2017,2021, LG&E held contracts with a notional amount of $147$64 million that rangemature in maturity through 2033.
Foreign Currency Risk
(PPL)
PPL iswas exposed to foreign currency risk, primarily through investments in and earnings of U.K.U.K affiliates. PPL has adopted a foreign currency risk management program designed to hedge certain foreign currency exposures, including firm commitments, recognized assets or liabilities, anticipated transactions, including the sale of its U.K utility business and net investments. In addition, PPL entersentered into financial instruments to protect against foreign currency translation risk of expected GBP earnings.
Net Investment Hedges
PPL entersentered into foreign currency contracts on behalf of a subsidiary to protect the value of a portion of its net investment in WPD. There were no contracts outstanding at December 31, 2017.2021.
At December 31, 2017 and 2016,2020, PPL had $22 million and $21$33 million of accumulated net investment hedge after tax gains (losses) that were included in the foreign currency translation adjustment component of AOCI. The remaining balance was transferred out of AOCI and
realized in discontinued operations as a result of the sale of the U.K. utility business.
Economic Activity
PPL entersentered into foreign currency contracts on behalf of a subsidiarysubsidiaries to economically hedge GBP-denominated anticipated earnings. At December 31, 2017, the total exposure hedged by PPL was approximately £2.6 billion (approximately $3.5 billion based on contracted rates). These contracts had termination dates ranging from January 2018 through June 2020.
Accounting and Reporting
(All Registrants)
All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNSthe Normal Purchase Normal Sale scope exception (NPNS) is elected. NPNS contracts for PPL and PPL Electric include certain full-requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 67 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 20172021 and 2016.2020.
See Note 1 for additional information on accounting policies related to derivative instruments.
(PPL)
The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets. Sheets:
170
| December 31, 2017 | December 31, 2016 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivatives designated as hedging instruments | Derivatives not designated as hedging instruments | Derivatives designated as hedging instruments | Derivatives not designated as hedging instruments | Derivatives designated as hedging instruments | Derivatives not designated as hedging instruments | Derivatives designated as hedging instruments | Derivatives not designated as hedging instruments | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | Assets | Liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current: | Current: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Price Risk Management | Price Risk Management | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Assets/Liabilities (a): | Assets/Liabilities (a): | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps (b) | $ | — | $ | — | $ | — | $ | 4 | $ | — | $ | — | $ | — | $ | 4 | Interest rate swaps (b) | $ | — | $ | — | $ | — | $ | 1 | $ | — | $ | — | $ | — | $ | 2 | |||||||||||||||||||||||||||||||||||||||||||||
| Cross-currency swaps (b) | 4 | — | — | — | 32 | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Foreign currency contracts | — | — | 45 | 67 | — | — | 31 | 21 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cross-currency swaps (c) | Cross-currency swaps (c) | — | — | — | — | 94 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Foreign currency contracts (c) | Foreign currency contracts (c) | — | — | — | — | — | — | — | 137 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total current | 4 | — | 45 | 71 | 32 | — | 31 | 25 | Total current | — | — | — | 1 | 94 | — | — | 139 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Noncurrent: | Noncurrent: | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Price Risk Management | Price Risk Management | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Assets/Liabilities (a): | Assets/Liabilities (a): | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Interest rate swaps (b) | — | — | — | 22 | — | — | — | 27 | Interest rate swaps (b) | — | — | — | 17 | — | — | — | 21 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cross-currency swaps (b) | 97 | — | — | — | 156 | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Foreign currency contracts | — | — | 118 | 81 | — | — | 180 | 6 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Cross-currency swaps (c) | Cross-currency swaps (c) | — | — | — | — | 52 | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total noncurrent | 97 | — | 118 | 103 | 156 | — | 180 | 33 | Total noncurrent | — | — | — | 17 | 52 | — | — | 21 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Total derivatives | $ | 101 | $ | — | $ | 163 | $ | 174 | $ | 188 | $ | — | $ | 211 | $ | 58 | Total derivatives | $ | — | $ | — | $ | — | $ | 18 | $ | 146 | $ | — | $ | — | $ | 160 | |||||||||||||||||||||||||||||||||||||||||||||
(a)Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
(b)Excludes accrued interest, if applicable.
(c)Included in "Current assets held for sale" and "Current liabilities held for sale" on the Balance Sheet.
The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities.liabilities:
| Derivative Relationships | Derivative Gain (Loss) Recognized in OCI | Location of Gain (Loss) Recognized in Income on Derivative | Gain (Loss) Reclassified from AOCI into Income | |||||||||||||||||
| 2021 | ||||||||||||||||||||
| Cash Flow Hedges: | ||||||||||||||||||||
| Interest rate swaps | $ | — | Interest Expense | $ | 11 | |||||||||||||||
| Income (Loss) from Discontinued operations (net of taxes) | (2) | |||||||||||||||||||
| Cross-currency swaps | (50) | Income (Loss) from Discontinued operations (net of taxes) | (39) | |||||||||||||||||
| Total | $ | (50) | $ | (30) | ||||||||||||||||
| Net Investment Hedges: | ||||||||||||||||||||
| Foreign currency contracts in Discontinued operations | $ | 1 | ||||||||||||||||||
| 2020 | ||||||||||||||||||||
| Cash Flow Hedges: | ||||||||||||||||||||
| Interest rate swaps | $ | (9) | Interest Expense | $ | (8) | |||||||||||||||
| Income (Loss) from Discontinued operations (net of taxes) | (2) | |||||||||||||||||||
| Cross-currency swaps | (15) | Income (Loss) from Discontinued operations (net of taxes) | (22) | |||||||||||||||||
| Total | $ | (24) | $ | (32) | ||||||||||||||||
| Net Investment Hedges: | ||||||||||||||||||||
| Foreign currency contracts in Discontinued operations | $ | 1 | ||||||||||||||||||
| 2019 | ||||||||||||||||||||
| Cash Flow Hedges: | ||||||||||||||||||||
| Interest rate swaps | $ | (30) | Interest Expense | $ | (9) | |||||||||||||||
| Cross-currency swaps | 17 | Income (Loss) from Discontinued operations (net of taxes) | (9) | |||||||||||||||||
| Total | $ | (13) | $ | (18) | ||||||||||||||||
| Net Investment Hedges: | ||||||||||||||||||||
| Foreign currency contracts in Discontinued operations | $ | 2 | ||||||||||||||||||
Derivative Relationships | Derivative Gain (Loss) Recognized in OCI (Effective Portion) | Location of Gain (Loss) Recognized in Income on Derivative | Gain (Loss) Reclassified from AOCI into Income (Effective Portion) | Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing) | ||||||||||
| 2017 | ||||||||||||||
| Cash Flow Hedges: | ||||||||||||||
| Interest rate swaps | $ | — | Interest Expense | $ | (9 | ) | $ | — | ||||||
| Cross-currency swaps | (98 | ) | Other Income (Expense) - net | (82 | ) | — | ||||||||
| Total | $ | (98 | ) | $ | (91 | ) | $ | — | ||||||
| Net Investment Hedges: | ||||||||||||||
| Foreign currency contracts | $ | 1 | ||||||||||||
| 2016 | ||||||||||||||
| Cash Flow Hedges: | ||||||||||||||
| Interest rate swaps | $ | (21 | ) | Interest Expense | $ | (7 | ) | $ | — | |||||
| Cross-currency swaps | 130 | Other Income (Expense) - net | 116 | — | ||||||||||
| Interest Expense | 3 | — | ||||||||||||
| Total | $ | 109 | $ | 112 | $ | — | ||||||||
| Net Investment Hedges: | ||||||||||||||
| Foreign currency contracts | $ | 2 | ||||||||||||
| Derivatives Not Designated as Hedging Instruments | Location of Gain (Loss) Recognized in Income on Derivative | 2021 | 2020 | 2019 | ||||||||||||||||||||||
| Foreign currency contracts | Income (Loss) from Discontinued Operations (net of taxes) | $ | (266) | $ | (98) | $ | (14) | |||||||||||||||||||
| Interest rate swaps | Interest Expense | (2) | (5) | (5) | ||||||||||||||||||||||
| Total | $ | (268) | $ | (103) | $ | (19) | ||||||||||||||||||||
| Derivatives Not Designated as Hedging Instruments | Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets | 2021 | 2020 | 2019 | ||||||||||||||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | 5 | $ | (2) | $ | (1) | |||||||||||||||||||
Derivative Relationships | Derivative Gain (Loss) Recognized in OCI (Effective Portion) | Location of Gain (Loss) Recognized in Income on Derivative | Gain (Loss) Reclassified from AOCI into Income (Effective Portion) | Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing) | ||||||||||
| 2015 | ||||||||||||||
| Cash Flow Hedges: | ||||||||||||||
| Interest rate swaps | $ | (34 | ) | Interest Expense | $ | (11 | ) | $ | — | |||||
| Discontinued operations | — | (77 | ) | |||||||||||
| Cross-currency swaps | 60 | Other Income (Expense) - net | 49 | — | ||||||||||
| Interest Expense | 2 | — | ||||||||||||
| Commodity contracts | Discontinued operations | 13 | 7 | |||||||||||
| Total | $ | 26 | $ | 53 | $ | (70 | ) | |||||||
| Net Investment Hedges: | ||||||||||||||
| Foreign currency contracts | $ | 9 | ||||||||||||
Derivatives Not Designated as Hedging Instruments | Location of Gain (Loss) Recognized in Income on Derivative | 2017 | 2016 | 2015 | ||||||||||
| Foreign currency contracts | Other Income (Expense) - net | $ | (261 | ) | $ | 384 | $ | 122 | ||||||
| Interest rate swaps | Interest Expense | (6 | ) | (7 | ) | (8 | ) | |||||||
| Total | $ | (267 | ) | $ | 377 | $ | 114 | |||||||
Derivatives Designated as Hedging Instruments | Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | — | $ | — | $ | (22 | ) | ||||||
Derivatives Not Designated as Hedging Instruments | Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | 5 | $ | 7 | $ | 1 | |||||||
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets. All derivative instruments designated as cash flow hedges were terminated in 2015 and there is nohedge activity inon the current period.Statement of Income for the year ended December 31, 2021:
| Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships | |||||||||||
| Interest Expense | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||
| Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded | $ | 918 | $ | (1,498) | |||||||
| 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 | 11 | (2) | |||||||||
| Cross-currency swaps: | |||||||||||
| Hedged items | — | 39 | |||||||||
| Amount of gain (loss) reclassified from AOCI to income | — | (39) | |||||||||
| Derivative Instruments | Location of Gain (Loss) | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | — | $ | — | $ | (22 | ) | ||||||
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets. All derivative instruments designated as cash flow hedges were terminated in 2015 and there is nohedge activity inon the current period.Statement of Income for the year ended December 31, 2020:
| Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships | |||||||||||
| Interest Expense | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||
| Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded | $ | 634 | $ | 829 | |||||||
| 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 | (8) | (2) | |||||||||
| Cross-currency swaps: | |||||||||||
| Hedged items | — | 22 | |||||||||
| Amount of gain (loss) reclassified from AOCI to income | — | (22) | |||||||||
| Derivative Instruments | Location of Gain (Loss) | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory asset - noncurrent | $ | — | $ | — | $ | (11 | ) | ||||||
The following table presents the pre-tax effect of derivative instruments designated as cash flow hedges that are recognized in regulatory assets. All derivative instruments designated as cash flow hedges were terminated in 2015 and there is nohedge activity inon the current period.Statement of Income for the year ended December 31,2019:
| Derivative Instruments | Location of Gain (Loss) | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | — | $ | — | $ | (11 | ) | ||||||
| Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships | |||||||||||
| Interest Expense | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||
| Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded | $ | 621 | $ | 1,010 | |||||||
| 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 | (9) | — | |||||||||
| Cross-currency swaps: | |||||||||||
| Hedged items | — | 9 | |||||||||
| Amount of gain (loss) reclassified from AOCI to income | — | (9) | |||||||||
(LG&E)
The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.instruments:
| December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||
| Assets | Liabilities | Assets | Liabilities | |||||||||||||||||||||||
| Current: | ||||||||||||||||||||||||||
| Price Risk Management | ||||||||||||||||||||||||||
| Assets/Liabilities: | ||||||||||||||||||||||||||
| Interest rate swaps | $ | — | $ | 1 | $ | — | $ | 2 | ||||||||||||||||||
| Total current | — | 1 | — | 2 | ||||||||||||||||||||||
| Noncurrent: | ||||||||||||||||||||||||||
| Price Risk Management | ||||||||||||||||||||||||||
| Assets/Liabilities: | ||||||||||||||||||||||||||
| Interest rate swaps | — | 17 | — | 21 | ||||||||||||||||||||||
| Total noncurrent | — | 17 | — | 21 | ||||||||||||||||||||||
| Total derivatives | $ | — | $ | 18 | $ | — | $ | 23 | ||||||||||||||||||
| December 31, 2017 | December 31, 2016 | |||||||||||||||
| Assets | Liabilities | Assets | Liabilities | |||||||||||||
| Current: | ||||||||||||||||
| Price Risk Management | ||||||||||||||||
| Assets/Liabilities: | ||||||||||||||||
| Interest rate swaps | $ | — | $ | 4 | $ | — | $ | 4 | ||||||||
| Total current | — | 4 | — | 4 | ||||||||||||
| Noncurrent: | ||||||||||||||||
| Price Risk Management | ||||||||||||||||
| Assets/Liabilities: | ||||||||||||||||
| Interest rate swaps | — | 22 | — | 27 | ||||||||||||
| Total noncurrent | — | 22 | — | 27 | ||||||||||||
| Total derivatives | $ | — | $ | 26 | $ | — | $ | 31 | ||||||||
The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets. assets:
| Derivative Instruments | Location of Gain (Loss) | 2021 | 2020 | 2019 | ||||||||||||||||||||||
| Interest rate swaps | Interest Expense | $ | (2) | $ | (5) | $ | (5) | |||||||||||||||||||
| Derivative Instruments | Location of Gain (Loss) | 2017 | 2016 | 2015 | Derivative Instruments | Location of Gain (Loss) | 2021 | 2020 | 2019 | |||||||||||||||||||||||||||||||
| Interest rate swaps | Interest Expense | $ | (6 | ) | $ | (7 | ) | $ | (8 | ) | Interest rate swaps | Regulatory assets - noncurrent | $ | 5 | $ | (2) | $ | (1) | ||||||||||||||||||||||
| Derivative Instruments | Location of Gain (Loss) | 2017 | 2016 | 2015 | ||||||||||
| Interest rate swaps | Regulatory assets - noncurrent | $ | 5 | $ | 7 | $ | 1 | |||||||
(PPL, LKE, LG&E and KU)
Offsetting Derivative Instruments
PPL, LKE, 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, LKE, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.
| Assets | Liabilities | |||||||||||||||||||||||||||||||
| Eligible for Offset | Eligible for Offset | |||||||||||||||||||||||||||||||
| Gross | Derivative Instruments | Cash Collateral Received | Net | Gross | Derivative Instruments | Cash Collateral Pledged | Net | |||||||||||||||||||||||||
| December 31, 2017 | ||||||||||||||||||||||||||||||||
| Treasury Derivatives | ||||||||||||||||||||||||||||||||
| PPL | $ | 264 | $ | 107 | $ | 20 | $ | 137 | $ | 174 | $ | 107 | $ | — | $ | 67 | ||||||||||||||||
| LKE | — | — | — | — | 26 | — | — | 26 | ||||||||||||||||||||||||
| LG&E | — | — | — | — | 26 | — | — | 26 | ||||||||||||||||||||||||
| Assets | Liabilities | |||||||||||||||||||||||||||||||||||||||||||||||||
| Eligible for Offset | Eligible for Offset | |||||||||||||||||||||||||||||||||||||||||||||||||
| Gross | Derivative Instruments | Cash Collateral Received | Net | Gross | Derivative Instruments | Cash Collateral Pledged | Net | |||||||||||||||||||||||||||||||||||||||||||
| December 31, 2021 | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Treasury Derivatives | ||||||||||||||||||||||||||||||||||||||||||||||||||
| PPL | $ | — | $ | — | $ | — | $ | — | $ | 18 | $ | — | $ | — | $ | 18 | ||||||||||||||||||||||||||||||||||
| LG&E | — | — | — | — | 18 | — | — | 18 | ||||||||||||||||||||||||||||||||||||||||||
| December 31, 2020 | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Treasury Derivatives | ||||||||||||||||||||||||||||||||||||||||||||||||||
| PPL | $ | 146 | $ | 34 | $ | — | $ | 112 | $ | 160 | $ | 34 | $ | — | $ | 126 | ||||||||||||||||||||||||||||||||||
| LG&E | — | — | — | — | 23 | — | — | 23 | ||||||||||||||||||||||||||||||||||||||||||
| Assets | Liabilities | |||||||||||||||||||||||||||||||
| Eligible for Offset | Eligible for Offset | |||||||||||||||||||||||||||||||
| Gross | Derivative Instruments | Cash Collateral Received | Net | Gross | Derivative Instruments | Cash Collateral Pledged | Net | |||||||||||||||||||||||||
| December 31, 2016 | ||||||||||||||||||||||||||||||||
| Treasury Derivatives | ||||||||||||||||||||||||||||||||
| PPL | $ | 399 | $ | 27 | $ | 19 | $ | 353 | $ | 58 | $ | 27 | $ | 3 | $ | 28 | ||||||||||||||||
| LKE | — | — | — | — | 31 | — | 3 | 28 | ||||||||||||||||||||||||
| LG&E | — | — | — | — | 31 | — | 3 | 28 | ||||||||||||||||||||||||
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, LKE, 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, LKE's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.
At December 31, 2017,2021, there were no derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the related effect of a decrease in credit ratings below investment grade are summarized as follows:grade.
| PPL | LKE | LG&E | ||||||||||
| Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features | $ | 51 | $ | 10 | $ | 10 | ||||||
| Aggregate fair value of collateral posted on these derivative instruments | — | — | — | |||||||||
| Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) | 51 | 10 | 10 | |||||||||
Goodwill
(PPL)
| U.K. Regulated | Kentucky Regulated | Total | |||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||
| Balance at beginning of period (a) | $ | 2,398 | $ | 2,888 | $ | 662 | $ | 662 | $ | 3,060 | $ | 3,550 | |||||||||||
| Effect of foreign currency exchange rates | 198 | (490 | ) | 198 | (490 | ) | |||||||||||||||||
| Balance at end of period (a) | $ | 2,596 | $ | 2,398 | $ | 662 | $ | 662 | $ | 3,258 | $ | 3,060 | |||||||||||
Other Intangible Assets
(PPL)
The gross carrying amount and the accumulated amortization of other intangible assets were:
174
| December 31, 2017 | December 31, 2016 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||||||||||
Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | |||||||||||||||||||||||||||||||
| Subject to amortization: | Subject to amortization: | |||||||||||||||||||||||||||||||||||||
| Contracts (a) | $ | 138 | $ | 67 | $ | 405 | $ | 325 | Contracts (a) | $ | 125 | $ | 90 | $ | 125 | $ | 82 | |||||||||||||||||||||
| Land and transmission rights | 382 | 120 | 362 | 115 | ||||||||||||||||||||||||||||||||||
| Emission allowances/RECs (b) | 1 | — | 2 | — | ||||||||||||||||||||||||||||||||||
| Land rights and easements | Land rights and easements | 406 | 135 | 401 | 133 | |||||||||||||||||||||||||||||||||
| Licenses and other | 7 | 3 | 6 | 2 | Licenses and other | 20 | 6 | 21 | 4 | |||||||||||||||||||||||||||||
| Total subject to amortization | 528 | 190 | 775 | 442 | Total subject to amortization | 551 | 231 | 547 | 219 | |||||||||||||||||||||||||||||
| Not subject to amortization due to indefinite life: | Not subject to amortization due to indefinite life: | |||||||||||||||||||||||||||||||||||||
| Land and transmission rights | 12 | — | 19 | — | ||||||||||||||||||||||||||||||||||
| Easements | 347 | — | 348 | — | ||||||||||||||||||||||||||||||||||
| Land rights and easements | Land rights and easements | 17 | — | 17 | — | |||||||||||||||||||||||||||||||||
| Other | Other | 6 | — | 6 | — | |||||||||||||||||||||||||||||||||
| Total not subject to amortization due to indefinite life | 359 | — | 367 | — | Total not subject to amortization due to indefinite life | 23 | — | 23 | — | |||||||||||||||||||||||||||||
| Total | $ | 887 | $ | 190 | $ | 1,142 | $ | 442 | Total | $ | 574 | $ | 231 | $ | 570 | $ | 219 | |||||||||||||||||||||
(a)Gross carrying amount in 2021 and 2020 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL.
Current intangible assets are included in "Other current assets" and long-term intangible assets are included in "Other intangibles" on the Balance Sheets.
| Amortization expense was as follows: | |||||||||||||||||
| 2021 | 2020 | 2019 | |||||||||||||||
| Intangible assets with no regulatory offset | $ | 9 | $ | 7 | $ | 6 | |||||||||||
| Intangible assets with regulatory offset | 8 | 8 | 9 | ||||||||||||||
| Total | $ | 17 | $ | 15 | $ | 15 | |||||||||||
| Amortization Expense was as follows: | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Intangible assets with no regulatory offset | $ | 6 | $ | 6 | $ | 6 | |||||
| Intangible assets with regulatory offset | 9 | 24 | 51 | ||||||||
| Total | $ | 15 | $ | 30 | $ | 57 | |||||
Amortization expense for each of the next five years excluding insignificant amounts for consumption of emission allowances/RECs, is estimated to be:
| 2022 | 2023 | 2024 | 2025 | 2026 | |||||||||||||||||||||||||
| Intangible assets with no regulatory offset | $ | 5 | $ | 5 | $ | 5 | $ | 5 | $ | 5 | |||||||||||||||||||
| Intangible assets with regulatory offset | 8 | 8 | 9 | 9 | 2 | ||||||||||||||||||||||||
| Total | $ | 13 | $ | 13 | $ | 14 | $ | 14 | $ | 7 | |||||||||||||||||||
| 2018 | 2019 | 2020 | 2021 | 2022 | |||||||||||||||
| Intangible assets with no regulatory offset | $ | 6 | $ | 6 | $ | 6 | $ | 6 | $ | 6 | |||||||||
| Intangible assets with regulatory offset | 9 | 9 | 8 | 8 | 8 | ||||||||||||||
| Total | $ | 15 | $ | 15 | $ | 14 | $ | 14 | $ | 14 | |||||||||
(PPL Electric)
The gross carrying amount and the accumulated amortization of other intangible assets were:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||
| Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||||||||||
| Subject to amortization: | |||||||||||||||||||||||
| Land rights and easements | $ | 382 | $ | 130 | $ | 379 | $ | 129 | |||||||||||||||
| Licenses and other | 2 | 1 | 2 | 1 | |||||||||||||||||||
| Total subject to amortization | 384 | 131 | 381 | 130 | |||||||||||||||||||
| Not subject to amortization due to indefinite life: | |||||||||||||||||||||||
| Land rights and easements | 17 | — | 17 | — | |||||||||||||||||||
| Total | $ | 401 | $ | 131 | $ | 398 | $ | 130 | |||||||||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||
Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||
| Subject to amortization: | |||||||||||||||
| Land and transmission rights | $ | 361 | $ | 117 | $ | 341 | $ | 112 | |||||||
| Licenses and other | 3 | 1 | 3 | 1 | |||||||||||
| Total subject to amortization | 364 | 118 | 344 | 113 | |||||||||||
| Not subject to amortization due to indefinite life: | |||||||||||||||
| Land and transmission rights | 13 | — | 20 | — | |||||||||||
| Total | $ | 377 | $ | 118 | $ | 364 | $ | 113 | |||||||
Intangible assets are shown as "Intangibles" on the Balance Sheets.
Amortization expense was insignificant in 2017, 2016 and 2015 andas follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Intangible assets with no regulatory offset | $ | 4 | $ | 4 | $ | 4 | |||||||||||
175
Amortization expense for each of the next five years is expectedestimated to be insignificant in future years.be:
| 2022 | 2023 | 2024 | 2025 | 2026 | |||||||||||||||||||||||||
| Intangible assets with no regulatory offset | $ | 4 | $ | 4 | $ | 4 | $ | 4 | $ | 4 | |||||||||||||||||||
(LG&E)
The gross carrying amount and the accumulated amortization of other intangible assets were:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||
| Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||||||||||
| Subject to amortization: | |||||||||||||||||||||||
| Land rights and easements | $ | 7 | $ | 1 | $ | 7 | $ | 1 | |||||||||||||||
| OVEC power purchase agreement (a) | 86 | 62 | 86 | 57 | |||||||||||||||||||
| Total subject to amortization | $ | 93 | $ | 63 | $ | 93 | $ | 58 | |||||||||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||
Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||
| Subject to amortization: | |||||||||||||||
| Coal contracts (a) | $ | — | $ | — | $ | 269 | $ | 269 | |||||||
| Land and transmission rights | 21 | 3 | 21 | 3 | |||||||||||
| OVEC power purchase agreement (b) | 126 | 58 | 126 | 49 | |||||||||||
| Total subject to amortization | $ | 147 | $ | 61 | $ | 416 | $ | 321 | |||||||
(a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets.
Amortization expense was as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Intangible assets with regulatory offset | $ | 5 | $ | 6 | $ | 6 | |||||||||||
| 2017 | 2016 | 2015 | |||||||||
| Intangible assets with no regulatory offset | $ | — | $ | 1 | $ | — | |||||
| Intangible assets with regulatory offset | 9 | 24 | 51 | ||||||||
| Total | $ | 9 | $ | 25 | $ | 51 | |||||
Amortization expense for each of the next five years is estimated to be:
| 2022 | 2023 | 2024 | 2025 | 2026 | |||||||||||||||||||||||||
| Intangible assets with regulatory offset | $ | 6 | $ | 6 | $ | 6 | $ | 6 | $ | 1 | |||||||||||||||||||
(KU)
The gross carrying amount and the accumulated amortization of other intangible assets were:
| December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||
| Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||||||||||
| Subject to amortization: | |||||||||||||||||||||||
| Land rights and easements | $ | 16 | $ | 4 | $ | 15 | $ | 3 | |||||||||||||||
| OVEC power purchase agreement (a) | 39 | 28 | 39 | 25 | |||||||||||||||||||
| Total subject to amortization | $ | 55 | $ | 32 | $ | 54 | $ | 28 | |||||||||||||||
(a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets.
Amortization expense was as follows:
| 2021 | 2020 | 2019 | |||||||||||||||
| Intangible assets with no regulatory offset | $ | 1 | $ | — | $ | — | |||||||||||
| Intangible assets with regulatory offset | 3 | 2 | 3 | ||||||||||||||
Amortization expense for each of the next five years is estimated to be:
| 2018 | 2019 | 2020 | 2021 | 2022 | |||||||||||||||
| Intangible assets with regulatory offset | $ | 9 | $ | 9 | $ | 8 | $ | 8 | $ | 8 | |||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||
Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||
| Subject to amortization: | |||||||||||||||
| Coal contracts (a) | $ | — | $ | — | $ | 124 | $ | 124 | |||||||
| Land and transmission rights | 7 | 1 | 7 | 1 | |||||||||||
| OVEC power purchase agreement (b) | 87 | 40 | 87 | 34 | |||||||||||
| Total subject to amortization | $ | 94 | $ | 41 | $ | 218 | $ | 159 | |||||||
| 2017 | 2016 | 2015 | |||||||||
| Intangible assets with regulatory offset | $ | 6 | $ | 13 | $ | 24 | |||||
| 2018 | 2019 | 2020 | 2021 | 2022 | |||||||||||||||
| Intangible assets with regulatory offset | $ | 6 | $ | 6 | $ | 6 | $ | 6 | $ | 6 | |||||||||
| December 31, 2017 | December 31, 2016 | ||||||||||||||
Gross Carrying Amount | Accumulated Amortization | Gross Carrying Amount | Accumulated Amortization | ||||||||||||
| Subject to amortization: | |||||||||||||||
| Coal contracts (a) | $ | — | $ | — | $ | 145 | $ | 145 | |||||||
| Land and transmission rights | 14 | 2 | 14 | 2 | |||||||||||
| OVEC power purchase agreement (b) | 39 | 18 | 39 | 15 | |||||||||||
| Total subject to amortization | $ | 53 | $ | 20 | $ | 198 | $ | 162 | |||||||
| 2017 | 2016 | 2015 | |||||||||
| Intangible assets with no regulatory offset | $ | — | $ | 1 | $ | — | |||||
| Intangible assets with regulatory offset | 3 | 11 | 27 | ||||||||
| Total | $ | 3 | $ | 12 | $ | 27 | |||||
| 2018 | 2019 | 2020 | 2021 | 2022 | |||||||||||||||
| Intangible assets with regulatory offset | $ | 3 | $ | 3 | $ | 2 | $ | 2 | $ | 2 | |||||||||
| 2022 | 2023 | 2024 | 2025 | 2026 | |||||||||||||||||||||||||
| Intangible assets with regulatory offset | $ | 2 | $ | 2 | $ | 3 | $ | 3 | $ | 1 | |||||||||||||||||||
(PPL and PPL Electric)
PPL Electric has identified legal retirement obligations for the retirement of certain transmission assets that could not be reasonably estimated due to indeterminable settlement dates. These assets are located on rights-of-way that allow the grantor to require PPL Electric to relocate or remove the assets. Since this option is at the discretion of the grantor of the right-of-way, PPL Electric is unable to determine when these events may occur.
(PPL, LKE, LG&E and KU)
PPL's, LG&E's and KU's AROsARO liabilities are primarily related to CCR closure costs. See Note 14 for information on the final retirement of assets associated with generating units.CCR rule. LG&E also has 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. As described in Notes 1 and 6, for LKE,For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset.asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory assetdeferred accretion and depreciation expense is offset against the associatedrecovered through cost of removal regulatory liability, PP&E and ARO liability.removal.
The changes in the carrying amounts of AROs were as follows:
| PPL | LKE | LG&E | KU | ||||||||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||||||||
| ARO at beginning of period | $ | 488 | $ | 586 | $ | 433 | $ | 535 | $ | 145 | $ | 175 | $ | 288 | $ | 360 | |||||||||||||||
| Accretion | 21 | 24 | 20 | 22 | 7 | 7 | 13 | 15 | |||||||||||||||||||||||
| Changes in estimated timing or cost (a) | (73 | ) | (84 | ) | (54 | ) | (95 | ) | (8 | ) | (19 | ) | (46 | ) | (76 | ) | |||||||||||||||
| Effect of foreign currency exchange rates | 4 | (9 | ) | — | — | — | — | — | — | ||||||||||||||||||||||
| Obligations settled | (43 | ) | (29 | ) | (43 | ) | (29 | ) | (23 | ) | (18 | ) | (20 | ) | (11 | ) | |||||||||||||||
| ARO at end of period | $ | 397 | $ | 488 | $ | 356 | $ | 433 | $ | 121 | $ | 145 | $ | 235 | $ | 288 | |||||||||||||||
| PPL | LG&E | KU | |||||||||||||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||||||||||||
| ARO at beginning of period | $ | 182 | $ | 215 | $ | 67 | $ | 73 | $ | 115 | $ | 142 | |||||||||||||||||||||||
| Accretion | 16 | 15 | 5 | 5 | 11 | 10 | |||||||||||||||||||||||||||||
| Changes in estimated timing or cost | 56 | 40 | 40 | 13 | 16 | 27 | |||||||||||||||||||||||||||||
| Obligations settled | (65) | (88) | (28) | (24) | (37) | (64) | |||||||||||||||||||||||||||||
| ARO at end of period | $ | 189 | $ | 182 | $ | 84 | $ | 67 | $ | 105 | $ | 115 | |||||||||||||||||||||||
The after-tax changes in AOCI by component for the years ended December 31 were as follows:
| Defined benefit plans | |||||||||||||||||||||||||||||||||||||||||
| Foreign currency translation adjustments | Unrealized gains (losses) on qualifying derivatives | Prior service costs | Actuarial gain (loss) | Total | |||||||||||||||||||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||||||||||||||||
| December 31, 2018 | $ | (1,533) | $ | (7) | $ | (19) | $ | (2,405) | $ | (3,964) | |||||||||||||||||||||||||||||||
| Amounts arising during the year | 108 | (11) | (1) | (592) | (496) | ||||||||||||||||||||||||||||||||||||
| Reclassifications from AOCI | — | 13 | 2 | 87 | 102 | ||||||||||||||||||||||||||||||||||||
| Net OCI during the year | 108 | 2 | 1 | (505) | (394) | ||||||||||||||||||||||||||||||||||||
| December 31, 2019 | $ | (1,425) | $ | (5) | $ | (18) | $ | (2,910) | $ | (4,358) | |||||||||||||||||||||||||||||||
| Amounts arising during the year | 267 | (19) | (1) | (341) | (94) | ||||||||||||||||||||||||||||||||||||
| Reclassifications from AOCI | — | 24 | 3 | 205 | 232 | ||||||||||||||||||||||||||||||||||||
| Net OCI during the year | 267 | 5 | 2 | (136) | 138 | ||||||||||||||||||||||||||||||||||||
| December 31, 2020 | $ | (1,158) | $ | — | $ | (16) | $ | (3,046) | $ | (4,220) | |||||||||||||||||||||||||||||||
| Defined benefit plans | |||||||||||||||||||||||||||||||||||||||||
| Foreign currency translation adjustments | Unrealized gains (losses) on qualifying derivatives | Prior service costs | Actuarial gain (loss) | Total | |||||||||||||||||||||||||||||||||||||
| Amounts arising during the year | 372 | (39) | — | (1) | 332 | ||||||||||||||||||||||||||||||||||||
| Reclassifications from AOCI | — | 25 | 2 | 126 | 153 | ||||||||||||||||||||||||||||||||||||
| Reclassifications from AOCI due to the sale of the U.K. utility business (Note 9) | 786 | 15 | 8 | 2,769 | 3,578 | ||||||||||||||||||||||||||||||||||||
| Net OCI during the year | 1,158 | 1 | 10 | 2,894 | 4,063 | ||||||||||||||||||||||||||||||||||||
| December 31, 2021 | $ | — | $ | 1 | $ | (6) | $ | (152) | $ | (157) | |||||||||||||||||||||||||||||||
| Unrealized gains (losses) | Defined benefit plans | ||||||||||||||||||||||||||
Foreign currency translation adjustments | Available- for-sale securities | Qualifying derivatives | Equity investees' AOCI | Prior service costs | Actuarial gain (loss) | Total | |||||||||||||||||||||
| PPL | |||||||||||||||||||||||||||
| December 31, 2014 | $ | (286 | ) | $ | 201 | $ | 20 | $ | 1 | $ | 3 | $ | (2,213 | ) | $ | (2,274 | ) | ||||||||||
| Amounts arising during the year | (234 | ) | 8 | 26 | — | (9 | ) | (366 | ) | (575 | ) | ||||||||||||||||
| Reclassifications from AOCI | — | (2 | ) | 2 | (1 | ) | — | 146 | 145 | ||||||||||||||||||
| Net OCI during the year | (234 | ) | 6 | 28 | (1 | ) | (9 | ) | (220 | ) | (430 | ) | |||||||||||||||
| Distribution of PPL Energy Supply (See Note 8) | — | (207 | ) | (55 | ) | — | — | 238 | (24 | ) | |||||||||||||||||
| December 31, 2015 | $ | (520 | ) | $ | — | $ | (7 | ) | $ | — | $ | (6 | ) | $ | (2,195 | ) | $ | (2,728 | ) | ||||||||
| Amounts arising during the year | (1,107 | ) | — | 91 | — | (3 | ) | (61 | ) | (1,080 | ) | ||||||||||||||||
| Reclassifications from AOCI | — | — | (91 | ) | (1 | ) | 1 | 121 | 30 | ||||||||||||||||||
| Net OCI during the year | (1,107 | ) | — | — | (1 | ) | (2 | ) | 60 | (1,050 | ) | ||||||||||||||||
| December 31, 2016 | $ | (1,627 | ) | $ | — | $ | (7 | ) | $ | (1 | ) | $ | (8 | ) | $ | (2,135 | ) | $ | (3,778 | ) | |||||||
| Amounts arising during the year | 538 | — | (79 | ) | — | — | (308 | ) | 151 | ||||||||||||||||||
| Reclassifications from AOCI | — | — | 73 | 1 | 1 | 130 | 205 | ||||||||||||||||||||
| Net OCI during the year | 538 | — | (6 | ) | 1 | 1 | (178 | ) | 356 | ||||||||||||||||||
| December 31, 2017 | $ | (1,089 | ) | $ | — | $ | (13 | ) | $ | — | $ | (7 | ) | $ | (2,313 | ) | $ | (3,422 | ) | ||||||||
| LKE | |||||||||||||||||||||||||||
| December 31, 2014 | $ | — | $ | (8 | ) | $ | (37 | ) | $ | (45 | ) | ||||||||||||||||
| Amounts arising during the year | — | (3 | ) | (4 | ) | (7 | ) | ||||||||||||||||||||
| Reclassifications from AOCI | — | 1 | 5 | 6 | |||||||||||||||||||||||
| Net OCI during the year | — | (2 | ) | 1 | (1 | ) | |||||||||||||||||||||
| December 31, 2015 | $ | — | $ | (10 | ) | $ | (36 | ) | $ | (46 | ) | ||||||||||||||||
| Amounts arising during the year | — | — | (27 | ) | (27 | ) | |||||||||||||||||||||
| Reclassifications from AOCI | (1 | ) | 2 | 2 | 3 | ||||||||||||||||||||||
| Net OCI during the year | (1 | ) | 2 | (25 | ) | (24 | ) | ||||||||||||||||||||
| December 31, 2016 | $ | (1 | ) | $ | (8 | ) | $ | (61 | ) | $ | (70 | ) | |||||||||||||||
| Amounts arising during the year | — | (2 | ) | (23 | ) | (25 | ) | ||||||||||||||||||||
| Reclassifications from AOCI | 1 | 1 | 5 | 7 | |||||||||||||||||||||||
| Net OCI during the year | 1 | (1 | ) | (18 | ) | (18 | ) | ||||||||||||||||||||
| December 31, 2017 | $ | — | $ | (9 | ) | $ | (79 | ) | $ | (88 | ) | ||||||||||||||||
The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2017, 20162021, 2020 and 2015. LKE amounts are insignificant for the years ended December 31, 2017, 2016 and 2015.2019. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 1112 for additional information.
| PPL | ||||||||||||||||||||||||||
| Details about AOCI | 2021 | 2020 | 2019 | Affected Line Item on the Statements of Income | ||||||||||||||||||||||
| Qualifying derivatives | ||||||||||||||||||||||||||
| Interest rate swaps | $ | 11 | $ | (8) | $ | (9) | Interest Expense | |||||||||||||||||||
| (2) | (2) | — | Income (Loss) from Discontinued Operations (net of income taxes) | |||||||||||||||||||||||
| Cross-currency swaps | (39) | (22) | (9) | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||||||||||||||
| Total Pre-tax | (30) | (32) | (18) | |||||||||||||||||||||||
| Income Taxes | 5 | 8 | 5 | |||||||||||||||||||||||
| Total After-tax | (25) | (24) | (13) | |||||||||||||||||||||||
| Defined benefit plans | ||||||||||||||||||||||||||
| Prior service costs | (3) | (4) | (3) | |||||||||||||||||||||||
| Net actuarial loss | (159) | (256) | (109) | |||||||||||||||||||||||
| Total Pre-tax | (162) | (260) | (112) | |||||||||||||||||||||||
| Income Taxes | 34 | 52 | 23 | |||||||||||||||||||||||
| Total After-tax | (128) | (208) | (89) | |||||||||||||||||||||||
| Sale of the U.K. utility business (Note 9) | ||||||||||||||||||||||||||
| Foreign currency translation adjustments | (646) | — | — | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||||||||||||||
| Qualifying derivatives | (15) | — | — | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||||||||||||||
| Defined benefit plans | (3,577) | — | — | Income (Loss) from Discontinued Operations (net of income taxes) | ||||||||||||||||||||||
| Total Pre-tax | (4,238) | — | — | |||||||||||||||||||||||
| Income Taxes | 660 | — | — | |||||||||||||||||||||||
| Total After-tax | (3,578) | — | — | |||||||||||||||||||||||
| Total reclassifications during the year | $ | (3,731) | $ | (232) | $ | (102) | �� | |||||||||||||||||||
178
| PPL | ||||||||||||||
| Details about AOCI | 2017 | 2016 | 2015 | Affected Line Item on the Statements of Income | ||||||||||
| Available-for-sale securities | $ | — | $ | — | $ | 4 | Other Income (Expense) - net | |||||||
| Total Pre-tax | — | — | 4 | |||||||||||
| Income Taxes | — | — | (2 | ) | ||||||||||
| Total After-tax | — | — | 2 | |||||||||||
| PPL | ||||||||||||||
| Details about AOCI | 2017 | 2016 | 2015 | Affected Line Item on the Statements of Income | ||||||||||
| Qualifying derivatives | ||||||||||||||
| Interest rate swaps | (9 | ) | (7 | ) | (11 | ) | Interest Expense | |||||||
| — | — | (77 | ) | Discontinued operations | ||||||||||
| Cross-currency swaps | (82 | ) | 116 | 49 | Other Income (Expense) - net | |||||||||
| — | 3 | 2 | Interest Expense | |||||||||||
| Commodity contracts | — | — | 20 | Discontinued operations | ||||||||||
| Total Pre-tax | (91 | ) | 112 | (17 | ) | |||||||||
| Income Taxes | 18 | (21 | ) | 15 | ||||||||||
| Total After-tax | (73 | ) | 91 | (2 | ) | |||||||||
| Equity Investees' AOCI | (1 | ) | 1 | 1 | Other Income (Expense) - net | |||||||||
| Total Pre-tax | (1 | ) | 1 | 1 | ||||||||||
| Income Taxes | — | — | — | |||||||||||
| Total After-tax | (1 | ) | 1 | 1 | ||||||||||
| Defined benefit plans | ||||||||||||||
| Prior service costs | (2 | ) | (2 | ) | — | |||||||||
| Net actuarial loss | (167 | ) | (156 | ) | (192 | ) | ||||||||
| Total Pre-tax | (169 | ) | (158 | ) | (192 | ) | ||||||||
| Income Taxes | 38 | 36 | 46 | |||||||||||
| Total After-tax | (131 | ) | (122 | ) | (146 | ) | ||||||||
| Total reclassifications during the year | $ | (205 | ) | $ | (30 | ) | $ | (145 | ) | |||||
| 2017 | 2016 | 2015 | |||||||||
| Operating Revenues | $ | — | $ | — | $ | — | |||||
| Operating Expenses | |||||||||||
| Other operation and maintenance | 2 | 2 | 9 | ||||||||
| Total Operating Expenses | 2 | 2 | 9 | ||||||||
| Operating Loss | (2 | ) | (2 | ) | (9 | ) | |||||
| Other Income (Expense) - net | |||||||||||
| Equity in earnings of subsidiaries | 1,175 | 1,915 | 711 | ||||||||
| Other income (expense) | (1 | ) | (1 | ) | (15 | ) | |||||
| Total | 1,174 | 1,914 | 696 | ||||||||
| Interest Expense | 8 | 8 | 9 | ||||||||
| Interest Expense with Affiliates | 16 | 10 | 10 | ||||||||
| Income Before Income Taxes | 1,148 | 1,894 | 668 | ||||||||
| Income Taxes | 20 | (8 | ) | (14 | ) | ||||||
| Net Income | $ | 1,128 | $ | 1,902 | $ | 682 | |||||
| Total other comprehensive income (loss) | 356 | (1,050 | ) | (430 | ) | ||||||
| Comprehensive Income Attributable to PPL Shareowners | $ | 1,484 | $ | 852 | $ | 252 | |||||
| Earnings Per Share of Common Stock: | |||||||||||
| Net Income Available to PPL Common Shareowners: | |||||||||||
| Basic | $ | 1.64 | $ | 2.80 | $ | 1.01 | |||||
| Diluted | $ | 1.64 | $ | 2.79 | $ | 1.01 | |||||
| Weighted-Average Shares of Common Stock Outstanding (in thousands) | |||||||||||
| Basic | 685,240 | 677,592 | 669,814 | ||||||||
| Diluted | 687,334 | 680,446 | 672,586 | ||||||||
| 2017 | 2016 | 2015 | |||||||||
| Cash Flows from Operating Activities | |||||||||||
| Net cash provided by (used in) operating activities | $ | 1,108 | $ | 1,563 | $ | 993 | |||||
| Cash Flows from Investing Activities | |||||||||||
| Capital contributions to affiliated subsidiaries | (585 | ) | (308 | ) | (491 | ) | |||||
| Return of capital from affiliated subsidiaries | — | — | 112 | ||||||||
| Net cash provided by (used in) investing activities | (585 | ) | (308 | ) | (379 | ) | |||||
| Cash Flows from Financing Activities | |||||||||||
| Issuance of equity, net of issuance costs | 453 | 144 | 203 | ||||||||
| Net increase (decrease) in short-term debt with affiliates | 113 | (341 | ) | 215 | |||||||
| Payment of common stock dividends | (1,072 | ) | (1,030 | ) | (1,004 | ) | |||||
| Other | (21 | ) | (24 | ) | (28 | ) | |||||
| Net cash provided by (used in) financing activities | (527 | ) | (1,251 | ) | (614 | ) | |||||
| Net Increase (Decrease) in Cash and Cash Equivalents | |||||||||||
| Cash and Cash Equivalents at Beginning of Period | 4 | — | — | ||||||||
| Cash and Cash Equivalents at End of Period | $ | — | $ | 4 | $ | — | |||||
| Supplemental Disclosures of Cash Flow Information: | |||||||||||
| Cash Dividends Received from Subsidiaries | $ | 1,253 | $ | 1,510 | $ | 1,198 | |||||
| 2017 | 2016 | ||||||
| Assets | |||||||
| Current Assets | |||||||
| Cash and cash equivalents | $ | — | $ | 4 | |||
| Accounts Receivable | |||||||
| Other | 7 | 7 | |||||
| Affiliates | 17 | 10 | |||||
| Price risk management assets | 196 | 63 | |||||
| Total Current Assets | 220 | 84 | |||||
| Investments | |||||||
| Affiliated companies at equity | 11,141 | 10,160 | |||||
| Other Noncurrent Assets | |||||||
| Deferred income taxes | 46 | 70 | |||||
| Price risk management assets | 186 | 284 | |||||
| Other noncurrent assets | 1 | 1 | |||||
| Total Other Noncurrent Assets | 233 | 355 | |||||
| Total Assets | $ | 11,594 | $ | 10,599 | |||
| Liabilities and Equity | |||||||
| Current Liabilities | |||||||
| Short-term debt with affiliates | $ | 157 | $ | 44 | |||
| Accounts payable with affiliates | 2 | 30 | |||||
| Dividends | 273 | 259 | |||||
| Price risk management liabilities | 233 | 237 | |||||
| Other current liabilities | 19 | 20 | |||||
| Total Current Liabilities | 684 | 590 | |||||
| Deferred Credits and Other Noncurrent Liabilities | 149 | 110 | |||||
| Equity | |||||||
| Common stock - $0.01 par value (a) | 7 | 7 | |||||
| Additional paid-in capital | 10,305 | 9,841 | |||||
| Earnings reinvested | 3,871 | 3,829 | |||||
| Accumulated other comprehensive loss | (3,422 | ) | (3,778 | ) | |||
| Total Equity | 10,761 | 9,899 | |||||
| Total Liabilities and Equity | $ | 11,594 | $ | 10,599 | |||
| 2017 | 2016 | 2015 | |||||||||
| Other Income (Expense) - net | |||||||||||
| Equity in Earnings of Subsidiaries | $ | 397 | $ | 452 | $ | 390 | |||||
| Interest Income with Affiliate | 14 | 9 | 4 | ||||||||
| Total | 411 | 461 | 394 | ||||||||
| Interest Expense | 30 | 29 | 39 | ||||||||
| Interest Expense with Affiliate | 20 | 18 | 5 | ||||||||
| Income Before Income Taxes | 361 | 414 | 350 | ||||||||
| Income Tax Expense (Benefit) | 45 | (15 | ) | (14 | ) | ||||||
| Net Income | $ | 316 | $ | 429 | $ | 364 | |||||
| Total other comprehensive loss | (18 | ) | (24 | ) | (1 | ) | |||||
| Comprehensive Income Attributable to Member | $ | 298 | $ | 405 | $ | 363 | |||||
| 2017 | 2016 | 2015 | |||||||||
| Cash Flows from Operating Activities | |||||||||||
| Net cash provided by (used in) operating activities | $ | 401 | $ | 285 | $ | 246 | |||||
| Cash Flows from Investing Activities | |||||||||||
| Capital contributions to affiliated subsidiaries | (30 | ) | (91 | ) | (140 | ) | |||||
| Net decrease (increase) in notes receivable from affiliates | (28 | ) | 47 | 73 | |||||||
| Net cash provided by (used in) investing activities | (58 | ) | (44 | ) | (67 | ) | |||||
| Cash Flows from Financing Activities | |||||||||||
| Net increase (decrease) in notes payable with affiliates | 58 | 90 | 315 | ||||||||
| Net increase (decrease) in short-term debt | — | (75 | ) | — | |||||||
| Retirement of long-term debt | — | — | (400 | ) | |||||||
| Contribution from member | — | 61 | 125 | ||||||||
| Distribution to member | (402 | ) | (316 | ) | (219 | ) | |||||
| Net cash provided by (used in) financing activities | (344 | ) | (240 | ) | (179 | ) | |||||
| Net Increase (Decrease) in Cash and Cash Equivalents | (1 | ) | 1 | — | |||||||
| Cash and Cash Equivalents at Beginning of Period | 1 | — | — | ||||||||
| Cash and Cash Equivalents at End of Period | $ | — | $ | 1 | $ | — | |||||
| Supplemental disclosures of cash flow information: | |||||||||||
| Cash Dividends Received from Subsidiaries | $ | 418 | $ | 376 | $ | 272 | |||||
| 2017 | 2016 | ||||||
| Assets | |||||||
| Current Assets | |||||||
| Cash and cash equivalents | $ | — | $ | 1 | |||
| Accounts receivable | 1 | — | |||||
| Accounts receivable from affiliates | 8 | 23 | |||||
| Income taxes receivable | 1 | 31 | |||||
| Notes receivable from affiliates | 1,035 | 1,007 | |||||
| Total Current Assets | 1,045 | 1,062 | |||||
| Investments | |||||||
| Affiliated companies at equity | 5,209 | 5,219 | |||||
| Other Noncurrent Assets | |||||||
| Deferred income taxes | 263 | 227 | |||||
| Total Assets | $ | 6,517 | $ | 6,508 | |||
| Liabilities and Equity | |||||||
| Current Liabilities | |||||||
| Notes payable to affiliates | $ | 241 | $ | 179 | |||
| Accounts payable to affiliates | 469 | 450 | |||||
| Taxes | 35 | — | |||||
| Other current liabilities | 5 | 6 | |||||
| Total Current Liabilities | 750 | 635 | |||||
| Long-term Debt | |||||||
| Long-term debt | 722 | 721 | |||||
| Notes payable to affiliates | 476 | 480 | |||||
| Total Long-term Debt | 1,198 | 1,201 | |||||
| Deferred Credits and Other Noncurrent Liabilities | 6 | 5 | |||||
| Equity | 4,563 | 4,667 | |||||
| Total Liabilities and Equity | $ | 6,517 | $ | 6,508 | |||
| For the Quarters Ended (a) | |||||||||||||||
| March 31 | June 30 | Sept. 30 | Dec. 31 | ||||||||||||
| 2017 | |||||||||||||||
| Operating revenues | $ | 1,951 | $ | 1,725 | $ | 1,845 | $ | 1,926 | |||||||
| Operating income | 796 | 702 | 777 | 793 | |||||||||||
| Net income | 403 | 292 | 355 | 78 | |||||||||||
| Net income available to PPL common shareowners: (b) | |||||||||||||||
| Basic EPS | 0.59 | 0.43 | 0.52 | 0.11 | |||||||||||
| Diluted EPS | 0.59 | 0.43 | 0.51 | 0.11 | |||||||||||
| Dividends declared per share of common stock (c) | 0.3950 | 0.3950 | 0.3950 | 0.3950 | |||||||||||
| Price per common share: | |||||||||||||||
| High | $ | 37.70 | $ | 40.06 | $ | 39.83 | $ | 38.37 | |||||||
| Low | 33.94 | 37.11 | 37.36 | 30.76 | |||||||||||
| 2016 | |||||||||||||||
| Operating revenues | $ | 2,011 | $ | 1,785 | $ | 1,889 | $ | 1,832 | |||||||
| Operating income | 823 | 725 | 786 | 714 | |||||||||||
| Net income | 481 | 483 | 473 | 465 | |||||||||||
| Net income available to PPL common shareowners: (b) | |||||||||||||||
| Basic EPS | 0.71 | 0.71 | 0.70 | 0.68 | |||||||||||
| Diluted EPS | 0.71 | 0.71 | 0.69 | 0.68 | |||||||||||
| Dividends declared per share of common stock (c) | 0.38 | 0.38 | 0.38 | 0.38 | |||||||||||
| Price per common share: | |||||||||||||||
| High | $ | 38.07 | $ | 39.68 | $ | 37.71 | $ | 34.74 | |||||||
| Low | 32.80 | 36.27 | 33.63 | 32.19 | |||||||||||
| For the Quarters Ended (a) | |||||||||||||||
| March 31 | June 30 | Sept. 30 | Dec. 31 | ||||||||||||
| 2017 | |||||||||||||||
| Operating revenues | $ | 573 | $ | 500 | $ | 547 | $ | 575 | |||||||
| Operating income | 159 | 156 | 189 | 197 | |||||||||||
| Net income | 79 | 77 | 95 | 111 | |||||||||||
| 2016 | |||||||||||||||
| Operating revenues | $ | 585 | $ | 495 | $ | 539 | $ | 537 | |||||||
| Operating income | 180 | 154 | 176 | 154 | |||||||||||
| Net income | 94 | 79 | 90 | 77 | |||||||||||
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ON ACCOUNTING AND FINANCIAL DISCLOSURE
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
None.
ITEM 9A. CONTROLS AND PROCEDURES
(a)Evaluation of disclosure controls and procedures.
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
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 December 31, 2017,2021, 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 annual report has been prepared. The aforementioned 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 officers and principal financial officers, to allow for timely decisions regarding required disclosure.
(b)Changes in internal control over financial reporting.
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company, and Kentucky Utilities Company
The Registrants' principal executive officers and principal financial officers have concluded that there were no changes in the Registrants' internal control over financial reporting during the Registrants' fourth fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Registrants' internal control over financial reporting.
Management's Report on Internal Control over Financial Reporting
PPL Corporation
PPL's management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f) or 15d-15(f). PPL's internal control over financial reporting is a process designed to provide reasonable assurance to PPL's management and Board of Directors regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in "Internal Control - Integrated Framework" (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in "Internal Control - Integrated Framework" (2013), our management concluded that our internal control over financial reporting was effective December 31, 2017.2021. The effectiveness of our internal control over financial reporting has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report contained on page 95.64.
PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Management of PPL's non-accelerated filer companies, PPL Electric, LKE, LG&E and KU, are responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f) or 15d-15(f). Each of the aforementioned companies' internal control over financial reporting is a process
designed to provide reasonable assurance to management and Board of Directors of these companies regarding the reliability of financial
179
reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.
Under the supervision and with the participation of our management, including the principal executive officers and principal financial officers of the companies listed above, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in "Internal Control - Integrated Framework" (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in "Internal Control - Integrated Framework" (2013), management of these companies concluded that our internal control over financial reporting was effective as of December 31, 2017.2021. This annual report does not include an attestation report of Deloitte & Touche LLP, the companies' independent registered public accounting firm regarding internal control over financial reporting for these non-accelerated filer companies. The effectiveness of internal control over financial reporting for the aforementioned companies was not subject to attestation by the companies' registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit these companies to provide only management's report in this annual report.
ITEM 9B. OTHER INFORMATION
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
None.
ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
PPL Corporation, PPL Electric Utilities Corporation, Louisville Gas and Electric Company and Kentucky Utilities Company
Not applicable.
180
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
PPL Corporation
Additional information for this item will be set forth in the sections entitled "Nominees for Directors,"Directors" and "Board Committees - Board Committee Membership" and "Section 16(a) Beneficial Ownership Reporting Compliance" in PPL's 20182022 Notice of Annual Meeting and Proxy Statement, which will be filed with the SEC not later than 120 days after December 31, 2017,2021, and which information is incorporated herein by reference. There have been no changes to the procedures by which shareowners may recommend nominees to PPL's boardBoard of directorsDirectors since the filing with the SEC of PPL's 20172021 Notice of Annual Meeting and Proxy Statement.Statement except that on October 22, 2021, PPL's Board of Directors approved and adopted amendments to the Bylaws of the Company, which now require that, to be properly considered, nominations must be submitted to the Company during a window of 90 to 120 days before the first anniversary of the prior year's annual meeting (Article III, Section 3.16).
PPL has adopted a code of ethics entitled "Standards of Integrity" that applies to all directors, managers, trustees, officers (including the principal executive officers, principal financial officers and principal accounting officers (each, a "principal officer")), employees and agents of PPL and PPL's subsidiaries for which it has operating control (PPL Electric, LKE, LG&E and KU). The "Standards of Integrity" are posted on PPL's Internet website: www.pplweb.com/Standards-of-Integritygovernance. A description of any amendment to the "Standards of Integrity" (other than a technical, administrative or other non-substantive amendment) will be posted on PPL's Internet website within four business days following the date of the amendment. In addition, if a waiver constituting a material departure from a provision of the "Standards of Integrity" is granted to one of the principal officers, a description of the nature of the waiver, the name of the person to whom the waiver was granted and the date of the waiver will be posted on PPL's Internet website within four business days following the date of the waiver.
PPL also has adopted its "Guidelines for Corporate Governance," which address, among other things, director qualification standards and director and board committee responsibilities. These guidelines, and the charters of each of the committees of PPL's boardBoard of directors,Directors, are posted on PPL's Internet website: www.pplweb.com/Guidelines and www.pplweb.com/board-committeesgovernance.
PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Item 10 is omitted as PPL Electric, LKE, LG&E and KU meet the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K.
181
EXECUTIVE OFFICERS OF THE REGISTRANTS
Officers of the Registrants are elected annually by their Boards of Directors to serve at the pleasure of the respective Boards. There are no family relationships among any of the executive officers, nor is there any arrangement or understanding between any executive officer and any other person pursuant to which the officer was selected.
There have been no events under any bankruptcy act, no criminal proceedings and no judgments or injunctions material to the evaluation of the ability and integrity of any executive officer during the past five years.
Listed below are the executive officers at December 31, 2017.2021.
PPL Corporation
| Name | Age | Positions Held During the Past Five Years | Dates | |||||||||||||||||
| Vincent Sorgi | 50 | President and Chief Executive Officer | June 2020 - present | |||||||||||||||||
| President and Chief Operating Officer | July 2019 - May 2020 | |||||||||||||||||||
| Executive Vice President and Chief Financial Officer | January 2019 - June 2019 | |||||||||||||||||||
| Senior Vice President and Chief Financial Officer | June 2014 - January 2019 | |||||||||||||||||||
| Senior Vice President and Chief Financial Officer | ||||||||||||||||||||
| Vice Development & Planning | ||||||||||||||||||||
| Vice President-Investor Relations and Treasurer | January 2016 - December | |||||||||||||||||||
| Gregory N. Dudkin | 64 | Executive Vice | April 2021 - present | |||||||||||||||||
| President-PPL Electric | March 2012 - April 2021 | |||||||||||||||||||
| Angela K. Gosman (a) | 53 | Senior Vice President and Chief Human Resources Officer | January 2022 - present | |||||||||||||||||
| Vice President and Chief Human Resources Officer-PPL Services | August 2021 - December 2021 | |||||||||||||||||||
| Vice President - Human Resources-PPL EU Services | May 2020 - July 2021 | |||||||||||||||||||
| Director - Human Resources-LKE | September 2016 - May 2020 | |||||||||||||||||||
| Wendy E. Stark (b) | 49 | Senior Vice President, General Counsel and Corporate Secretary | April 2021 - present | |||||||||||||||||
| Stephanie R. Raymond (c) | 51 | President-PPL Electric | April 2021 - present | |||||||||||||||||
| Vice President-Distribution Operations | January 2018 - April 2021 | |||||||||||||||||||
| Vice President-Transmission and Substations | January 2014 - December 2017 | |||||||||||||||||||
| John R. Crockett III (c) | 57 | President-LKE | October 2021 - present | |||||||||||||||||
| General Counsel, Chief Compliance Officer and Corporate Secretary | January 2018 - September 2021 | |||||||||||||||||||
| Marlene C. Beers | 50 | Vice President and Controller | March 2019 - present | |||||||||||||||||
| Vice President-Finance and Regulatory Affairs and Controller-PPL Electric | August 2018 - February 2019 | |||||||||||||||||||
| Controller-PPL Electric | February 2016 - July 2018 | |||||||||||||||||||
| Tadd J. Henninger | 46 | Vice President-Finance and Treasurer | July 2019 - present | |||||||||||||||||
| Vice President and Treasurer | January 2018 - July 2019 | |||||||||||||||||||
| Assistant Treasurer | December 2015 - December | |||||||||||||||||||
(a)Angela K. Gosman was designated as an executive officer by the Compensation Committee of the Board of Directors of PPL Corporation in December 2021 to be effective in January 2022.
(b)Effective January 1, 2022, Wendy E. Stark was elected Senior Vice President, General Counsel, Corporate Secretary and Chief Legal Officer of PPL Corporation.
(c)Designated an executive officer of PPL by virtue of their respective positions at a PPL subsidiary.
ITEM 11. EXECUTIVE COMPENSATION
PPL Corporation
Information for this item will be set forth in the sections entitled "Compensation of Directors," "The Board's Role in Risk Oversight," "Compensation Committee Interlocks and Insider Participation"of Directors" and "Executive Compensation" in PPL's 20182022 Notice of Annual Meeting and Proxy Statement, which will be filed with the SEC not later than 120 days after December 31, 2017,2021, and which information is incorporated herein by reference.
PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Item 11 is omitted as PPL Electric, LKE, LG&E and KU meet the conditions set forth in General Instructions (I)(1)(a) and (b) of Form 10-K.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
AND RELATED STOCKHOLDER MATTERS
PPL Corporation
Information for this item will be set forth in the section entitled "Stock Ownership" in PPL's 20182022 Notice of Annual Meeting and Proxy Statement, which will be filed with the SEC not later than 120 days after December 31, 2017,2021, and which information is incorporated herein by reference. In addition, provided below in tabular format is information as of December 31, 2017,2021, with respect to compensation plans (including individual compensation arrangements) under which equity securities of PPL are authorized for issuance.
Equity Compensation Plan Information
Number of securities to be issued upon exercise of outstanding options, warrants and rights (3) | Weighted-average exercise price of outstanding options, warrants and rights (3) | Number of securities remaining available for future issuance under equity compensation plans (4) | ||||||||||||||||||
| Equity compensation | ||||||||||||||||||||
| plans approved by | 29,624 | – ICP | $ | 25.41 | – ICP | 1,355,369 | – DDCP | |||||||||||||
security holders (1) | 55,153 | – SIP | $ | 26.59 | – SIP | 9,691,708 | – SIP | |||||||||||||
| 681,225 | – ICPKE | $ | 26.62 | – ICPKE | 626,110 | – ICPKE | ||||||||||||||
| 766,002 | – Total | $ | 26.57 | – Combined | 11,673,187 | – Total | ||||||||||||||
| Equity compensation | ||||||||||||||||||||
| plans not approved by | ||||||||||||||||||||
security holders (2) | ||||||||||||||||||||
(1)Includes (a) the ICP, under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards were awarded to executive officers of PPL and no awards remain for issuance under this plan; (b) the ICPKE, under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards may be awarded to non-executive key employees of PPL and its subsidiaries; (c) the SIP approved by shareowners in 2017 under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards may be awarded to executive officers of PPL and its subsidiaries; and (d) the DDCP, under which stock units may be awarded to directors of PPL. See Note 11 to the Financial Statements for additional information.
(2)All of PPL's current compensation plans under which equity securities of PPL are authorized for issuance have been approved by PPL's shareowners.
(3)Relates to common stock issuable upon the exercise of stock options awarded under the ICP, SIP and ICPKE as of December 31, 2021. In addition, as of December 31, 2021, the following other securities had been awarded and are outstanding under the ICP, SIP, ICPKE and DDCP: 161,988 restricted stock units, 425,309 TSR performance awards and
Number of securities to be issued upon exercise of outstanding options, warrants and rights (3) | Weighted-average exercise price of outstanding options, warrants and rights (3) | Number of securities remaining available for future issuance under equity compensation plans (4) | ||||||||
| Equity compensation | ||||||||||
| plans approved by | 495,422 | – ICP | $ | 39.88 | – ICP | 1,720,050 | – DDCP | |||
security holders (1) | 1,329,058 | – SIP | $ | 26.21 | – SIP | 10,506,026 | – SIP | |||
| 1,937,703 | – ICPKE | $ | 28.95 | – ICPKE | 1,598,811 | – ICPKE | ||||
| 3,762,183 | – Total | $ | 29.42 | – Combined | 13,824,887 | – Total | ||||
| Equity compensation | ||||||||||
| plans not approved by | ||||||||||
security holders (2) | ||||||||||
508,860 ROE performance awards under the SIP; 842,595 restricted stock units 208,464 TSR performance awards and 213,493 ROE performance awards under the ICPKE; and 685,170 stock units under the DDCP.
(4)Based upon the following aggregate award limitations under the ICP, SIP, ICPKE and DDCP: (a) under the ICP, 15,769,431 awards (i.e., 5% of the total PPL common stock outstanding as of April 23, 1999) granted after April 23, 1999; (b) under the SIP, 15,000,000 awards; (c) under the ICPKE, 16,573,608 awards (i.e., 5% of the total PPL common stock outstanding as of January 1, 2003) granted after April 25, 2003, reduced by outstanding awards for which common stock was not yet issued as of such date of 2,373,812 resulting in a limit of 14,199,796; and (d) under the DDCP, the number of stock units available for issuance was reduced to 2,000,000 stock units in March 2012. In addition, each of the ICP and ICPKE includes an annual award limitation of 2% of total PPL common stock outstanding as of January 1 of each year.
PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Item 12 is omitted as PPL Electric, LKE, LG&E and KU meet the conditions set forth in General Instructions (I)(1)(a) and (b) of Form 10-K.
184
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
PPL Corporation
Information for this item will be set forth in the sections entitled "Board of Directors - Independence of Directors" and "Transactions with Related Persons" and "Independence of Directors" in PPL's 20182022 Notice of Annual Meeting and Proxy Statement, which will be filed with the SEC not later than 120 days after December 31, 2017,2021 and is incorporated herein by reference.
PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Item 13 is omitted as PPL Electric, LKE, LG&E and KU meet the conditions set forth in General Instructions (I)(1)(a) and (b) of Form 10-K.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
PPL Corporation
Information for this item will be set forth in the section entitled "Fees to Independent Auditor for 20172021 and 2016"2020" in PPL's 20182022 Notice of Annual Meeting and Proxy Statement, which will be filed with the SEC not later than 120 days after December 31, 2017,2021, and which information is incorporated herein by reference.
PPL Electric Utilities Corporation
For the fiscal yearyears ended 20172021 and 2016,2020, Deloitte & Touche LLP (Deloitte) served as PPL Electric's independent auditor. The following table presents an allocation of fees billed, including expenses, by the independent auditor to PPL Electric, for professional services rendered for the auditaudits of PPL Electric's annual financial statements and for fees billed for other services rendered by Deloitte.
| 2021 | 2020 | ||||||||||
(in thousands) | |||||||||||
| Audit fees (a) | $ | 1,345 | $ | 1,737 | |||||||
| Audit-related fees (b) | 17 | 16 | |||||||||
| 2017 | 2016 | ||||||
(in thousands) | |||||||
| Audit fees (a) | $ | 1,086 | $ | 1,104 | |||
| Audit-related fees (b) | 28 | — | |||||
| All other fees (c) | 253 | — | |||||
| (a)Includes estimated fees for audit of |
(b)Fees for agreed-upon procedures related to annual EPA filings.
| 2017 | 2016 | ||||||
(in thousands) | |||||||
| Audit fees (a) | $ | 1,717 | $ | 1,767 | |||
Louisville Gas and Electric Company
For the fiscal years ended 20172021 and 2016,2020, Deloitte served as LG&E's independent auditor. The following table presents an allocation of fees billed, including expenses, by the independent auditor to LG&E, for professional services rendered for the audits of LG&E's annual financial statements and for fees billed for other services rendered by Deloitte.
| 2021 | 2020 | ||||||||||
(in thousands) | |||||||||||
| Audit fees (a) | $ | 952 | $ | 832 | |||||||
| Other | — | 5 | |||||||||
| 2017 | 2016 | ||||||
(in thousands) | |||||||
| Audit fees (a) | $ | 826 | $ | 814 | |||
(a)Includes estimated fees for audit of annual financial statements and review of financial statements included in LG&E's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.
Kentucky Utilities Company
For the fiscal years ended 20172021 and 2016,2020, Deloitte served as KU's independent auditor. The following table presents an allocation of fees billed, including expenses, by the independent auditor to KU, for professional services rendered for the audits of KU's annual financial statements and for fees billed for other services rendered by Deloitte.
185
| 2017 | 2016 | |||||||
(in thousands) | ||||||||
| Audit fees (a) | $ | 874 | $ | 936 | ||||
| 2021 | 2020 | |||||||||||||
(in thousands) | ||||||||||||||
| Audit fees (a) | $ | 928 | $ | 955 | ||||||||||
| Other | — | 6 | ||||||||||||
(a)Includes estimated fees for audit of annual financial statements and review of financial statements included in KU's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
Approval of Fees. The Audit Committee of PPL has procedures for pre-approving audit and non-audit services to be provided by the independent auditor. These procedures are designed to ensure the continued independence of the independent auditor. More specifically, the use of the independent auditor to perform either audit or non-audit services is prohibited unless specifically approved in advance by the Audit Committee of PPL. As a result of this approval process, the Audit Committee of PPL has pre-approved specific categories of services and authorization levels. All services outside of the specified categories and all amounts exceeding the authorization levels are approved by the Chair of the Audit Committee of PPL, who serves as the Committee designee to review and approve audit and non-audit related services during the year. A listing of the approved audit and non-audit services is reviewed with the full Audit Committee of PPL no later than its next meeting.
The Audit Committee of PPL approved 100% of the 20172021 and 20162020 services provided by Deloitte.
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company
(a) The following documents are filed as part of this report:
1.Financial Statements - Refer to the "Table of Contents" for an index of the financial statements included in this report.
2.Supplementary Data and Supplemental Financial Statement Schedule I - PPL Corporation Condensed Unconsolidated Financial Statements.included in response to Item 8.
All other schedules are omitted because of the absence of the conditions under which they are required or because the required information is included in the financial statements or notes thereto.
3.Exhibits
See Exhibit Index immediately following the signature pages.
SHAREOWNER AND INVESTOR INFORMATION
Annual Meeting: The 20182022 annual meeting of shareowners of PPL will be held on Wednesday, May 16, 2018, at The PPL Center, 701 Hamilton Street, Allentown, Pennsylvania.18, 2022 in a virtual meeting format.
Proxy Statement Material: A proxy statement and notice of PPL's annual meeting will be provided to all shareowners who are holders of record as of February 28, 2018.2022. The latest proxy statement can be accessed at www.pplweb.com/PPLCorpProxy.
PPL Annual Report: The report will be published in the beginning of April and will be provided to all shareowners who are holders of record as of February 28, 2018.2022. The latest annual report can be accessed at www.pplweb.com/PPLCorpProxy.
Dividends: Subject to the declaration of dividends on PPL common stock by the PPL Board of Directors or its Executive Committee, dividends are paid on the first business day of April, July, October and January. The 20182022 record dates for dividends are expected to be March 9,10, June 8,10, September 109 and December 10.9.
PPL's Website(www.pplweb.com): Shareowners can access PPL publications such as annual and quarterly reports to the Securities and Exchange Commission (SEC Forms 10-K and 10-Q), other PPL filings, corporate governance materials, news releases, stock quotes and historical performance. Visitors to our website can subscribe to receive automated email alerts for SEC filings, earnings releases, daily stock prices or other financial news.
Financial reports which are available at www.pplweb.com will be mailed without charge upon request by writing to:request.
By mail:
PPL Treasury Dept.
Two North Ninth Street
Allentown, PA 18101
By email: invserv@pplweb.com
By telephone:
610-774-5151 or by calling:Toll-free at 1-800-345-3085
Online Account Access: Registered shareowners can activate their account for online access by visiting shareowneronline.com.
Direct Stock Purchase and Dividend Reinvestment Plans (Plan): PPL offers investors the opportunity to acquire shares of PPL common stock through its Plan. Through the Plan, participants are eligible to invest up to $25,000 per calendar month in PPL common stock. Shareowners may choose to have dividends on their PPL common stock fully or partially reinvested in PPL common stock or can receive full payment of cash dividends by check or electronic funds transfer. Participants in the Plan may choose to have their common stock certificates deposited into their Plan account.
Direct Registration System: PPL participates in the Direct Registration System (DRS). Shareowners may choose to have their common stock certificates converted to book entry form within the DRS by submitting their certificates to PPL's transfer agent.
Listed Securities:
New York Stock Exchange
PPL Corporation:
Common Stock (Code: PPL)
PPL Capital Funding, Inc.:
2007 Series A Junior Subordinated Notes due 2067 (Code: PPL/67)
Fiscal Agents:
Transfer Agent and Registrar; Dividend Disbursing Agent; Plan Administrator
Equiniti Trust Company
Shareowner Services
1110 Centre Pointe Curve, Suite 101
Mendota Heights, MN 55120
Toll Free: 1-800-345-3085
Outside U.S.: 651-450-4064
Website: shareowneronline.com
Indenture Trustee
The Bank of New York Mellon
Corporate Trust Administration
500 Ross Street
Pittsburgh, PA 15262
EXHIBIT INDEX
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)-32 are incorporated herein by reference. Exhibits indicated by a [_] are filed or listed pursuant to Item 601(b)(10)(iii) of Regulation S-K.
| - | Securities Purchase and Registration Rights Agreement, dated March 5, 2014, among PPL Capital Funding, Inc., PPL Corporation, and the several purchasers named in Schedule B thereto (Exhibit 1.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 10, 2014) | |||||||||||||
| - | ||||||||||||||
| - | ||||||||||||||
| Separation Agreement among PPL Corporation, Talen Energy Holdings, Inc., Talen Energy Corporation, PPL Energy Supply, LLC, Raven Power Holdings LLC, C/R Energy Jade, LLC and Sapphire Power Holdings LLC., dated as of June 9, 2014 (Exhibit 2.1 to PPL Energy Supply, LLC Form 8-K Report (File No. 1-32944) dated June 12, 2014) | ||||||||||||||
| - | Transaction Agreement among PPL Corporation, Talen Energy Holdings, Inc., Talen Energy Corporation, PPL Energy Supply, LLC, Talen Energy Merger Sub, Inc., C/R Energy Jade, LLC, Sapphire Power Holdings LLC. and Raven Power Holdings LLC, dated as of June 9, 2014 (Exhibit 2.2 to PPL Energy Supply, LLC Form 8-K Report (File No. 1-32944) dated June 12, 2014) | |||||||||||||
| - | Share Purchase Agreement, dated as of March 17, 2021, by and among PPL WPD Limited, National Grid Holdings One plc and National Grid plc. (Exhibit 2.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 18, 2021) | |||||||||||||
| - | Share Purchase Agreement, dated as of March 17, 2021, by and among PPL Energy Holdings, LLC, PPL Corporation (solely as guarantor), and National Grid USA (Exhibit 2.2 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 18, 2021) | |||||||||||||
| - | Assignment and Assumption Agreement, dated as of May 3, 2021, by and among PPL Energy Holdings, LLC, PPL Corporation, National Grid USA and PPL Rhode Island Holdings, LLC (Exhibit 2(b)-2 to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2021) | |||||||||||||
| - | Tax Deed, dated as of June 9, 2021, by and among PPL WPD Limited, National Grid Holdings One plc (Exhibit 2.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 14, 2021) | |||||||||||||
| - | Amended and Restated Articles of Incorporation of PPL Corporation, effective as of May 25, 2016 (Exhibit 3(i) to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 26, 2016) | |||||||||||||
| - | Bylaws of PPL Corporation, effective as of | |||||||||||||
| - | Amended and Restated Articles of Incorporation of PPL Electric Utilities Corporation, effective as of October 31, 2013 (Exhibit 3(a) to PPL Electric Utilities Corporation Form 10-Q Report (File No. 1-905) for the quarter ended September 30, 2013) | |||||||||||||
| - | Bylaws of PPL Electric Utilities Corporation, effective as of October 27, 2015 (Exhibit 3(a) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended September 30, 2015) | |||||||||||||
| - | Amended and Restated Articles of Incorporation of Louisville Gas and Electric Company, effective as of November 6, 1996 (Exhibit 3(a) to Registration Statement filed on Form S-4 (File No. 333-173676)) | |||||||||||||
190
| - | Articles of Amendment to Articles of Incorporation of Louisville Gas and Electric Company, effective as of April 6, 2004 (Exhibit 3(b) to Registration Statement filed on Form S-4 (File No. 333-173676)) | |||||||||||||
| - | Bylaws of Louisville Gas and Electric Company, effective as of December 16, 2003 (Exhibit 3(c) to Registration Statement filed on Form S-4 (File No. 333-173676)) | |||||||||||||
| - | Amended and Restated Articles of Incorporation of Kentucky Utilities Company, effective as of December 14, 1993 (Exhibit 3(a) to Registration Statement filed on Form S-4 (File No. 333-173675)) | |||||||||||||
| - | Articles of Amendment to Articles of Incorporation of Kentucky Utilities Company, effective as of April 8, 2004 (Exhibit 3(b) to Registration Statement filed on Form S-4 (File No. 333-173675)) | |||||||||||||
| - | Bylaws of Kentucky Utilities Company, effective as of December 16, 2003 (Exhibit 3(c) to Registration Statement filed on Form S-4 (File No. 333-173675)) | |||||||||||||
| - | Amended and Restated Employee Stock Ownership Plan, dated December 1, 2016 (Exhibit 4(a) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2016) | |||||||||||||
| - | Amendment No. 1 to PPL Employee Stock Ownership Plan, dated October 2, 2017 (Exhibit 4(c) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended September 30, 2017) | |||||||||||||
| - | ||||||||||||||
| - | Amendment No. 3 to PPL Employee Stock Ownership Plan, dated January 1, 2019 (Exhibit 4(a)-4 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2018) | |||||||||||||
| - | Indenture, dated as of November 1, 1997, among PPL Corporation, PPL Capital Funding, Inc. and JPMorgan Chase Bank (formerly The Chase Manhattan Bank), as Trustee (Exhibit 4.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated November 12, 1997) | |||||||||||||
| - | Supplemental Indenture No. 8, dated as of June 14, 2012, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 14, 2012) | |||||||||||||
| - | Supplemental Indenture No. 9, dated as of October 15, 2012, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated October 15, 2012) | |||||||||||||
| - | Supplemental Indenture No. 10, dated as of May 24, 2013, to said Indenture (Exhibit 4.2 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 24, 2013) | |||||||||||||
| - | Supplemental Indenture No. 11, dated as of May 24, 2013, to said Indenture (Exhibit 4.3 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 24, 2013) | |||||||||||||
| - | Supplemental Indenture No. 12, dated as of May 24, 2013, to said Indenture (Exhibit 4.4 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 24, 2013) | |||||||||||||
| - | Supplemental Indenture No. 13, dated as of March 10, 2014, to said Indenture (Exhibit 4.2 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 10, 2014) | |||||||||||||
| - | Supplemental Indenture No. 14, dated as of March 10, 2014, to said Indenture (Exhibit 4.3 to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 10, 2014) | |||||||||||||
191
| - | Supplemental Indenture No. 15, dated as of May 17, 2016, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 17, 2016) | |||||||||||||
| - | Supplemental Indenture No. 16, dated as of September 8, 2017, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated September 6, 2017) | |||||||||||||
| - | Supplemental Indenture No. 17, dated as of | |||||||||||||
| - | ||||||||||||||
| Indenture, dated as of August 1, 2001, by PPL Electric Utilities Corporation and JPMorgan Chase Bank (formerly The Chase Manhattan Bank), as Trustee (Exhibit 4.1 to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated August 21, 2001) | ||||||||||||||
| - | Supplemental Indenture No. 6, dated as of December 1, 2005, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated December 22, 2005) | |||||||||||||
| - | Supplemental Indenture No. 7, dated as of August 1, 2007, to said Indenture (Exhibit 4(b) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated August 14, 2007) | |||||||||||||
| - | Supplemental Indenture No. 9, dated as of October 1, 2008, to said Indenture (Exhibit 4(c) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated October 31, 2008) | |||||||||||||
| - | Supplemental Indenture No. 10, dated as of May 1, 2009, to said Indenture (Exhibit 4(b) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated May 22, 2009) | |||||||||||||
| - | Supplemental Indenture No. 11, dated as of July 1, 2011, to said Indenture (Exhibit 4.1 to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated July 13, 2011) | |||||||||||||
| - | Supplemental Indenture No. 12, dated as of July 1, 2011, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated July 18, 2011) | |||||||||||||
| - | Supplemental Indenture No. 13, dated as of August 1, 2011, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated August 23, 2011) | |||||||||||||
| - | Supplemental Indenture No. 14, dated as of August 1, 2012, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated August 24, 2012) | |||||||||||||
| - | Supplemental Indenture No. 15, dated as of July 1, 2013, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated July 11, 2013) | |||||||||||||
| - | Supplemental Indenture No. 16, dated as of June 1, 2014, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated June 5, 2014) | |||||||||||||
| - | Supplemental Indenture No. 17, dated as of October 1, 2015, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated October 1, 2015) | |||||||||||||
| - | Supplemental Indenture No. 18, dated as of March 1, 2016, to said Indenture (Exhibit 4(c) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated March 10, 2016) | |||||||||||||
| - | Supplemental Indenture No. 19, dated as of May 1, 2017, to said Indenture (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated May 11, 2017) | |||||||||||||
192
| - | ||||||||||||||
| - | ||||||||||||||
| - | Supplemental Indenture No. 22, dated as of September 15, 2020, to said Indenture (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated October 1, 2020) | |||||||||||||
| - | Supplemental Indenture No. 23, dated as of June 15, 2020, to said Indenture (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 24, 2021) | |||||||||||||
| - | Pollution Control Facilities Loan Agreement, dated as of October 1, 2008, between Pennsylvania Economic Development Financing Authority and PPL Electric Utilities Corporation (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated October 31, 2008) | |||||||||||||
| - | Pollution Control Facilities Loan Agreement, dated as of March 1, 2016, between PPL Electric Utilities Corporation and the Lehigh County Industrial Development Authority (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated March 10, 2016) | |||||||||||||
| - | Pollution Control Facilities Loan Agreement, dated as of March 1, 2016, between PPL Electric Utilities Corporation and the Lehigh County Industrial Development Authority (Exhibit 4(b) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated March 10, 2016) | |||||||||||||
| - | ||||||||||||||
| Subordinated Indenture, dated as of March 1, 2007, between PPL Capital Funding, Inc., PPL Corporation and The Bank of New York, as Trustee (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 20, 2007) | ||||||||||||||
| - | Supplemental Indenture No. 1, dated as of March 1, 2007, to said Subordinated Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 20, 2007) | |||||||||||||
| - | Supplemental Indenture No. 4, dated as of March 15, 2013, to said Subordinated Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated March 15, 2013) | |||||||||||||
| - | ||||||||||||||
| Indenture, dated as of October 1, 2010, between Kentucky Utilities Company and The Bank of New York Mellon, as Trustee (Exhibit 4(q)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | ||||||||||||||
| - | Supplemental Indenture No. 1, dated as of October 15, 2010, to said Indenture (Exhibit 4(q)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Supplemental Indenture No. 2, dated as of November 1, 2010, to said Indenture (Exhibit 4(q)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Supplemental Indenture No. 3, dated as of November 1, 2013, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated November 13, 2013) | |||||||||||||
| - | Supplemental Indenture No. 4, dated as of September 1, 2015, to said Indenture (Exhibit 4(b) to Kentucky Utilities Company Form 8-K Report (File No. 1-3464) dated September 28, 2015) | |||||||||||||
| - | Supplemental Indenture No. 5, dated as of August 1, 2016, to said Indenture (Exhibit 4(b) to Kentucky Utilities Company Form 8-K Report (File No. 1-3464) dated August 26, 2016) | |||||||||||||
193
| - | Supplemental Indenture No. 6, dated as of August 1, 2018, to said Indenture (Exhibit 4(a) to PPL Corporation 10-Q Report (File No. 1-11459) for the quarter ended September 30, 2018) | |||||||||||||
| - | Supplemental Indenture No. 7, dated as of March 1, 2019, to said Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated April 1, 2019) | |||||||||||||
| - | Supplemental Indenture No. 8, dated as of May 15, 2020, to said Indenture (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 3, 2020) | |||||||||||||
| - | Indenture, dated as of October 1, 2010, between Louisville Gas and Electric Company and The Bank of New York Mellon, as Trustee (Exhibit 4(r)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Supplemental Indenture No. 1, dated as of October 15, 2010, to said Indenture (Exhibit 4(r)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Supplemental Indenture No. 2, dated as of November 1, 2010, to said Indenture (Exhibit 4(r)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Supplemental Indenture No. 3, dated as of November 1, 2013, to said Indenture (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated November 13, 2013) | |||||||||||||
| - | Supplemental Indenture No. 4, dated as of September 1, 2015, to said Indenture (Exhibit 4(a) to Louisville Gas and Electric Company Form 8-K Report (File No. 1-2893) dated September 28, 2015) | |||||||||||||
| - | Supplemental Indenture No. 5, dated as of September 1, 2016, to said Indenture (Exhibit 4(b) to Louisville Gas and Electric Company Form 8-K (File No. 1-2893) dated September 15, 2016) | |||||||||||||
| - | Supplemental Indenture No. 6, dated as of May 15, 2017, to said Indenture (Exhibit 4(b) to Louisville Gas and Electric Company Form 8-K Report (File No. 1-2893) dated June 1, 2017) | |||||||||||||
| - | Supplemental Indenture No. 7, dated as of | |||||||||||||
| - | 2002 Series A Carroll County Loan Agreement, dated February 1, 2002, by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(w)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated as of September 1, 2010 to said Loan Agreement by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(w)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2002 Series B Carroll County Loan Agreement, dated February 1, 2002, by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(x)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated as of September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(x)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2004 Series A Carroll County Loan Agreement, dated October 1, 2004 and amended and restated as of September 1, 2008, by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(z)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
194
| - | Amendment No. 1 dated as of September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(z)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2006 Series B Carroll County Loan Agreement, dated October 1, 2006 and amended and restated September 1, 2008, by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(aa)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated as of September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(aa)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | ||||||||||||||
| 2008 Series A Carroll County Loan Agreement, dated August 1, 2008 by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(cc)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | ||||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Carroll, Kentucky (Exhibit 4(cc)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2016 Series A Carroll County Loan Agreement dated as of August 1, 2016 between Kentucky Utilities Company and the County of Carroll, Kentucky (Exhibit 4(a) to Kentucky Utilities Company Form 8-K Report (File No. 1-3464) dated August 26, 2016) | |||||||||||||
| - | 2000 Series A Mercer County Loan Agreement, dated May 1, 2000 and amended and restated as of September 1, 2008, by and between Kentucky Utilities Company, and County of Mercer, Kentucky (Exhibit 4(dd)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Mercer, Kentucky (Exhibit 4(dd)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2002 Series A Mercer County Loan Agreement, dated February 1, 2002, by and between Kentucky Utilities Company, and County of Mercer, Kentucky (Exhibit 4(ee)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Mercer, Kentucky (Exhibit 4(ee)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2002 Series A Muhlenberg County Loan Agreement, dated February 1, 2002, by and between Kentucky Utilities Company, and County of Muhlenberg, Kentucky (Exhibit 4(ff)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Kentucky Utilities Company, and County of Muhlenberg, Kentucky (Exhibit 4(ff)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | ||||||||||||||
195
| - | ||||||||||||||
| 2001 Series A Jefferson County Loan Agreement, dated November 1, 2001, by and between Louisville Gas and Electric Company, and Jefferson County, Kentucky (Exhibit 4(jj)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | ||||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and Jefferson County, Kentucky (Exhibit 4(jj)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2001 Series B Jefferson County Loan Agreement, dated November 1, 2001, by and between Louisville Gas and Electric Company, and Jefferson County, Kentucky (Exhibit 4(kk)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and Jefferson County, Kentucky (Exhibit 4(kk)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2003 Series A Louisville/Jefferson County Metro Government Loan Agreement, dated October 1, 2003, by and between Louisville Gas and Electric Company and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(ll)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(ll)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2005 Series A Louisville/Jefferson County Metro Government Loan Agreement, dated February 1, 2005 and amended and restated as of September 1, 2008, by and between Louisville Gas and Electric Company, and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(mm)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(mm)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2007 Series A Louisville/Jefferson County Metro Government Loan Agreement, dated as of March 1, 2007 and amended and restated as of September 1, 2008, by and between Louisville Gas and Electric Company, and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(nn)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(nn)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2007 Series B Louisville/Jefferson County Metro Government Amended and Restated Loan Agreement, dated November 1, 2010, by and between Louisville Gas and Electric Company and Louisville/Jefferson County Metro Government, Kentucky (Exhibit 4(oo) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2001 Series A Trimble County Loan Agreement, dated November 1, 2001, by and between Louisville Gas and Electric Company, and County of Trimble, Kentucky (Exhibit 4(qq)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and the County of Trimble, Kentucky (Exhibit 4(qq)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
196
| - | ||||||||||||||
| 2017 Series A Trimble County Loan Agreement, dated as of June 1, 2017, by and between Louisville Gas and Electric Company and the County of Trimble, Kentucky (Exhibit 4(a) to Louisville Gas and Electric Company Form 8-K Report (File No. 1-2893) dated June 1, 2017) | ||||||||||||||
| - | ||||||||||||||
| - | Amendment No. 1 dated September 1, 2010, to said Loan Agreement by and between Louisville Gas and Electric Company, and County of Trimble, Kentucky (Exhibit 4(rr)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2010) | |||||||||||||
| - | 2016 Series A Trimble County Loan Agreement dated as of September 1, 2016 between Louisville Gas and Electric Company and the County of Trimble, Kentucky (Exhibit 4(a) to Louisville Gas and Electric Company Form 8-K (File No. 1-2893) dated September 15, 2016) | |||||||||||||
| - | ||||||||||||||
| - | Description of PPL Capital Funding, Inc. | |||||||||||||
| - | Description of PPL Electric Utilities Corporation's common stock, no par value per share (Exhibit 4(tt) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2019) | |||||||||||||
| - | $150 million Revolving Credit Agreement, dated as of March 26, 2014, among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor and The Bank of Nova Scotia, as Administrative Agent, Issuing Lender and Lender (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated April 1, 2014) | |||||||||||||
| - | First Amendment to said Revolving Credit Agreement, dated as of March 17, 2015 (Exhibit 10(c)-2 to PPL Corporation Form 10-K Report (File No. | |||||||||||||
| - | Second Amendment to said Revolving Credit Agreement, dated as of March 17, 2016 (Exhibit 10(a) to PPL Corporation Form 10-Q Report (File No. | |||||||||||||
| - | Third Amendment to said Revolving Credit Agreement, dated as of March 17, 2017 (Exhibit 10(a) to PPL Corporation Form 10-Q Report (File No. | |||||||||||||
| - | Fourth Amendment to said Revolving Credit Agreement, dated as of March 16, 2018 (Exhibit 10(b)-5 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2018) | |||||||||||||
| - | Fifth Amendment to said Revolving Credit Agreement, dated as of March 8, 2019 (Exhibit 10.2 to PPL Corporation Form 8-K Report (File No. 11459) dated March 8, 2019) | |||||||||||||
| - | Sixth Amendment to said Revolving Credit Agreement, dated as of March 12, 2020 (Exhibit 10(e) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2020) | |||||||||||||
| - | Seventh Amendment to said Revolving Credit Agreement, dated as of March 9, 2021 | |||||||||||||
| - | Employee Matters Agreement, among PPL Corporation, Talen Energy Corporation, C/R Energy Jade, LLC, Sapphire Power Holdings LLC. and Raven Power Holdings LLC, dated as of June 9, 2014 (Exhibit 10.1 to PPL Energy Supply, LLC Form 8-K Report (File No. 1-32944) dated June 12, 2014) | |||||||||||||
197
| - | ||||||||||||||
| - | ||||||||||||||
| - | ||||||||||||||
| - | ||||||||||||||
| - | $ | |||||||||||||
| - | First Amendment | |||||||||||||
| - | $1,250,000,000 Amended and Restated Revolving Credit Agreement dated as of December 6, 2021 among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor, the Lenders party thereto and Wells Fargo, National Association, as Administrative Agent, Issuing Lender and Swingline Lender (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated | |||||||||||||
| December 6, 2021) | ||||||||||||||
| - | ||||||||||||||
| $ | ||||||||||||||
| - | ||||||||||||||
| - | $400,000,000 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, National Association, as Administrative Agent, Issuing Lender and Swingline Lender (Exhibit 10.4 to PPL Corporation Form 8-K Report (File No. 1-11459) dated | |||||||||||||
| December 6, 2021) | ||||||||||||||
| - | ||||||||||||||
| Amended and Restated Directors Deferred Compensation Plan, dated June 12, 2000 (Exhibit 10(h) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2000) | ||||||||||||||
| - | Amendment No. 1 to said Directors Deferred Compensation Plan, dated December 18, 2002 (Exhibit 10(m)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2002) | |||||||||||||
| - | Amendment No. 2 to said Directors Deferred Compensation Plan, dated December 4, 2003 (Exhibit 10(q)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2003) | |||||||||||||
| - | Amendment No. 3 to said Directors Deferred Compensation Plan, dated as of January 1, 2005 (Exhibit 10(cc)-4 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2005) | |||||||||||||
198
| - | Amendment No. 4 to said Directors Deferred Compensation Plan, dated as of May 1, 2008 (Exhibit 10(x)-5 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2008) | |||||||||||||
| - | Amendment No. 5 to said Directors Deferred Compensation Plan, dated May 28, 2010 (Exhibit 10(a) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended June 30, 2010) | |||||||||||||
| - | Amendment No. 6 to said Directors Deferred Compensation Plan, dated as of April 15, 2015 (Exhibit 10(b) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2015) | |||||||||||||
| - | PPL Corporation Directors Deferred Compensation Plan Trust Agreement, dated as of April 1, 2001, between PPL Corporation and Wachovia Bank, N.A. (as successor to First Union National Bank), as Trustee (Exhibit 10(hh)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2012) | |||||||||||||
| - | PPL Officers Deferred Compensation Plan, PPL Supplemental Executive Retirement Plan and PPL Supplemental Compensation Pension Plan Trust Agreement, dated as of April 1, 2001, between PPL Corporation and Wachovia Bank, N.A. (as successor to First Union National Bank), as Trustee (Exhibit 10(hh)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2012) | |||||||||||||
| - | PPL Revocable Employee Nonqualified Plans Trust Agreement, dated as of March 20, 2007, between PPL Corporation and Wachovia Bank, N.A., as Trustee (Exhibit 10(c) to PPL Corporation Form 10-Q Report (File No. | |||||||||||||
| - | PPL Employee Change in Control Agreements Trust Agreement, dated as of March 20, 2007, between PPL Corporation and Wachovia Bank, N.A., as Trustee (Exhibit 10(d) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2007) | |||||||||||||
| - | PPL Revocable Director Nonqualified Plans Trust Agreement, dated as of March 20, 2007, between PPL Corporation and Wachovia Bank, N.A., as Trustee (Exhibit 10(e) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2007) | |||||||||||||
| - | Amended and Restated Officers Deferred Compensation Plan, dated December 8, 2003 (Exhibit 10(r) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2003) | |||||||||||||
| - | Amendment No. 1 to said Officers Deferred Compensation Plan, dated as of January 1, 2005 (Exhibit 10(ee)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2005) | |||||||||||||
| - | Amendment No. 2 to said Officers Deferred Compensation Plan, dated as of January 22, 2007 (Exhibit 10(bb)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2006) | |||||||||||||
| - | Amendment No. 3 to said Officers Deferred Compensation Plan, dated as of June 1, 2008 (Exhibit 10(z)-4 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2008) | |||||||||||||
| - | Amendment No. 4 to said Officers Deferred Compensation Plan, dated as of February 15, 2012 (Exhibit 10(ff)-5 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2011) | |||||||||||||
| - | Amendment No. 5 to said Executive Deferred Compensation Plan, dated as of May 8, 2014 (Exhibit 10(a) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended June 30, 2014) | |||||||||||||
199
| - | Amendment No. 6 to said Executive Deferred Compensation Plan, dated as of December 16, 2015 (Exhibit [_]10(q)-7 to PPL Corporation Form 10-K Report (File No. | |||||||||||||
| - | Amendment No. 7 to said Executive Deferred Compensation Plan, dated as of January 1, 2019 (Exhibit [_]10(x)-8 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2018) | |||||||||||||
| - | Amendment No. 8 to said Executive Deferred Compensation Plan, dated as of December 20, 2021 | |||||||||||||
| - | Amended and Restated Supplemental Executive Retirement Plan, dated December 8, 2003 (Exhibit 10(s) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2003) | |||||||||||||
| - | Amendment No. 1 to said Supplemental Executive Retirement Plan, dated December 16, 2004 (Exhibit 99.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated December 17, 2004) | |||||||||||||
| - | Amendment No. 2 to said Supplemental Executive Retirement Plan, dated as of January 1, 2005 (Exhibit 10(ff)-3 to PPL Corporation Form 10-K Report (File 1-11459) for the year ended December 31, 2005) | |||||||||||||
| - | Amendment No. 3 to said Supplemental Executive Retirement Plan, dated as of January 22, 2007 (Exhibit 10(cc)-4 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2006) | |||||||||||||
| - | Amendment No. 4 to said Supplemental Executive Retirement Plan, dated as of December 9, 2008 (Exhibit 10(aa)-5 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2008) | |||||||||||||
| - | Amendment No. 5 to said Supplemental Executive Retirement Plan, dated as of February 15, 2012 (Exhibit 10(gg)-6 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2011) | |||||||||||||
| - | Amendment No. 6 to the Amended and Restated Supplemental Executive Retirement Plan, dated March 23, 2018 (Exhibit 10(g) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2018) | |||||||||||||
| - | Amended and Restated Incentive Compensation Plan, effective January 1, 2003 (Exhibit 10(p) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2002) | |||||||||||||
| - | Amendment No. 1 to said Incentive Compensation Plan, dated as of January 1, 2005 (Exhibit 10(gg)-2 to PPL Corporation Form 10-K Report (File 1-11459) for the year ended December 31, 2005) | |||||||||||||
| - | Amendment No. 2 to said Incentive Compensation Plan, dated as of January 26, 2007 (Exhibit 10(dd)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2006) | |||||||||||||
| - | Amendment No. 3 to said Incentive Compensation Plan, dated as of March 21, 2007 (Exhibit 10(f) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended March 31, 2007) | |||||||||||||
| - | Amendment No. 4 to said Incentive Compensation Plan, effective December 1, 2007 (Exhibit 10(a) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended September 30, 2008) | |||||||||||||
| - | Amendment No. 5 to said Incentive Compensation Plan, dated as of December 16, 2008 (Exhibit 10(bb)-6 to PPL Corporation Form 10-K Report (File 1-11459) for the year ended December 31, 2008) | |||||||||||||
200
| - | Form of Stock Option Agreement for stock option awards under the Incentive Compensation Plan (Exhibit 10(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated February 1, 2006) | |||||||||||||
| - | Form of Restricted Stock Unit Agreement for restricted stock unit awards under the Incentive Compensation Plan (Exhibit 10(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated February 1, 2006) | |||||||||||||
| - | Form of Performance Unit Agreement for performance unit awards under the Incentive Compensation Plan (Exhibit 10(ss) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2007) | |||||||||||||
| - | Amended and Restated Incentive Compensation Plan for Key Employees, effective | |||||||||||||
| - | Short-term Incentive Plan (Annex B to Proxy Statement of PPL Corporation, dated April 12, 2016) | |||||||||||||
| - | ||||||||||||||
| Form of Change in Control Severance Protection Agreement entered into between PPL Corporation and Joseph P. Bergstein, Jr., John R. Crockett III, Gregory N. Dudkin, | ||||||||||||||
| - | PPL Corporation Amended and Restated 2012 Stock Incentive Plan, | |||||||||||||
| - | Form of Performance Unit Agreement for performance unit awards under the Stock Incentive Plan (Exhibit 10(tt)-2 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2012) | |||||||||||||
| - | Form of Performance Contingent Restricted Stock Unit Agreement for restricted stock unit awards under the Stock Incentive Plan (Exhibit 10(tt)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2012) | |||||||||||||
| - | Form of Nonqualified Stock Option Agreement for stock option awards under the Stock Incentive Plan (Exhibit 10(tt)-4 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2012) | |||||||||||||
| - | Form of Total Shareholder Return Performance Unit Agreement for performance units under the Amended and Restated 2012 Stock Incentive Plan (Exhibit 10(dd)-5 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2017) | |||||||||||||
| - | Form of Return on Equity Performance Unit Agreement for performance units under the Amended and Restated 2012 Stock Incentive Plan (Exhibit 10(dd)-6 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2017) | |||||||||||||
| - | PPL Corporation Executive Severance Plan, effective as of July 26, 2012 (Exhibit 10(d) to PPL Corporation Form 10-Q Report (File No. 1-11459) for the quarter ended June 30, 2012) | |||||||||||||
| - | Form of Western Power Distribution Phantom Stock Option Award Agreement for stock option awards under the Western Power Distribution Long-Term Incentive Plan (Exhibit [_]10(bbb)-1 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2014) | |||||||||||||
| - | ||||||||||||||
| Form of Grant Letter dated May 29, 2015 (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 1, 2015) | ||||||||||||||
201
| Amended and Restated Personal Contract dated August 13, 2013, between Western Power Distribution (South West) plc and Philip Swift (Exhibit [_]10(kk)-1 to PPL Corporation | ||||||||||||||
| Ill-Health Retirement Arrangement letter agreement dated March 2, 2016, between Western Power Distribution (South West) plc and Philip Swift (Exhibit [_]10(kk)-2 to PPL | ||||||||||||||
| Pension Arrangement letter agreement dated March 2, 2016, between Western Power Distribution (South West) plc and Philip Swift (Exhibit [_]10(kk)-3 to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2018) | ||||||||||||||
| - | Transition and Retirement Agreement dated August 12, 2021, by and among Paul W. Thompson, LG&E and KU | |||||||||||||
| - | Transition Incentive Award letter agreement dated August 21, 2020, between PPL Corporation and Philip Swift | |||||||||||||
| - | Transition Incentive Award Amendment letter agreement dated February 8, 2021, between PPL Corporation and Philip Swift | |||||||||||||
| - | Form of Earnings | |||||||||||||
| - | ||||||||||||||
| - | ||||||||||||||
| - | Subsidiaries of PPL Corporation | |||||||||||||
| - | Consent of Deloitte & Touche LLP - PPL Corporation | |||||||||||||
| - | Consent of Deloitte & Touche LLP - PPL Electric Utilities Corporation | |||||||||||||
| - | Consent of Deloitte & Touche LLP - Louisville Gas and Electric Company | |||||||||||||
| - | Consent of Deloitte & Touche LLP - Kentucky Utilities Company | |||||||||||||
| - | ||||||||||||||
| - | Certificate of PPL's principal executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of PPL's principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
202
| - | Certificate of PPL Electric's principal executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of PPL Electric's principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | ||||||||||||||
| Certificate of LG&E's principal executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | ||||||||||||||
| - | Certificate of LG&E's principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of KU's principal executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of KU's principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of PPL's principal executive officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | Certificate of PPL Electric's principal executive officer and principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | ||||||||||||||
| Certificate of LG&E's principal executive officer and principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | ||||||||||||||
| - | Certificate of KU's principal executive officer and principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | |||||||||||||
| - | PPL Corporation and Subsidiaries Long-term Debt Schedule | |||||||||||||
| 101.INS | - | XBRL Instance Document for PPL Corporation, PPL | ||||||||||||
| 101.SCH | - | XBRL Taxonomy Extension Schema for PPL Corporation, PPL | ||||||||||||
| 101.CAL | - | XBRL Taxonomy Extension Calculation Linkbase for PPL Corporation, PPL | ||||||||||||
| 101.DEF | - | XBRL Taxonomy Extension Definition Linkbase for PPL Corporation, PPL | ||||||||||||
| 101.LAB | - | XBRL Taxonomy Extension Label Linkbase for PPL Corporation, PPL | ||||||||||||
203
| 101.PRE | - | XBRL Taxonomy Extension Presentation Linkbase for PPL Corporation, PPL | ||||||||||||
| 104 | The Cover Page Interactive Data File is formatted as Inline XBRL and contained in Exhibits 101. | |||||||||||||
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
PPL Corporation
(Registrant)
| By /s/ | ||||||||||||||
| Chief Executive Officer | ||||||||||||||
| Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated. | ||||||||||||||
| /s/ | ||||||||||||||
| Chief Executive Officer | ||||||||||||||
| and Director | ||||||||||||||
| (Principal Executive Officer) | ||||||||||||||
| /s/ | ||||||||||||||
| Chief Financial Officer | ||||||||||||||
| (Principal Financial Officer) | ||||||||||||||
| /s/ | ||||||||||||||
| Vice President and Controller | ||||||||||||||
| (Principal Accounting Officer) | ||||||||||||||
| Directors: | ||||||||||||||
| Natica von Althann | ||||||||||||||
| Steven G. Elliott | Keith H. Williamson | |||||||||||||
| Venkata Rajamannar Madabhushi | Phoebe A. Wood | |||||||||||||
| Armando Zagalo de Lima | ||||||||||||||
| Craig A. Rogerson | ||||||||||||||
| | ||||||||||||||
| /s/ | ||||||||||||||
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
PPL Electric Utilities Corporation
(Registrant)
| By /s/ | ||||||||||||||
| President | ||||||||||||||
| Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated. | ||||||||||||||
| /s/ | ||||||||||||||
| President | ||||||||||||||
| (Principal Executive Officer) | ||||||||||||||
Controller (Principal Financial Officer and Principal Accounting Officer) | ||||||||||||||||
| Directors: | ||||||||||||||||
| /s/ | ||||||||||||||||
/s/ Vincent Sorgi | ||||||||||||||||
| Joseph P. Bergstein, Jr. | Vincent Sorgi | |||||||||||||||
/s/ Gregory N. Dudkin | /s/ Wendy E. Stark | |||||||||||||||
| Wendy E. Stark | ||||||||||||||||
| /s/ Stephanie R. Raymond | ||||||||||||||||
| Stephanie R. Raymond | ||||||||||||||||
| Date: February | ||||||||||||||||
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Louisville Gas and Electric Company
(Registrant)
| By /s/ | ||||||||||||||
| Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated. | ||||||||||||||
| /s/ | ||||||||||||||
President | ||||||||||||||
| (Principal Executive Officer) | ||||||||||||||
| /s/ Kent W. Blake | ||||||||||||||
| Kent W. Blake - | ||||||||||||||
Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer) | ||||||||||||||
| Directors: | ||||||||||||||
| /s/ Lonnie E. Bellar | /s/ John R. Crockett III | |||||||||||||
| Lonnie E. Bellar | John R. Crockett III | |||||||||||||
| /s/ Joseph P. Bergstein, Jr. | /s/ Gregory N. Dudkin | |||||||||||||
| Joseph P. Bergstein, Jr. | Gregory N. Dudkin | |||||||||||||
| /s/ Kent W. Blake | ||||||||||||||
| Kent W. Blake | ||||||||||||||
| Date: February | ||||||||||||||
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Kentucky Utilities Company
(Registrant)
| By /s/ | ||||||||||||||
| Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated. | ||||||||||||||
| /s/ | ||||||||||||||
President | ||||||||||||||
| (Principal Executive Officer) | ||||||||||||||
| /s/ Kent W. Blake | ||||||||||||||
| Kent W. Blake - | ||||||||||||||
Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer) | ||||||||||||||
| Directors: | ||||||||||||||
| /s/ Lonnie E. Bellar | /s/ John R. Crockett III | |||||||||||||
| Lonnie E. Bellar | John R. Crockett III | |||||||||||||
| /s/ Joseph P. Bergstein, Jr. | /s/ Gregory N. Dudkin | |||||||||||||
| Joseph P. Bergstein, Jr. | Gregory N. Dudkin | |||||||||||||
| /s/ Kent W. Blake | ||||||||||||||
| Kent W. Blake | ||||||||||||||
| Date: February | ||||||||||||||