

UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549

FORM 10-Q

[X]	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the quarterly period ended September 30, ~~2017~~2018.
OR
[ ]	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the transition period from _________ to ___________



Commission File Number	Registrant; State of Incorporation; Address and Telephone Number	IRS Employer Identification No.

1-11459	PPL Corporation (Exact name of Registrant as specified in its charter) (Pennsylvania) Two North Ninth Street Allentown, PA 18101-1179 (610) 774-5151	23-2758192

1-905	PPL Electric Utilities Corporation (Exact name of Registrant as specified in its charter) (Pennsylvania) Two North Ninth Street Allentown, PA 18101-1179 (610) 774-5151	23-0959590

333-173665	LG&E and KU Energy LLC (Exact name of Registrant as specified in its charter) (Kentucky) 220 West Main Street Louisville, KY 40202-1377 (502) 627-2000	20-0523163

1-2893	Louisville Gas and Electric Company (Exact name of Registrant as specified in its charter) (Kentucky) 220 West Main Street Louisville, KY 40202-1377 (502) 627-2000	61-0264150

1-3464	Kentucky Utilities Company (Exact name of Registrant as specified in its charter) (Kentucky and Virginia) One Quality Street Lexington, KY 40507-1462 (502) 627-2000	61-0247570

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



PPL Corporation	Yes X	No
PPL Electric Utilities Corporation	Yes X	No
LG&E and KU Energy LLC	Yes X	No
Louisville Gas and Electric Company	Yes X	No
Kentucky Utilities Company	Yes X	No

Indicate by check mark whether the registrants have submitted electronically ~~and posted on their corporate Web site, if any,~~ every Interactive Data File required to be submitted ~~and posted~~ pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit ~~and post~~ such files).



PPL Corporation	Yes X	No
PPL Electric Utilities Corporation	Yes X	No
LG&E and KU Energy LLC	Yes X	No
Louisville Gas and Electric Company	Yes X	No
Kentucky Utilities Company	Yes X	No

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



	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
PPL Corporation	[ X ]	[ ]	[ ]	[ ]	[ ]
PPL Electric Utilities Corporation	[ ]	[ ]	[ X ]	[ ]	[ ]
LG&E and KU Energy LLC	[ ]	[ ]	[ X ]	[ ]	[ ]
Louisville Gas and Electric Company	[ ]	[ ]	[ X ]	[ ]	[ ]
Kentucky Utilities Company	[ ]	[ ]	[ X ]	[ ]	[ ]

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



	PPL Corporation	[ ]
	PPL Electric Utilities Corporation	[ ]
	LG&E and KU Energy LLC	[ ]
	Louisville Gas and Electric Company	[ ]
	Kentucky Utilities Company	[ ]

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



PPL Corporation	Yes	No X
PPL Electric Utilities Corporation	Yes	No X
LG&E and KU Energy LLC	Yes	No X
Louisville Gas and Electric Company	Yes	No X
Kentucky Utilities Company	Yes	No X

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



	PPL Corporation	Common stock, $0.01 par value, ~~688,464,316~~720,199,922 shares outstanding at October 25, ~~2017.~~2018.

	PPL Electric Utilities Corporation	Common stock, no par value, 66,368,056 shares outstanding and all held by PPL Corporation at October 25, ~~2017.~~2018.

	LG&E and KU Energy LLC	PPL Corporation directly holds all of the membership interests in LG&E and KU Energy LLC.

	Louisville Gas and Electric Company	Common stock, no par value, 21,294,223 shares outstanding and all held by LG&E and KU Energy LLC at October 25, ~~2017.~~2018.

	Kentucky Utilities Company	Common stock, no par value, 37,817,878 shares outstanding and all held by LG&E and KU Energy LLC at October 25, ~~2017.~~2018.

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

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PPL CORPORATION

PPL ELECTRIC UTILITIES CORPORATION

LG&E AND KU ENERGY LLC

LOUISVILLE GAS AND ELECTRIC COMPANY

KENTUCKY UTILITIES COMPANY

FORM 10-Q

FOR THE QUARTER ENDED SEPTEMBER 30, ~~2017~~2018

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This combined Form 10-Q is separately filed by the following Registrants in their individual capacity: PPL Corporation, PPL Electric Utilities Corporation, 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.

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~~Registrants' financial statements in accordance with GAAP. This presentation has been applied where identification of particular subsidiaries is not material to the matter being disclosed, and to conform narrative disclosures to the presentation of financial information on a consolidated basis.



				Page
GLOSSARY OF TERMS AND ABBREVIATIONS				i
FORWARD-LOOKING INFORMATION				1
PART I. FINANCIAL INFORMATION
	Item 1. Financial Statements
		PPL Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	3
			Condensed Consolidated Statements of Comprehensive Income ~~(Loss)~~	4
			Condensed Consolidated Statements of Cash Flows	5
			Condensed Consolidated Balance Sheets	6
			Condensed Consolidated Statements of Equity	8
		PPL Electric Utilities Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	10
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Balance Sheets	12
			Condensed Consolidated Statements of Equity	14
		LG&E and KU Energy LLC and Subsidiaries
			Condensed Consolidated Statements of Income	15
			Condensed Consolidated Statements of Comprehensive Income	16
			Condensed Consolidated Statements of Cash Flows	17
			Condensed Consolidated Balance Sheets	18
			Condensed Consolidated Statements of Equity	20
		Louisville Gas and Electric Company
			Condensed Statements of Income	22
			Condensed Statements of Cash Flows	23
			Condensed Balance Sheets	24
			Condensed Statements of Equity	26
		Kentucky Utilities Company
			Condensed Statements of Income	28
			Condensed Statements of Cash Flows	29
			Condensed Balance Sheets	30
			Condensed Statements of Equity	32

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	Combined Notes to Condensed Financial Statements (Unaudited)
		1. Interim Financial Statements		33
		2. Summary of Significant Accounting Policies		33
		3. Segment and Related Information		3435
		4. ~~Earnings Per Share~~		34
		~~5. Income Taxes~~Revenue from Contracts with Customers		36
		~~6. Utility Rate Regulation~~5. Earnings Per Share		3739
		~~7. Financing Activities~~6. Income Taxes		40
		~~8. Defined Benefits~~7. Utility Rate Regulation		4344
		8. Financing Activities		50
		9. ~~Commitments and Contingencies~~Defined Benefits		4553
		10. ~~Related Party Transactions~~		54
		~~11. Other Income (Expense) - net~~Commitments and Contingencies		55
		~~12. Fair Value Measurements~~11. Related Party Transactions		5564
		12. Other Income (Expense) - net		66
		13. ~~Derivative Instruments and Hedging Activities~~Fair Value Measurements		5766
		14. ~~Goodwill~~Derivative Instruments and ~~Other Intangible Assets~~Hedging Activities		6569
		15. Asset Retirement Obligations		6576
		16. Accumulated Other Comprehensive Income (Loss)		6676
		17. New Accounting Guidance Pending Adoption		6778
	Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		7081
			Introduction	7081
			Business Strategy	7283
			Financial and Operational Developments	7384
		Results of Operations		7489
			PPL Corporation and Subsidiaries - Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins	7590
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis, Earnings and Adjusted Gross Margins	87104
			LG&E and KU Energy LLC and Subsidiaries - Statement of Income Analysis, Earnings and Adjusted Gross Margins	90107
			Louisville Gas and Electric Company - Statement of Income Analysis, Earnings and Adjusted Gross Margins	92110
			Kentucky Utilities Company - Statement of Income Analysis, Earnings and Adjusted Gross Margins	95113
		Financial Condition		97116
			Liquidity and Capital Resources	97116
			Risk Management	~~103~~122
			Foreign Currency Translation	~~105~~124
			Related Party Transactions	~~105~~124
			Acquisitions, Development and Divestitures	~~105~~125
			Environmental Matters	~~106~~125
		New Accounting Guidance		~~106~~125
		Application of Critical Accounting Policies		~~106~~126
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			~~107~~127
	Item 4. Controls and Procedures			~~107~~127
PART II. OTHER INFORMATION
	Item 1. Legal Proceedings			~~107~~127
	Item 1A. Risk Factors			~~107~~127
	Item 4. Mine Safety Disclosures			~~107~~127
	Item 5. Other Information			127
	Item 6. Exhibits			~~107~~128
SIGNATURES				~~110~~130
COMPUTATIONS OF RATIO OF EARNINGS TO FIXED CHARGES
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

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GLOSSARY OF TERMS AND ABBREVIATIONS

PPL Corporation and its subsidiaries

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 LKE and its subsidiaries.

PPL - PPL Corporation, the 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 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 EU Services - PPL EU Services Corporation, a subsidiary of PPL that provides administrative, management and support services primarily to PPL Electric.

PPL Global - PPL Global, LLC, a subsidiary of PPL Energy Funding that, primarily through its subsidiaries, owns and operates WPD, PPL's regulated electricity distribution businesses in the U.K.

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 indirect U.K. subsidiary of PPL ~~Global, which carries a liability for a closed defined benefit pension plan and a receivable from WPD plc.~~Global. Following a reorganization in October 2015 and October 2017, PPL WPD Limited is ~~now~~an indirect parent to WPD plc having previously been a sister company.

WPD - refers to PPL WPD Limited and its subsidiaries.

WPD (East Midlands) - Western Power Distribution (East Midlands) plc, a British regional electricity distribution utility company.

WPD plc - Western Power Distribution plc, ~~a direct~~an indirect U.K. 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 Midlands - refers to WPD (East Midlands) and WPD (West Midlands), collectively.

WPD (South Wales) - Western Power Distribution (South Wales) plc, a British regional electricity distribution utility company.

WPD (South West) - Western Power Distribution (South West) plc, a British regional electricity distribution utility company.

WPD (West Midlands) - Western Power Distribution (West Midlands) plc, a British regional electricity distribution utility company.

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WKE - Western Kentucky Energy Corp., a subsidiary of LKE that leased certain ~~non-utility~~non-regulated utility generating plants in western Kentucky until July 2009.

Other terms and abbreviations

£ - British pound sterling.

~~2016~~2017 Form 10-K - Annual Report to the SEC on Form 10-K for the year ended December 31, ~~2016.~~2017.

Act 11 - Act 11 of 2012 that became effective on April 16, 2012. The Pennsylvania legislation ~~authorizes~~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.~~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 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).

Advanced Metering System - meters and ~~meter reading~~meter-reading systems 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 - ~~PPL's~~ at-the-market ~~common~~ stock offering program.

~~BSER~~ - Best System of Emission Reduction. The degree of emission reduction the EPA determines has been adequately demonstrated when taking into account the cost of achieving such reduction and any non-air quality health and environmental impact and energy requirements.

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

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

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.

COBRA - Consolidated Omnibus Budget Reconciliation Act, which provides individuals the option to temporarily continue employer group health insurance coverage after termination of employment.

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.

CPIH - Consumer Price Index including owner-occupiers' housing costs. An aggregate measure of changes in the cost of living in the U.K., including a measure of owner-occupiers' housing costs.

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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Depreciation not normalized - the flow-through income tax impact related to the state regulatory treatment of depreciation-related timing differences.

~~Distribution Automation~~ - advanced grid intelligence enabling LG&E and KU to perform remote monitoring and control, circuit segmentation and "self-healing" of select distribution system circuits, improving grid reliability and efficiency.

DNO - Distribution Network Operator in the U.K.

DRIP - PPL Amended and Restated Dividend Reinvestment and Direct Stock Purchase Plan.

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

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

DUoS - Distribution Use of System, the charge to licensed third party energy suppliers who are WPD's customers and use WPD's networks to deliver electricity to their customers, the end-users.

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

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

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

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

EPS - ~~Earnings~~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.

GHG(s) - greenhouse gas(es).

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

HB 487 - House Bill 487. Comprehensive Kentucky state tax legislation enacted on April 27, 2018.

IBEW - International Brotherhood of Electrical Workers.

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

IT - Information Technology.

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

~~LCIDA~~kV - ~~Lehigh County Industrial Development Authority.~~kilovolt.

kWh - kilowatt hour, basic unit of electrical energy.

iii

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LIBOR - London Interbank Offered Rate.

~~Margins~~Mcf - ~~A non-GAAP financial~~one thousand cubic feet, a unit of measure ~~of performance used in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).~~for natural gas.

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

MPR - Mid-period review, which is a review of output requirements in RIIO-ED1 that can be initiated by Ofgem halfway through the price control covering material changes to existing outputs that can be justified by clear changes in government policy or new outputs that may be needed to meet the needs of consumers and other network users. On April 30, 2018, Ofgem decided not to engage in a mid-period review of the RIIO-ED1 price-control period.

MW - megawatt, one thousand kilowatts.

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

NERC - North American Electric Reliability Corporation.

~~NGCC~~New Source Review - ~~Natural gas-fired combined-cycle generating plant.~~a Clean Air Act program that requires industrial facilities to install updated pollution control equipment when they are built or when making a modification that increases emissions beyond certain allowable thresholds.

~~iii~~

~~Table of Contents~~

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.

Ofgem - Office of Gas and Electricity Markets, the British agency that regulates transmission, distribution and wholesale sales of electricity and related matters.

OVEC - Ohio Valley Electric Corporation, located in Piketon, Ohio, an entity in which LKE indirectly owns an 8.13% interest (consists of LG&E's 5.63% and KU's 2.50% interests), which is accounted for as a cost-method investment. OVEC owns and operates two coal-fired power plants, the Kyger Creek plant in Ohio and the Clifty Creek plant in Indiana, with combined ~~summer rating~~ capacities of 2,120 MW.

Performance ~~Unit~~unit - A 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) total shareowner return (TSR) over a three-year performance period as compared to companies in the Philadelphia Stock Exchange Utility ~~Index.~~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.

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.

PP&E - property, plant and equipment.

PPL Energy Supply - prior to the June 1, 2015 spinoff, PPL Energy Supply, LLC, a subsidiary of PPL Energy Funding and the indirect parent company of PPL Montana, LLC.

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

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RAV - regulatory asset value. This term, used within the U.K. regulatory environment, is also commonly known as RAB or regulatory asset base. RAV is based on historical investment costs at time of privatization, plus subsequent allowed additions less annual regulatory depreciation, and represents the value on which DNOs earn a return in accordance with the regulatory cost of capital. RAV is indexed to Retail Price Index (RPI) in order to allow for the effects of inflation. RAV additions ~~are~~have been and continue to be based on a percentage of annual total expenditures that have a long-term benefit to WPD (similar to capital projects for the U.S. regulated businesses that are generally included in rate base).

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").

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

RFC - ReliabilityFirst Corporation, one of eight regional entities with delegated authority from NERC that work to safeguard the reliability of the bulk power systems throughout North America.

RIIO - Ofgem's framework for setting U.K. regulated gas and electric utility price controls which stands for "Revenues = Incentive + Innovation + Outputs." RIIO-1 refers to the first generation of price controls under the RIIO framework. RIIO-ED1 refers to the RIIO regulatory price control applicable to the operators of U.K. electricity distribution networks, the duration of which is April 2015 through March 2023. RIIO-2 refers to the second generation of price controls under the RIIO framework. RIIO-ED2 refers to the second regulatory price control applicable to the operators of U.K. electricity distribution networks, which will begin in April 2023.

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.

RPI - ~~Retail Price Index,~~retail price index, is a measure of inflation in the United Kingdom published monthly by the Office for National Statistics.

~~SCRs~~ ~~- selective catalytic reduction, a pollution control process for the removal of nitrogen oxide from exhaust gas.~~

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

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.

~~Table~~SCRs - selective catalytic reduction, a pollution control process for the removal of ~~Contents~~

nitrogen oxide from exhaust gas.

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.

SERC - SERC Reliability Corporation, one of eight regional entities with delegated authority from NERC that work to safeguard the reliability of the bulk power systems throughout North America.

Smart meter - an electric meter that utilizes smart metering technology.

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's 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 owner of the competitive generation assets of PPL Energy Supply and certain affiliates of Riverstone.

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

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

U.K. Finance Acts - refers to U.K. Finance Act of 2015 and 2016, enacted in November 2015 and September 2016 respectively, which collectively reduced the U.K. statutory corporate income tax rate from 20% to 19%, effective April 1, 2017 and from 19% to 17%, effective April 1, 2020.

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

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

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Forward-looking Information

Statements contained in this Form 10-Q concerning expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are other than statements of historical fact are "forward-looking statements" within the meaning of the federal securities laws. Although the Registrants believe that the expectations and assumptions reflected in these statements are reasonable, there can be no assurance that these expectations will prove to be correct. Forward-looking statements are subject to many risks and uncertainties, and actual results may differ materially from the results discussed in forward-looking statements. In addition to the specific factors discussed in each Registrant's ~~2016~~2017 Form 10-K and in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in this Form 10-Q, the following are among the important factors that could cause actual results to differ materially and adversely from the forward-looking statements:

the outcome of rate cases or other cost recovery or revenue ~~filings;~~proceedings;

changes in U.S. state or federal, or U.K. tax laws or ~~regulations;~~regulations, including the TCJA;

effects of cyber-based intrusions or natural disasters, threatened or actual terrorism, war or other hostilities;

significant decreases in demand for electricity in the U.S.;

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

changes in foreign currency exchange rates for British pound sterling and the related impact on unrealized gains and losses on PPL's foreign currency economic hedges;

the effectiveness of our risk management programs, including foreign currency and interest rate hedging;

non-achievement by WPD of performance targets set by Ofgem;

the effect of changes in RPI on WPD's revenues and index linked debt;

~~the March 29, 2017 notification by the U.K.~~developments related to ~~the European Council of the European Union of~~ongoing negotiations regarding the U.K.'s intent to withdraw from the European Union and any actions in response thereto;

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 or credit, 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 its impact on the value of assets in defined benefit plans, and the potential cash funding requirements if fair value declines;

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;

the potential impact of any unrecorded commitments and liabilities ~~if any,~~ 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 ~~credit ratings;~~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;

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;

new 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;

business dispositions or acquisitions and our ability to realize expected benefits from such business transactions;

collective labor bargaining negotiations; and

the outcome of litigation against the Registrants and their subsidiaries.

Any such forward-looking statements should be considered in light of such 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 such statement to reflect subsequent developments or information.

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PART I. FINANCIAL INFORMATION

ITEM 1. Financial Statements

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, except share data)


	Three Months Ended September 30,					Nine Months Ended September 30,					Three Months Ended September 30,					Nine Months Ended September 30,
	2017			2016		2017			2016		2018		2017			2018		2017
Operating Revenues	$	1,845		$	1,889	$	5,521		$	5,685	$	1,872	$	1,845		$	5,846	$	5,521

Operating Expenses
Operation
Fuel	202			227		576			607		206		202			609		576
Energy purchases	143			151		494			531		149		143			538		494
Other operation and maintenance	397			417		1,217			1,292		479		438			1,453		1,340
Depreciation	257			232		745			692		275		257			817		745
Taxes, other than income	69			76		214			229		77		69			234		214
Total Operating Expenses	1,068			1,103		3,246			3,351		1,186		1,109			3,651		3,369

Operating Income	777			786		2,275			2,334		686		736			2,195		2,152

Other Income (Expense) - net	(76		)	49		(235		)	284		106		(35		)	297		(112		)

Interest Expense	230			223		669			671		244		230			718		669

Income Before Income Taxes	471			612		1,371			1,947		548		471			1,774		1,371

Income Taxes	116			139		321			510		103		116			362		321

Net Income	$	355		$	473	$	1,050		$	1,437	$	445	$	355		$	1,412	$	1,050

Earnings Per Share of Common Stock:
Net Income Available to PPL Common Shareowners:
Basic	$	0.52		$	0.70	$	1.53		$	2.12	$	0.63	$	0.52		$	2.02	$	1.53
Diluted	$	0.51		$	0.69	$	1.53		$	2.11	$	0.62	$	0.51		$	2.01	$	1.53

Dividends Declared Per Share of Common Stock	$	0.3950		$	0.38	$	1.185		$	1.14	$	0.41	$	0.395		$	1.23	$	1.185

Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	686,563			678,114		683,783			676,905		703,730		686,563			699,117		683,783
Diluted	688,746			680,348		686,081			679,969		710,517		688,746			702,305		686,081

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

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME ~~(LOSS)~~

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016			2018			2017			2018			2017
Net income	$	355		$	473		$	1,050		$	1,437		$	445		$	355		$	1,412		$	1,050

Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax of $0, ($2), ($1), ($4)	(12		)	(641		)	195			(837		)
Qualifying derivatives, net of tax of $0, ($16), $7, ($9)	1			62			(29		)	57
Foreign currency translation adjustments, net of tax of $0, $0, ($2), ($1)													(187		)	(12		)	(321		)	195
Qualifying derivatives, net of tax of ($5), $0, ($5), $7													22			1			21			(29		)
Defined benefit plans:
Net actuarial gain (loss), net of tax of $2, $4, $9, $3	(3		)	(6		)	(14		)	(4		)
Prior service costs, net of tax of $0, $0, $0, $0													—			—			(1		)	—
Net actuarial gain (loss), net of tax of $3, $2, $3, $9													(8		)	(3		)	(9		)	(14		)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax of $1, $17, ($6), $15	—			(69		)	24			(62		)
Qualifying derivatives, net of tax of $3, $1, $4, ($6)													(14		)	—			(21		)	24
Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0, $0	—			—			1			(1		)	—			—			—			1
Defined benefit plans:
Prior service costs, net of tax of ($1), ($1), ($1), ($1)	—			—			1			1			—			—			1			1
Net actuarial (gain) loss, net of tax of ($10), ($10), ($28), ($27)	34			31			97			94
Net actuarial (gain) loss, net of tax of ($8), ($10), ($26), ($28)													34			34			104			97
Total other comprehensive income (loss)	20			(623		)	275			(752		)	(153		)	20			(226		)	275

Comprehensive income (loss)	$	375		$	(150	)	$	1,325		$	685
Comprehensive income													$	292		$	375		$	1,186		$	1,325

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

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2018			2017
Cash Flows from Operating Activities
Net income	$	1,050		$	1,437		$	1,412		$	1,050
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	745			692			817			745
Amortization	72			54			56			72
Defined benefit plans - expense (income)	(69		)	(29		)
Defined benefit plans - (income)							(146		)	(69		)
Deferred income taxes and investment tax credits	284			436			255			284
Unrealized (gains) losses on derivatives, and other hedging activities	194			107			(129		)	194
Stock-based compensation expense	30			23			21			30
Other	(8		)	(12		)	(12		)	(8		)
Change in current assets and current liabilities
Accounts receivable	25			(29		)	38			25
Accounts payable	(93		)	(40		)	(55		)	(93		)
Unbilled revenues	81			32			129			81
Fuel, materials and supplies	35			8			25			35
Prepayments	(37		)	(34		)	(38		)	(37		)
Taxes payable	6			40			20			6
Regulatory assets and liabilities, net	(3		)	(32		)	39			(3		)
Accrued interest	49			32			48			49
Other current liabilities	(53		)	(48		)	(36		)	(53		)
Other	5			(5		)	(21		)	5
Other operating activities
Defined benefit plans - funding	(558		)	(345		)	(284		)	(558		)
Proceeds from transfer of excess benefit plan funds							65			—
Other assets	4			18			(38		)	4
Other liabilities	(5		)	(75		)	44			(5		)
Net cash provided by operating activities	1,754			2,230			2,210			1,754
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(2,152		)	(2,073		)	(2,344		)	(2,152		)
Expenditures for intangible assets	(25		)	(23		)
Purchase of available-for-sale securities							(65		)	—
Other investing activities	13			30			(57		)	(16		)
Net cash used in investing activities	(2,164		)	(2,066		)	(2,466		)	(2,168		)
Cash Flows from Financing Activities
Issuance of long-term debt	1,088			1,241			602			1,088
Retirement of long-term debt	(60		)	(905		)	(277		)	(60		)
Settlement of cross-currency swaps	—			46
Issuance of common stock	275			133			678			275
Payment of common stock dividends	(800		)	(772		)	(846		)	(800		)
Net increase (decrease) in short-term debt	269			(268		)
Net increase in short-term debt							481			269
Other financing activities	(34		)	(33		)	(20		)	(34		)
Net cash provided by (used in) financing activities	738			(558		)
Effect of Exchange Rates on Cash and Cash Equivalents	7			(26		)
Net Increase (Decrease) in Cash and Cash Equivalents	335			(420		)
Cash and Cash Equivalents at Beginning of Period	341			836
Cash and Cash Equivalents at End of Period	$	676		$	416
Net cash provided by financing activities							618			738
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash							(9		)	7
Net Increase in Cash, Cash Equivalents and Restricted Cash							353			331
Cash, Cash Equivalents and Restricted Cash at Beginning of Period							511			365
Cash, Cash Equivalents and Restricted Cash at End of Period							$	864		$	696

Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	373		$	293		$	311		$	373
Accrued expenditures for intangible assets at September 30,	$	60		$	104		$	70		$	60

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

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Assets

Current Assets
Cash and cash equivalents	$	676	$	341	$	842	$	485
Accounts receivable (less reserve: 2017, $52; 2016, $54)
Accounts receivable (less reserve: 2018, $54; 2017, $51)
Customer	617		666		684		681
Other	96		46		58		100
Unbilled revenues	405		480		411		543
Fuel, materials and supplies	323		356		295		320
Prepayments	101		63		103		66
Price risk management assets	57		63		91		49
Other current assets	56		52		61		50
Total Current Assets	2,331		2,067		2,545		2,294

Property, Plant and Equipment
Regulated utility plant	36,678		34,674		39,144		38,228
Less: accumulated depreciation - regulated utility plant	6,624		6,013		7,196		6,785
Regulated utility plant, net	30,054		28,661		31,948		31,443
Non-regulated property, plant and equipment	422		413		365		384
Less: accumulated depreciation - non-regulated property, plant and equipment	154		134		111		110
Non-regulated property, plant and equipment, net	268		279		254		274
Construction work in progress	1,494		1,134		1,816		1,375
Property, Plant and Equipment, net	31,816		30,074		34,018		33,092

Other Noncurrent Assets
Regulatory assets	1,869		1,918		1,525		1,504
Goodwill	3,134		3,060		3,242		3,258
Other intangibles	666		700		700		697
Pension benefit asset	532		9		615		284
Price risk management assets	267		336		206		215
Other noncurrent assets	143		151		191		135
Total Other Noncurrent Assets	6,611		6,174		6,479		6,093

Total Assets	$	40,758	$	38,315	$	43,042	$	41,479

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

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017			December 31, 2016			September 30, 2018			December 31, 2017
Liabilities and Equity

Current Liabilities
Short-term debt	$	1,211		$	923		$	1,549		$	1,080
Long-term debt due within one year	448			518			330			348
Accounts payable	838			820			814			924
Taxes	110			101			121			105
Interest	322			270			326			282
Dividends	272			259			287			273
Customer deposits	291			276			265			292
Regulatory liabilities	87			101			136			95
Other current liabilities	570			569			555			624
Total Current Liabilities	4,149			3,837			4,383			4,023

Long-term Debt	19,110			17,808			19,924			19,847

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	4,224			3,889			2,717			2,462
Investment tax credits	130			132			127			129
Accrued pension obligations	796			1,001			649			800
Asset retirement obligations	312			428			279			312
Regulatory liabilities	873			899			2,739			2,704
Other deferred credits and noncurrent liabilities	472			422			441			441
Total Deferred Credits and Other Noncurrent Liabilities	6,807			6,771			6,952			6,848

Commitments and Contingent Liabilities (Notes 6 and 9)
Commitments and Contingent Liabilities (Notes 7 and 10)

Equity
Common stock - $0.01 par value (a)	7			7			7			7
Additional paid-in capital	10,122			9,841			11,001			10,305
Earnings reinvested	4,066			3,829			4,423			3,871
Accumulated other comprehensive loss	(3,503		)	(3,778		)	(3,648		)	(3,422		)
Total Equity	10,692			9,899			11,783			10,761

Total Liabilities and Equity	$	40,758		$	38,315		$	43,042		$	41,479


(a)	1,560,000 shares authorized; ~~688,133~~719,702 and ~~679,731~~693,398 shares issued and outstanding at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

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

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


																Common stock shares outstanding (a)	Common stock		Additional paid-in capital			Earnings reinvested			Accumulated other comprehensive loss			Total
December 31, 2017																693,398	$	7	$	10,305		$	3,871		$	(3,422	)	$	10,761
Common stock issued																26,304			699									699
Stock-based compensation																			(3		)							(3		)
Net income																						1,412						1,412
Dividends and dividend equivalents																						(860		)				(860		)
Other comprehensive income (loss)																									(226		)	(226		)
September 30, 2018																719,702	$	7	$	11,001		$	4,423		$	(3,648	)	$	11,783
	Common stock shares outstanding (a)	Common stock		Additional paid-in capital			Earnings reinvested			Accumulated other comprehensive loss			Total
December 31, 2016	679,731	$	7	$	9,841		$	3,829		$	(3,778	)	$	9,899		679,731	$	7	$	9,841		$	3,829		$	(3,778	)	$	9,899
Common stock issued	8,402			303									303			8,402			303									303
Stock-based compensation				(22		)							(22		)				(22		)							(22		)
Net income							1,050						1,050									1,050						1,050
Dividends and dividend equivalents							(813		)				(813		)							(813		)				(813		)
Other comprehensive income (loss)										275			275												275			275
September 30, 2017	688,133	$	7	$	10,122		$	4,066		$	(3,503	)	$	10,692		688,133	$	7	$	10,122		$	4,066		$	(3,503	)	$	10,692

December 31, 2015	673,857	$	7	$	9,687		$	2,953		$	(2,728	)	$	9,919
Common stock issued	5,411			168									168
Stock-based compensation				(31		)							(31		)
Net income							1,437						1,437
Dividends and dividend equivalents							(773		)				(773		)
Other comprehensive income (loss)										(752		)	(752		)
Adoption of stock-based compensation guidance cumulative effect adjustment							7						7
September 30, 2016	679,268	$	7	$	9,824		$	3,624		$	(3,480	)	$	9,975


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

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

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016		2018		2017		2018		2017
Operating Revenues	$	547	$	539	$	1,620	$	1,619	$	548	$	547	$	1,704	$	1,620

Operating Expenses
Operation
Energy purchases	121		129		374		414		127		121		403		374
Other operation and maintenance	133		144		435		431		127		133		419		435
Depreciation	77		64		228		185		89		77		262		228
Taxes, other than income	27		26		79		79		27		27		81		79
Total Operating Expenses	358		363		1,116		1,109		370		358		1,165		1,116

Operating Income	189		176		504		510		178		189		539		504

Other Income (Expense) - net	4		4		8		12		5		4		18		8

Interest Income from Affiliate	2		—		3		—		4		2		5		3

Interest Expense	36		32		105		97		41		36		117		105

Income Before Income Taxes	159		148		410		425		146		159		445		410

Income Taxes	64		58		159		162		35		64		111		159

Net Income (a)	$	95	$	90	$	251	$	263	$	111	$	95	$	334	$	251


(a)	Net income equals comprehensive income.

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

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2018			2017
Cash Flows from Operating Activities
Net income	$	251		$	263		$	334		$	251
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	228			185			262			228
Amortization	25			19			17			25
Defined benefit plans - expense	10			9			2			10
Deferred income taxes and investment tax credits	129			151			77			129
Other	(8		)	(14		)	(13		)	(8		)
Change in current assets and current liabilities
Accounts receivable	7			(6		)	22			7
Accounts payable	(38		)	(1		)	(46		)	(38		)
Unbilled revenues	30			10			45			30
Prepayments	(31		)	29			(25		)	(31		)
Regulatory assets and liabilities, net	—			(41		)	(25		)	—
Taxes payable	10			(6		)	(1		)	10
Other	(9		)	(13		)	12			(9		)
Other operating activities
Defined benefit plans - funding	(24		)	—			(28		)	(24		)
Other assets	(2		)	15			(37		)	(2		)
Other liabilities	(3		)	(5		)	54			(3		)
Net cash provided by operating activities	575			595			650			575

Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(851		)	(739		)	(835		)	(851		)
Expenditures for intangible assets	(7		)	(3		)
Net increase in notes receivable from affiliate	(2		)	—
Net decrease in notes receivable from affiliate							—			(2		)
Other investing activities	2			2			(2		)	(5		)
Net cash used in investing activities	(858		)	(740		)	(837		)	(858		)

Cash Flows from Financing Activities
Issuance of long-term debt	470			224			398			470
Retirement of long-term debt	—			(224		)
Contributions from parent	575			200			429			575
Payment of common stock dividends to parent	(231		)	(193		)	(271		)	(231		)
Net increase (decrease) in short-term debt	(295		)	130
Net decrease in short-term debt							—			(295		)
Other financing activities	(6		)	(3		)	(4		)	(6		)
Net cash provided by financing activities	513			134			552			513

Net Increase (Decrease) in Cash and Cash Equivalents	230			(11		)
Cash and Cash Equivalents at Beginning of Period	13			47
Cash and Cash Equivalents at End of Period	$	243		$	36
Net Increase in Cash, Cash Equivalents and Restricted Cash							365			230
Cash, Cash Equivalents and Restricted Cash at Beginning of Period							51			15
Cash, Cash Equivalents and Restricted Cash at End of Period							$	416		$	245

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	190		$	166		$	171		$	190

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

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Assets

Current Assets
Cash and cash equivalents	$	243	$	13	$	414	$	49
Accounts receivable (less reserve: 2017, $25; 2016, $28)
Accounts receivable (less reserve: 2018, $26; 2017, $24)
Customer	275		272		309		279
Other	10		21		18		71
Accounts receivable from affiliates	1		—		11		—
Notes receivable from affiliate	2		—
Unbilled revenues	84		114		82		127
Materials and supplies	31		32		26		34
Prepayments	40		9		31		6
Regulatory assets	14		19		18		16
Other current assets	11		8		10		6
Total Current Assets	711		488		919		588

Property, Plant and Equipment
Regulated utility plant	10,449		9,654		11,332		10,785
Less: accumulated depreciation - regulated utility plant	2,880		2,714		2,848		2,778
Regulated utility plant, net	7,569		6,940		8,484		8,007
Construction work in progress	699		641		643		508
Property, Plant and Equipment, net	8,268		7,581		9,127		8,515

Other Noncurrent Assets
Regulatory assets	1,073		1,094		738		709
Intangibles	256		251		260		259
Other noncurrent assets	15		12		52		11
Total Other Noncurrent Assets	1,344		1,357		1,050		979

Total Assets	$	10,323	$	9,426	$	11,096	$	10,082

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

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Liabilities and Equity

Current Liabilities
Short-term debt	$	—	$	295
Long-term debt due within one year	—		224
Accounts payable	397		367		$	384	$	386
Accounts payable to affiliates	38		42		25		31
Taxes	22		12		7		8
Interest	38		34		43		36
Regulatory liabilities	72		83		72		86
Other current liabilities	90		101		99		98
Total Current Liabilities	657		1,158		630		645

Long-term Debt	3,298		2,607		3,693		3,298

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	2,036		1,899		1,258		1,154
Accrued pension obligations	257		281		210		246
Regulatory liabilities					686		668
Other deferred credits and noncurrent liabilities	89		90		135		79
Total Deferred Credits and Other Noncurrent Liabilities	2,382		2,270		2,289		2,147

Commitments and Contingent Liabilities (Notes 6 and 9)
Commitments and Contingent Liabilities (Notes 7 and 10)

Equity
Common stock - no par value (a)	364		364		364		364
Additional paid-in capital	2,729		2,154		3,158		2,729
Earnings reinvested	893		873		962		899
Total Equity	3,986		3,391		4,484		3,992

Total Liabilities and Equity	$	10,323	$	9,426	$	11,096	$	10,082


(a)	170,000 shares authorized; 66,368 shares issued and outstanding at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

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

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total			Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
December 31, 2017												66,368	$	364	$	2,729	$	899		$	3,992
Net income																	334			334
Capital contributions from parent															429					429
Dividends declared on common stock																	(271		)	(271		)
September 30, 2018												66,368	$	364	$	3,158	$	962		$	4,484

December 31, 2016	66,368	$	364	$	2,154	$	873		$	3,391		66,368	$	364	$	2,154	$	873		$	3,391
Net income						251			251								251			251
Capital contributions from PPL				575					575
Capital contributions from parent															575					575
Dividends declared on common stock						(231		)	(231		)						(231		)	(231		)
September 30, 2017	66,368	$	364	$	2,729	$	893		$	3,986		66,368	$	364	$	2,729	$	893		$	3,986

December 31, 2015	66,368	$	364	$	1,934	$	821		$	3,119
Net income						263			263
Capital contributions from PPL				200					200
Dividends declared on common stock						(193		)	(193		)
September 30, 2016	66,368	$	364	$	2,134	$	891		$	3,389


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

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

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended September 30,					Nine Months Ended September 30,
	2017		2016			2017			2016			2018		2017			2018			2017
Operating Revenues	$	818	$	835		$	2,350		$	2,382		$	802	$	818		$	2,417		$	2,350

Operating Expenses
Operation
Fuel	202		227			576			607			206		202			609			576
Energy purchases	22		24			120			118			22		22			135			120
Other operation and maintenance	199		197			598			603			216		197			632			594
Depreciation	114		102			324			301			119		114			354			324
Taxes, other than income	17		16			49			46			18		17			53			49
Total Operating Expenses	554		566			1,667			1,675			581		552			1,783			1,663

Operating Income	264		269			683			707			221		266			634			687

Other Income (Expense) - net	1		(3		)	(5		)	(9		)	—		(1		)	(2		)	(9		)

Interest Expense	49		50			148			147			52		49			154			148

Interest Expense with Affiliate	5		4			13			12			7		5			18			13

Income Before Income Taxes	211		212			517			539			162		211			460			517

Income Taxes	79		79			195			202			32		79			102			195

Net Income	$	132	$	133		$	322		$	337		$	130	$	132		$	358		$	322

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

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended September 30,					Nine Months Ended September 30,
	2017			2016		2017			2016			2018		2017			2018		2017
Net income	$	132		$	133	$	322		$	337		$	130	$	132		$	358	$	322

Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Defined benefit plans:
Net actuarial gain (loss), net of tax of $0, $0, $7, ($1)	(1		)	—		(12		)	1
Net actuarial gain (loss), net of tax of $0, $0, $0, $7												—		(1		)	—		(12		)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0, $0	—			—		1			(1		)	—		—			—		1
Defined benefit plans:
Prior service costs, net of tax of ($1), ($1), ($1), ($1)	—			—		1			1
Net actuarial loss, net of tax of $0, $0, ($2), ($1)	1			1		3			3
Prior service costs, net of tax of $0, ($1), $0, ($1)												1		—			2		1
Net actuarial (gain) loss, net of tax of $0, $0, ($1), ($2)												1		1			2		3
Total other comprehensive income (loss)	—			1		(7		)	4			2		—			4		(7		)

Comprehensive income	$	132		$	134	$	315		$	341		$	132	$	132		$	362	$	315

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

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2018			2017
Cash Flows from Operating Activities
Net income	$	322		$	337		$	358		$	322
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	324			301			354			324
Amortization	19			21			13			19
Defined benefit plans - expense	19			20			12			19
Deferred income taxes and investment tax credits	173			212			71			173
Other	1			—			(2		)	1
Change in current assets and current liabilities
Accounts receivable	18			(43		)	8			18
Accounts payable	(30		)	7			4			(30		)
Accounts payable to affiliates	3			4			7			3
Unbilled revenues	19			6			54			19
Fuel, materials and supplies	34			7			17			34
Regulatory assets and liabilities, net							62			(3		)
Taxes payable	13			—			(11		)	13
Accrued interest	41			42			41			41
Other	(1		)	(4		)	(36		)	2
Other operating activities
Defined benefit plans - funding	(32		)	(82		)	(126		)	(32		)
Expenditures for asset retirement obligations	(22		)	(15		)	(46		)	(22		)
Other assets	5			1			(1		)	5
Other liabilities	14			2			8			14
Net cash provided by operating activities	920			816			787			920
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(579		)	(600		)	(826		)	(579		)
Other investing activities	4			1			1			4
Net cash used in investing activities	(575		)	(599		)	(825		)	(575		)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate	(4		)	84			(145		)	(4		)
Issuance of long-term debt with affiliate							250			—
Issuance of long-term debt	60			221			118			60
Retirement of long-term debt	(60		)	(221		)	(27		)	(60		)
Net increase (decrease) in short-term debt	5			(130		)
Debt issuance and credit facility costs	(3		)	(3		)
Distributions to member	(316		)	(224		)	(217		)	(316		)
Contributions from member	—			37
Net cash used in financing activities	(318		)	(236		)
Net increase in short-term debt							60			5
Other financing activities							(2		)	(3		)
Net cash provided by (used in) financing activities							37			(318		)
Net Increase (Decrease) in Cash and Cash Equivalents	27			(19		)	(1		)	27
Cash and Cash Equivalents at Beginning of Period	13			30			30			13
Cash and Cash Equivalents at End of Period	$	40		$	11		$	29		$	40

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	142		$	86		$	108		$	142

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

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Assets

Current Assets
Cash and cash equivalents	$	40	$	13	$	29	$	30
Accounts receivable (less reserve: 2017, $25; 2016, $24)
Accounts receivable (less reserve: 2018, $26; 2017, $25)
Customer	215		235		230		246
Other	43		17		47		44
Accounts receivable from affiliates	1		—
Unbilled revenues	151		170		149		203
Fuel, materials and supplies	264		297		238		254
Prepayments	27		24		32		25
Regulatory assets	20		20		11		18
Other current assets	8		4		7		8
Total Current Assets	769		780		743		828

Property, Plant and Equipment
Regulated utility plant	12,906		12,746		13,438		13,187
Less: accumulated depreciation - regulated utility plant	1,685		1,465		2,031		1,785
Regulated utility plant, net	11,221		11,281		11,407		11,402
Construction work in progress	574		317		1,000		627
Property, Plant and Equipment, net	11,795		11,598		12,407		12,029

Other Noncurrent Assets
Regulatory assets	796		824		787		795
Goodwill	996		996		996		996
Other intangibles	88		95		80		86
Other noncurrent assets	71		78		75		68
Total Other Noncurrent Assets	1,951		1,993		1,938		1,945

Total Assets	$	14,515	$	14,371	$	15,088	$	14,802

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

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Liabilities and Equity

Current Liabilities
Short-term debt	$	190	$	185	$	304	$	244
Long-term debt due within one year	98		194		330		98
Notes payable with affiliate	159		163
Notes payable with affiliates					80		225
Accounts payable	283		251		271		338
Accounts payable to affiliates	8		6		14		7
Customer deposits	57		56		60		58
Taxes	52		39		55		66
Price risk management liabilities	5		4		4		4
Regulatory liabilities	15		18		64		9
Interest	73		32		73		32
Asset retirement obligations	94		60		86		85
Other current liabilities	125		119		127		161
Total Current Liabilities	1,159		1,127		1,468		1,327

Long-term Debt

Long-term debt	4,570		4,471		4,521		4,661
Long-term debt to affiliate	400		400		650		400
Total Long-term Debt	4,970		4,871		5,171		5,061

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,909		1,735		922		866
Investment tax credits	130		132		127		129
Price risk management liabilities					15		22
Accrued pension obligations	345		350		256		365
Asset retirement obligations	261		373		231		271
Regulatory liabilities	873		899		2,053		2,036
Price risk management liabilities	24		27
Other deferred credits and noncurrent liabilities	178		190		137		162
Total Deferred Credits and Other Noncurrent Liabilities	3,720		3,706		3,741		3,851

Commitments and Contingent Liabilities (Notes 6 and 9)
Commitments and Contingent Liabilities (Notes 7 and 10)

Member's Equity	4,666		4,667		4,708		4,563

Total Liabilities and Equity	$	14,515	$	14,371	$	15,088	$	14,802

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

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


				Member's Equity
December 31, 2017				$	4,563
Net income				358
Distributions to member				(217		)
Other comprehensive income				4
September 30, 2018				$	4,708
	Member's Equity
December 31, 2016	$	4,667		$	4,667
Net income	322			322
Distributions to member	(316		)	(316		)
Other comprehensive income	(7		)
Other comprehensive income (loss)				(7		)
September 30, 2017	$	4,666		$	4,666

December 31, 2015	$	4,517
Net income	337
Contributions from member	37
Distributions to member	(224		)
Other comprehensive income	4
September 30, 2016	$	4,671

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

Table of Contents

THIS PAGE INTENTIONALLY LEFT BLANK.

Table of Contents

CONDENSED STATEMENTS OF INCOME

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016			2018			2017			2018			2017
Operating Revenues
Retail and wholesale	$	361		$	366		$	1,055		$	1,058		$	357		$	361		$	1,095		$	1,055
Electric revenue from affiliate	2			2			23			19			5			2			21			23
Total Operating Revenues	363			368			1,078			1,077			362			363			1,116			1,078

Operating Expenses
Operation
Fuel	76			86			225			233			83			76			234			225
Energy purchases	18			19			107			104			17			18			121			107
Energy purchases from affiliate	3			5			8			10			2			3			10			8
Other operation and maintenance	89			85			262			264			95			87			277			258
Depreciation	47			43			136			126			49			47			146			136
Taxes, other than income	8			9			25			24			9			8			27			25
Total Operating Expenses	241			247			763			761			255			239			815			759

Operating Income	122			121			315			316			107			124			301			319

Other Income (Expense) - net	(1		)	(1		)	(2		)	(6		)	(3		)	(3		)	(5		)	(6		)

Interest Expense	17			18			53			53			20			17			57			53

Income Before Income Taxes	104			102			260			257			84			104			239			260

Income Taxes	39			39			99			98			18			39			51			99

Net Income (a)	$	65		$	63		$	161		$	159		$	66		$	65		$	188		$	161


(a)	Net income equals comprehensive income.

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

Table of Contents

CONDENSED STATEMENTS OF CASH FLOWS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2018			2017
Cash Flows from Operating Activities
Net income	$	161		$	159		$	188		$	161
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	136			126			146			136
Amortization	11			10			10			11
Defined benefit plans - expense	5			6			2			5
Deferred income taxes and investment tax credits	96			117			46			96
Change in current assets and current liabilities
Accounts receivable	12			(17		)	14			12
Accounts receivable from affiliates	6			(11		)	2			6
Accounts payable	(12		)	24			14			(12		)
Accounts payable to affiliates	(10		)	(6		)	(2		)	(10		)
Unbilled revenues	11			10			30			11
Fuel, materials and supplies	6			11			9			6
Regulatory assets and liabilities, net							24			(2		)
Taxes payable	(15		)	—			4			(15		)
Accrued interest	12			13			13			12
Other	6			1			(14		)	8
Other operating activities
Defined benefit plans - funding	(3		)	(45		)	(59		)	(3		)
Expenditures for asset retirement obligations	(13		)	(11		)	(17		)	(13		)
Other assets	5			(3		)	—			5
Other liabilities	4			(1		)	—			4
Net cash provided by operating activities	418			383			410			418
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(293		)	(343		)	(420		)	(293		)
Net cash used in investing activities	(293		)	(343		)	(420		)	(293		)
Cash Flows from Financing Activities
Net increase in notes payable with affiliates	10			—			—			10
Issuance of long-term debt	60			125			100			60
Retirement of long-term debt	(60		)	(125		)	—			(60		)
Net increase (decrease) in short-term debt	21			(14		)	(23		)	21
Debt issuance and credit facility costs	(2		)	(1		)
Payment of common stock dividends to parent	(150		)	(87		)	(113		)	(150		)
Contributions from parent	—			47			43			—
Net cash used in financing activities	(121		)	(55		)
Other financing activities							(1		)	(2		)
Net cash provided by (used in) financing activities							6			(121		)
Net Increase (Decrease) in Cash and Cash Equivalents	4			(15		)	(4		)	4
Cash and Cash Equivalents at Beginning of Period	5			19			15			5
Cash and Cash Equivalents at End of Period	$	9		$	4		$	11		$	9

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	83		$	46		$	51		$	83

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

Table of Contents

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Assets

Current Assets
Cash and cash equivalents	$	9	$	5	$	11	$	15
Accounts receivable (less reserve: 2017, $1; 2016, $2)
Accounts receivable (less reserve: 2018, $1; 2017, $1)
Customer	96		109		102		116
Other	14		11		13		13
Unbilled revenues					61		91
Accounts receivable from affiliates	22		28		22		24
Unbilled revenues	64		75
Fuel, materials and supplies	137		143		122		131
Prepayments	15		12		14		11
Regulatory assets	11		9		11		12
Other current assets	2		1		3		3
Total Current Assets	370		393		359		416

Property, Plant and Equipment
Regulated utility plant	5,447		5,357		5,684		5,587
Less: accumulated depreciation - regulated utility plant	575		498		707		614
Regulated utility plant, net	4,872		4,859		4,977		4,973
Construction work in progress	279		133		520		305
Property, Plant and Equipment, net	5,151		4,992		5,497		5,278

Other Noncurrent Assets
Regulatory assets	413		450		400		411
Goodwill	389		389		389		389
Other intangibles	54		59		49		53
Other noncurrent assets	13		17		27		12
Total Other Noncurrent Assets	869		915		865		865

Total Assets	$	6,390	$	6,300	$	6,721	$	6,559

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

Table of Contents

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Liabilities and Equity

Current Liabilities
Short-term debt	$	190	$	169	$	176	$	199
Long-term debt due within one year	98		194		234		98
Notes payable with affiliate	10		—
Accounts payable	166		148		152		179
Accounts payable to affiliates	17		26		22		23
Customer deposits	27		27		28		27
Taxes	25		40		29		25
Price risk management liabilities	5		4		4		4
Regulatory liabilities	5		5		26		3
Interest	23		11		24		11
Asset retirement obligations	33		41		21		24
Other current liabilities	46		36		39		52
Total Current Liabilities	645		701		755		645

Long-term Debt	1,521		1,423		1,574		1,611

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,073		974		611		572
Investment tax credits	36		36		35		35
Price risk management liabilities					15		22
Accrued pension obligations	47		53		—		45
Asset retirement obligations	85		104		86		97
Regulatory liabilities	388		419		920		919
Price risk management liabilities	24		27
Other deferred credits and noncurrent liabilities	84		87		80		86
Total Deferred Credits and Other Noncurrent Liabilities	1,737		1,700		1,747		1,776

Commitments and Contingent Liabilities (Notes 6 and 9)
Commitments and Contingent Liabilities (Notes 7 and 10)

Stockholder's Equity
Common stock - no par value (a)	424		424		424		424
Additional paid-in capital	1,682		1,682		1,755		1,712
Earnings reinvested	381		370		466		391
Total Equity	2,487		2,476		2,645		2,527

Total Liabilities and Equity	$	6,390	$	6,300	$	6,721	$	6,559


(a)	75,000 shares authorized; 21,294 shares issued and outstanding at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

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

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CONDENSED STATEMENTS OF EQUITY

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


												Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
December 31, 2017												21,294	$	424	$	1,712	$	391		$	2,527
Net income																	188			188
Capital contributions from parent															43					43
Cash dividends declared on common stock																	(113		)	(113		)
September 30, 2018												21,294	$	424	$	1,755	$	466		$	2,645
	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
December 31, 2016	21,294	$	424	$	1,682	$	370		$	2,476		21,294	$	424	$	1,682	$	370		$	2,476
Net income						161			161								161			161
Cash dividends declared on common stock						(150		)	(150		)						(150		)	(150		)
September 30, 2017	21,294	$	424	$	1,682	$	381		$	2,487		21,294	$	424	$	1,682	$	381		$	2,487

December 31, 2015	21,294	$	424	$	1,611	$	295		$	2,330
Net income						159			159
Capital contributions from LKE				47					47
Cash dividends declared on common stock						(87		)	(87		)
September 30, 2016	21,294	$	424	$	1,658	$	367		$	2,449


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

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

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CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016			2017			2016			2018		2017		2018		2017
Operating Revenues
Retail and wholesale	$	457	$	469		$	1,295		$	1,324		$	445	$	457	$	1,322	$	1,295
Electric revenue from affiliate	3		5			8			10			2		3		10		8
Total Operating Revenues	460		474			1,303			1,334			447		460		1,332		1,303

Operating Expenses
Operation
Fuel	126		141			351			374			123		126		375		351
Energy purchases	4		5			13			14			5		4		14		13
Energy purchases from affiliate	2		2			23			19			5		2		21		23
Other operation and maintenance	104		107			313			320			114		104		331		312
Depreciation	67		59			188			175			70		67		208		188
Taxes, other than income	9		7			24			22			9		9		26		24
Total Operating Expenses	312		321			912			924			326		312		975		911

Operating Income	148		153			391			410			121		148		357		392

Other Income (Expense) - net	—		(3		)	(3		)	(4		)	1		—		1		(4		)

Interest Expense	24		24			72			71			24		24		74		72

Income Before Income Taxes	124		126			316			335			98		124		284		316

Income Taxes	47		48			120			128			21		47		59		120

Net Income (a)	$	77	$	78		$	196		$	207		$	77	$	77	$	225	$	196


(a)	Net income approximates comprehensive income.

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

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CONDENSED STATEMENTS OF CASH FLOWS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2018			2017
Cash Flows from Operating Activities
Net income	$	196		$	207		$	225		$	196
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	188			175			208			188
Amortization	7			10			2			7
Defined benefit plans - expense	3			4			—			3
Deferred income taxes and investment tax credits	116			122			37			116
Other	—			(1		)	(2		)	—
Change in current assets and current liabilities
Accounts receivable	6			(24		)	2			6
Accounts receivable from affiliates	(1		)	—			—			(1		)
Accounts payable	(6		)	(11		)	(2		)	(6		)
Accounts payable to affiliates	(16		)	2			(8		)	(16		)
Unbilled revenues	8			(4		)	24			8
Fuel, materials and supplies	28			(4		)	8			28
Regulatory assets and liabilities, net							38			(1		)
Taxes payable	(21		)	—			11			(21		)
Accrued interest	22			22			21			22
Other	(6		)	2			(4		)	(5		)
Other operating activities
Defined benefit plans - funding	(22		)	(19		)	(53		)	(22		)
Expenditures for asset retirement obligations	(9		)	(4		)	(29		)	(9		)
Other assets	—			(4		)	(1		)	—
Other liabilities	8			(4		)	8			8
Net cash provided by operating activities	501			469			485			501
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(283		)	(255		)	(405		)	(283		)
Net increase in notes receivable with affiliates	(10		)	—			—			(10		)
Other investing activities	4			1			1			4
Net cash used in investing activities	(289		)	(254		)	(404		)	(289		)
Cash Flows from Financing Activities
Issuance of long-term debt	—			96			18			—
Retirement of long-term debt	—			(96		)	(27		)	—
Net decrease in short-term debt	(16		)	(41		)
Debt issuance and credit facility costs	(1		)	(1		)
Net increase (decrease) in short-term debt							83			(16		)
Payment of common stock dividends to parent	(171		)	(197		)	(196		)	(171		)
Contributions from parent	—			20			45			—
Other financing activities							(1		)	(1		)
Net cash used in financing activities	(188		)	(219		)	(78		)	(188		)
Net Increase (Decrease) in Cash and Cash Equivalents	24			(4		)
Net Increase in Cash and Cash Equivalents							3			24
Cash and Cash Equivalents at Beginning of Period	7			11			15			7
Cash and Cash Equivalents at End of Period	$	31		$	7		$	18		$	31

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	58		$	40		$	57		$	58

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

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CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Assets

Current Assets
Cash and cash equivalents	$	31	$	7	$	18	$	15
Accounts receivable (less reserve: 2017, $1; 2016, $2)
Accounts receivable (less reserve: 2018, $2; 2017, $1)
Customer	119		126		128		130
Other	28		5		25		30
Accounts receivable from affiliates	1		—
Notes receivable from affiliate	10		—
Unbilled revenues	87		95		88		112
Fuel, materials and supplies	127		154		116		123
Prepayments	14		12		17		14
Regulatory assets	9		11		—		6
Other current assets	6		3		4		5
Total Current Assets	432		413		396		435

Property, Plant and Equipment
Regulated utility plant	7,452		7,382		7,746		7,592
Less: accumulated depreciation - regulated utility plant	1,110		965		1,323		1,170
Regulated utility plant, net	6,342		6,417		6,423		6,422
Construction work in progress	293		181		479		321
Property, Plant and Equipment, net	6,635		6,598		6,902		6,743

Other Noncurrent Assets
Regulatory assets	383		374		387		384
Goodwill	607		607		607		607
Other intangibles	34		36		31		33
Other noncurrent assets	55		57		77		52
Total Other Noncurrent Assets	1,079		1,074		1,102		1,076

Total Assets	$	8,146	$	8,085	$	8,400	$	8,254

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

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CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2017		December 31, 2016			September 30, 2018		December 31, 2017
Liabilities and Equity

Current Liabilities
Short-term debt	$	—	$	16		$	128	$	45
Long-term debt due within one year						96		—
Accounts payable	105		78			105		137
Accounts payable to affiliates	42		56			47		53
Customer deposits	30		29			32		31
Taxes	24		45			30		19
Regulatory liabilities	10		13			38		6
Interest	38		16			37		16
Asset retirement obligations	61		19			65		61
Other current liabilities	35		36			43		46
Total Current Liabilities	345		308			621		414

Long-term Debt	2,328		2,327			2,224		2,328

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,289		1,170			719		691
Investment tax credits	94		96			92		94
Accrued pension obligations	37		62			—		36
Asset retirement obligations	176		269			145		174
Regulatory liabilities	485		480			1,133		1,117
Other deferred credits and noncurrent liabilities	43		50			35		43
Total Deferred Credits and Other Noncurrent Liabilities	2,124		2,127			2,124		2,155

Commitments and Contingent Liabilities (Notes 6 and 9)
Commitments and Contingent Liabilities (Notes 7 and 10)

Stockholder's Equity
Common stock - no par value (a)	308		308			308		308
Additional paid-in capital	2,616		2,616			2,661		2,616
Accumulated other comprehensive loss	—		(1		)
Earnings reinvested	425		400			462		433
Total Equity	3,349		3,323			3,431		3,357

Total Liabilities and Equity	$	8,146	$	8,085		$	8,400	$	8,254


(a)	80,000 shares authorized; 37,818 shares issued and outstanding at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

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

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CONDENSED STATEMENTS OF EQUITY

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


															Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Accumulated other comprehensive income (loss)			Total
December 31, 2017															37,818	$	308	$	2,616	$	433		$	—		$	3,357
Capital contributions from parent																		45								45
Net income																				225						225
Cash dividends declared on common stock																				(196		)				(196		)
September 30, 2018															37,818	$	308	$	2,661	$	462		$	—		$	3,431
	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Accumulated other comprehensive loss			Total
December 31, 2016	37,818	$	308	$	2,616	$	400		$	(1	)	$	3,323		37,818	$	308	$	2,616	$	400		$	(1	)	$	3,323
Net income						196						196								196						196
Cash dividends declared on common stock						(171		)				(171		)						(171		)				(171		)
Other comprehensive income									1			1											1			1
September 30, 2017	37,818	$	308	$	2,616	$	425		$	—		$	3,349		37,818	$	308	$	2,616	$	425		$	—		$	3,349

December 31, 2015	37,818	$	308	$	2,596	$	383		$	—		$	3,287
Capital contributions from LKE				20								20
Net income						207						207
Cash dividends declared on common stock						(197		)				(197		)
Other comprehensive income (loss)									(1		)	(1		)
September 30, 2016	37,818	$	308	$	2,616	$	393		$	(1	)	$	3,316


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

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

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Combined Notes to Condensed Financial Statements (Unaudited)

1. Interim Financial Statements

(All Registrants)

Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrants' related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant.

The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, ~~2016~~2017 is derived from that Registrant's ~~2016~~2017 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's ~~2016~~2017 Form 10-K. The results of operations for the three and nine months ended September 30, ~~2017~~2018 are not necessarily indicative of the results to be expected for the full year ending December 31, ~~2017~~2018 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

2. Summary of Significant Accounting Policies

(~~PPL and PPL Electric)~~All Registrants)

The following accounting policy disclosures represent updates to Note 1 in each ~~indicated~~ Registrant's ~~2016~~2017 Form 10-K and should be read in conjunction with those disclosures.

~~Accounts Receivable~~Income Taxes

The Registrants recognized certain provisional amounts relating to the impact of the enactment of the TCJA in their December 31, 2017 financial statements, in accordance with SEC guidance. Included in those provisional amounts were estimates of: tax depreciation, deductible executive compensation, accumulated foreign earnings, foreign tax credits, and deemed dividends from foreign subsidiaries, all of which were based on the interpretation and application of various provisions of the TCJA.

In ~~accordance with a PUC-approved purchase~~the third quarter of ~~accounts receivable program,~~2018, PPL ~~Electric purchases certain accounts receivable~~filed its consolidated federal income tax return, which was prepared using guidance issued by the U.S. Treasury Department and the IRS since the filing of each Registrant’s 2017 Form 10-K. Accordingly, the Registrants have updated the following provisional amounts and now consider them to be complete: (1) the amount of the deemed dividend and associated foreign tax credits relating to the transition tax imposed on accumulated foreign earnings as of December 31, 2017; (2) the amount of accelerated 100% “bonus” depreciation PPL is eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction 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 value35% to 21% on the ~~date~~changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of ~~acquisition. During~~PPL's U.S. regulated operations. See Note 6 to the Financial Statements for the final amounts reported in PPL's 2017 federal income tax return, provisional adjustment amounts for the year ended December 31, 2017, the related measurement period adjustments and the resulting tax impact for the three and nine months ended September 30, 2018.

The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 is complete as of September 30, 2018 with respect to the three items discussed above. The Registrants continue to analyze the impact of the TCJA on the deductibility of executive compensation awarded on or before November 2, 2017. The Registrants do not currently anticipate a material change from what was reflected in the December 31, 2017 financial statements and expect to record the impact, if any, of changes in the deductibility of executive compensation in the fourth quarter of 2018.

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New Accounting Guidance Adopted

Accounting for Revenue from Contracts with Customers

Effective January 1, 2018, the Registrants adopted accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers. This model is based on the core principle that revenue should be recognized to depict the transfer of control of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Registrants adopted this guidance using the modified retrospective transition method. No cumulative effect adjustment was required as of the January 1, 2018 adoption date.

The adoption of this guidance did not have a material impact on the Registrants' revenue recognition policies. See Note 4 for the required disclosures resulting from the adoption of this standard.

Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost

Effective January 1, 2018, the Registrants adopted accounting guidance that changes the income statement presentation of net periodic benefit cost. Retrospectively, this guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during the period. The other components of net periodic benefits are presented separately from the line items that include the service cost and outside of any subtotal of operating income. Prospectively, the guidance limits the capitalization to the service cost component of net periodic benefit costs.

For PPL, ~~Electric purchased $324 million and $968 million~~the non-service cost components of ~~accounts receivable from alternative energy suppliers. During~~net periodic benefit costs were in a net credit position for the three and nine months ended September 30, ~~2016,~~2018. The non-service cost credits that would have been capitalized under previous guidance, but are now recorded as income within "Other Income (Expense) - net," were $5 million ($4 million after-tax or $0.01 per share) and $16 million ($13 million after-tax or $0.02 per share) for the three and nine months ended September 30, 2018. For PPL Electric, ~~purchased $365 million~~LG&E and ~~$1.0 billion of accounts receivable from alternative electricity suppliers.~~KU, non-service costs or credits that would have been capitalized under previous guidance are now recognized as a regulatory asset or regulatory liability, as applicable, in accordance with regulatory approvals.

The following provides the non-service cost components of net periodic benefits (costs) or credits presented in "Other Income (Expense) - net" in 2018 and reclassified from "Other operation and maintenance" to "Other Income (Expense) - net" in 2017 on the Statements of Income as a result of the adoption.



	Three Months					Nine Months
	2018		2017			2018			2017
PPL	$	61	$	41		$	195		$	123
PPL Electric	1		—			4			—
LKE	1		(2		)	3			(4		)
LG&E	—		(2		)	(1		)	(4		)
KU	—		—			2			(1		)

PPL and PPL Electric elected to use the practical expedient that permits using the amounts disclosed in the defined benefit plan note for the prior comparative period as the estimation basis for applying the retrospective presentation requirements.

Presentation of Restricted Cash in the Statement of Cash Flows(PPL and PPL Electric)

Effective January 1, 2018, PPL and PPL Electric adopted accounting guidance that changes the cash flow statement presentation of restricted cash. Under the new guidance, amounts considered restricted cash are presented with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total cash amounts on the Statements of Cash Flows. The guidance requires a reconciliation of the total cash, cash equivalents and restricted cash from the Statement of Cash Flows to amounts on the Balance Sheets and disclosure of the nature of the restrictions. PPL and PPL Electric have applied this guidance on a retrospective basis for all periods presented. The adoption of this guidance did not have a material impact on the Statements of Cash Flows.

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Reconciliation of Cash, Cash Equivalents and Restricted Cash

The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows:



	PPL				PPL Electric
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Cash and cash equivalents	$	842	$	485	$	414	$	49
Restricted cash - current (a)	3		3		2		2
Restricted cash - noncurrent (a)	19		23		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	864	$	511	$	416	$	51


(a)	Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."

3. Segment and Related Information

(PPL)

See Note 2 in PPL's ~~2016~~2017 Form 10-K for a discussion of reportable segments and related information.

Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended September 30 are as follows:


	Three Months					Nine Months						Three Months					Nine Months
	2017		2016			2017			2016			2018			2017		2018			2017
Income Statement Data
Revenues from external customers
Operating Revenues from external customers
U.K. Regulated	$	477	$	515		$	1,547		$	1,673		$	517		$	477	$	1,716		$	1,547
Kentucky Regulated	818		835			2,350			2,382			802			818		2,417			2,350
Pennsylvania Regulated	547		539			1,620			1,619			548			547		1,704			1,620
Corporate and Other	3		—			4			11			5			3		9			4
Total	$	1,845	$	1,889		$	5,521		$	5,685		$	1,872		$	1,845	$	5,846		$	5,521

Net Income
U.K. Regulated (a)	$	126	$	281		$	560		$	915		$	245		$	126	$	836		$	560
Kentucky Regulated	125		126			299			314			122			125		332			299
Pennsylvania Regulated	95		91			251			263			112			95		335			251
Corporate and Other	9		(25		)	(60		)	(55		)	(34		)	9		(91		)	(60		)
Total	$	355	$	473		$	1,050		$	1,437		$	445		$	355	$	1,412		$	1,050


(a)	Includes unrealized gains and losses from hedging ~~foreign-currency related~~foreign currency economic activity. See Note 1314 for additional information.

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


	September 30, 2017		December 31, 2016		September 30, 2018		December 31, 2017
Balance Sheet Data
Assets
U.K. Regulated (a)	$	16,052	$	14,537	$	16,823	$	16,813
Kentucky Regulated	14,181		14,037		14,754		14,468
Pennsylvania Regulated	10,323		9,426		11,110		10,082
Corporate and Other (b)	202		315		355		116
Total	$	40,758	$	38,315	$	43,042	$	41,479


(a)	Includes ~~$11.7~~$12.4 billion and ~~$10.8~~$12.5 billion of net PP&E as of September 30, ~~2017~~2018 and December 31, ~~2016.~~2017. WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP.


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

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(PPL Electric, LKE, LG&E and KU)

PPL Electric has two operating segments that are aggregated into a single reportable segment. LKE, LG&E and KU are individually single operating and reportable segments.

4. 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.

4.U.K. Regulated Segment Revenue(PPL)

The U.K. Regulated Segment generates revenues from contracts with customers primarily from WPD’s DUoS operations.

DUoS revenues result from WPD charging licensed third-party energy suppliers for their use of WPD’s distribution systems to deliver energy to their customers. WPD satisfies its performance obligation and DUoS revenue is recognized over-time as electricity is delivered. The amount of revenue recognized is based on actual and forecasted volumes of electricity delivered during the period multiplied by a per-unit energy tariff, plus fixed charges. This method of recognition fairly presents WPD's transfer of electric service to the customer as the calculation is based on volumes, and the tariff rate is set by WPD using a methodology prescribed by Ofgem. Customers are billed monthly and outstanding amounts are typically due within 14 days of the invoice date.

DUoS customers are “at will” customers of WPD 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 WPD’s DUoS contracts.

Pennsylvania Regulated Segment Revenue(PPL and PPL Electric)

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 a per-unit of energy 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 per-unit of energy tariff rate and the monthly fixed charge are set by the PUC. Customers are typically billed monthly and outstanding amounts are typically 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.

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.

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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.

Kentucky Regulated Segment Revenue(PPL, LKE, LG&E and KU)

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 tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended September 30, 2018.



	Three Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,872		$	548		$	802		$	362		$	447
Revenues derived from:
Alternative revenue programs (b)	(4		)	(3		)	(1		)	(4		)	3
Other (c)	(15		)	(3		)	(5		)	(2		)	(3		)
Revenues from Contracts with Customers	$	1,853		$	542		$	796		$	356		$	447



	Nine Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	5,846		$	1,704		$	2,417		$	1,116		$	1,332
Revenues derived from:
Alternative revenue programs (b)	37			(1		)	38			16			22
Other (c)	(43		)	(9		)	(14		)	(5		)	(9		)
Revenues from Contracts with Customers	$	5,840		$	1,694		$	2,441		$	1,127		$	1,345


(a)	PPL includes $517 million and $1.7 billion for the three and nine months ended September 30, 2018 of revenues from external customers reported by the U.K. Regulated segment. PPL Electric and LKE represent revenues from external customers reported by the Pennsylvania Regulated and Kentucky Regulated segments. See Note 3 for additional information.


(b)	Alternative revenue programs for PPL Electric include the over/under-collection of its transmission formula rate. Alternative revenue programs for LKE, LG&E and KU include the over/under collection for the ECR and DSM programs as well as LG&E's over/under collection of its GLT program and KU's

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over/under collection of its generation formula rate. Over-collections of revenue are shown as positive amounts in the table above; under-collections are shown as negative amounts.


(c)	Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues.

As discussed in Note 2 in PPL's 2017 Form 10-K, PPL's segments are segmented by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the table above. For PPL Electric, revenues from contracts with customers are further disaggregated by distribution and transmission, which were $442 million and $100 million for the three months ended September 30, 2018 and $1.4 billion and $306 million for the nine months ended September 30, 2018.

The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended September 30, 2018.



	Three Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	475	$	—	$	—	$	—	$	—
Residential	647		328		319		162		157
Commercial	307		88		219		112		107
Industrial	156		12		144		45		99
Other (b)	119		14		65		27		39
Wholesale - municipal	30		—		30		—		30
Wholesale - other (c)	19		—		19		10		15
Transmission	100		100		—		—		—
Revenues from Contracts with Customers	$	1,853	$	542	$	796	$	356	$	447



	Nine Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,606	$	—	$	—	$	—	$	—
Residential	2,039		1,036		1,003		505		498
Commercial	928		275		653		343		310
Industrial	466		37		429		134		295
Other (b)	339		40		200		88		113
Wholesale - municipal	91		—		91		—		91
Wholesale - other (c)	65		—		65		57		38
Transmission	306		306		—		—		—
Revenues from Contracts with Customers	$	5,840	$	1,694	$	2,441	$	1,127	$	1,345


(a)	Represents customers of WPD.


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


(c)	Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE.

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

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The following table shows the accounts receivable balances that were impaired for the periods ended September 30, 2018.



	Three Months		Nine Months
PPL	$	11	$	24
PPL Electric	7		17
LKE	4		7
LG&E	2		3
KU	2		4

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



	PPL		PPL Electric		LKE		LG&E		KU
Contract liabilities as of December 31, 2017	$	29	$	19	$	8	$	4	$	4
Contract liabilities as of September 30, 2018	40		17		8		4		4

The following table shows the revenue recognized during the period ended September 30, 2018 that was included in the contract liability balance at December 31, 2017.



	Nine Months
PPL	$	22
PPL Electric	8
LKE	8
LG&E	4
KU	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 September 30, 2018, PPL had $65 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $44 million within the next 12 months.

5. Earnings Per Share

(PPL)

Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by 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.

~~Table~~ In 2018, these securities also included the PPL common stock forward sale agreements. See Note 8 for additional information on these agreements. The forward sale agreements are dilutive under the Treasury Stock Method to the extent the average stock price of ~~Contents~~

PPL's common shares exceeds the forward sale price prescribed in the agreements.

Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended September 30 used in the EPS calculation are:

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Three Months Nine Months
2017 2016 2017 2016
Income (Numerator)

Net income $ 355
$ 473
$ 1,050
$ 1,437
Less amounts allocated to participating securities 1
1
2
4
Net income available to PPL common shareowners - Basic and Diluted $ 354
$ 472
$ 1,048
$ 1,433

Shares of Common Stock (Denominator)

Weighted-average shares - Basic EPS 686,563
678,114
683,783
676,905
Add incremental non-participating securities:

Share-based payment awards 2,183
2,234
2,298
3,064
Weighted-average shares - Diluted EPS 688,746
680,348
686,081
679,969

Basic EPS

Net Income available to PPL common shareowners $ 0.52
$ 0.70
$ 1.53
$ 2.12

Diluted EPS

Net Income available to PPL common shareowners $ 0.51
$ 0.69
$ 1.53
$ 2.11



	Three Months				Nine Months
	2018		2017		2018		2017
Income (Numerator)
Net income	$	445	$	355	$	1,412	$	1,050
Less amounts allocated to participating securities	1		1		2		2
Net income available to PPL common shareowners - Basic and Diluted	$	444	$	354	$	1,410	$	1,048

Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	703,730		686,563		699,117		683,783
Add incremental non-participating securities:
Share-based payment awards	298		2,183		427		2,298
Forward sale agreements	6,489		—		2,761		—
Weighted-average shares - Diluted EPS	710,517		688,746		702,305		686,081

Basic EPS
Net Income available to PPL common shareowners	$	0.63	$	0.52	$	2.02	$	1.53

Diluted EPS
Net Income available to PPL common shareowners	$	0.62	$	0.51	$	2.01	$	1.53

For the periods ended September 30, PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands):


	Three Months		Nine Months		Three Months		Nine Months
	2017	2016	2017	2016	2018	2017	2018	2017
Stock-based compensation plans (a)	256	248	1,707	3,168	80	256	568	1,707
DRIP	355	761	1,169	1,533	493	355	1,504	1,169


(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.

See Note 78 for additional information on common stock issued under the ATM ~~Program.~~Program and settlement of a portion of the PPL common stock forward sale agreements.

For the periods ended September 30, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.


	Three Months		Nine Months		Three Months		Nine Months
	2017	2016	2017	2016	2018	2017	2018	2017
Stock options	696	696	696	696	15	696	229	696
Performance units	—	316	—	210
Restricted stock units					2	—	15	—

6. Income Taxes

(All Registrants)

Tax Cuts and Jobs Act (TCJA)

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2017; (2) the amount of accelerated 100% “bonus” depreciation PPL is eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on the changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of PPL's U.S. regulated operations. The final amounts reported in PPL's 2017 federal income tax return, provisional adjustment amounts for the year ended December 31, 2017, the related measurement period adjustments and the resulting tax impact for the three and nine months ended September 30, 2018 are as follows.



	Taxable Income (Loss) (a)
	Adjustments per 2017 Tax Return			Adjustments per 2017 Tax Provision			September 30, 2018 Adjustment
PPL
Deemed Dividend	$	397		$	462		$	(65	)
Bonus Depreciation (b)	(67		)	—			(67		)
Consolidated Federal Net Operating Loss due to the TCJA(c)	(330		)	(462		)	132
Total	$	—		$	—		$	—

PPL Electric
Bonus Depreciation (b)	$	(39	)	$	—		$	(39	)
Consolidated Federal Net Operating Loss reallocated due to the TCJA (c)	(68		)	(105		)	37
Total	$	(107	)	$	(105	)	$	(2	)

LKE
Bonus Depreciation (b)	$	(28	)	$	—		$	(28	)
Consolidated Federal Net Operating Loss reallocated due to the TCJA (c)	(32		)	(45		)	13
Total	$	(60	)	$	(45	)	$	(15	)

LG&E
Bonus Depreciation (b)	$	(17	)	$	—		$	(17	)
Consolidated Federal Net Operating Loss reallocated due to the TCJA (c)	17			—			17
Total	$	—		$	—		$	—

KU
Bonus Depreciation (b)	$	(11	)	$	—		$	(11	)
Consolidated Federal Net Operating Loss reallocated due to the TCJA (c)	11			—			11
Total	$	—		$	—		$	—


(a)	The above table reflects, for each item, the amount subject to change as a result of the TCJA and does not reflect the total amount of each item included in the return and the provision.


(b)	The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2023. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income.


(c)	An increase in the consolidated federal net operating loss reduces net deferred tax liabilities with the opposite effect if there is a decrease in the consolidated federal net operating loss. These increases or decreases have no impact to “Income Taxes” on the Statements of Income.



	Income Tax Expense (Benefit)
	Adjustments per 2017 Tax Return			Adjustments per 2017 Tax Provision			September 30, 2018 Adjustment
PPL
Deemed Dividend	$	139		$	161		$	(22	)
Foreign Tax Credits	(157		)	(205		)	48
Valuation of Foreign Tax Credit Carryforward	110			145			(35		)
Reduction in U.S. federal income tax rate (a)	229			220			9
Total	$	321		$	321		$	—

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	Income Tax Expense (Benefit)
	Adjustments per 2017 Tax Return			Adjustments per 2017 Tax Provision			September 30, 2018 Adjustment
PPL Electric
Reduction in U.S. federal income tax rate (a)	$	(13	)	$	(13	)	$	—

LKE
Reduction in U.S. federal income tax rate (a)	$	110		$	112		$	(2	)


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

~~5. Income Taxes~~The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 is complete as of September 30, 2018 with respect to the three items discussed above. The Registrants continue to analyze the impact of the TCJA on the deductibility of executive compensation awarded on or before November 2, 2017. The Registrants do not currently anticipate a material change from what was reflected in the December 31, 2017 financial statements and expect to record the impact, if any, of changes in the deductibility of executive compensation in the fourth quarter of 2018.

Reconciliations of income taxes for the periods ended September 30 are as follows.

																									(PPL)
	Three Months						Nine Months						Three Months						Nine Months
	2017			2016			2017			2016			2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	165		$	214		$	480		$	681
Federal income tax on Income Before Income Taxes at statutory tax rate (a)													$	115		$	165		$	373		$	480
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14			13			37			37			9			14			34			37
Valuation allowance adjustments	4			4			9			13			5			4			17			9
Impact of lower U.K. income tax rates	(45		)	(37		)	(133		)	(136		)
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(8		)	(1		)	(24		)	(3		)
Impact of the U.K. Finance Acts (b)	(3		)	(42		)	(12		)	(42		)
Depreciation not normalized	(2		)	—			(7		)	(6		)
Impact of lower U.K. income tax rates relative to U.S. income tax rates (a)													(7		)	(45		)	(20		)	(133		)
U.S. income tax on foreign earnings - net of foreign tax credit (a) (b)													1			(8		)	2			(24		)
Federal and state tax reserve adjustments													—			—			3			—
Impact of the U.K. Finance Acts													(4		)	(3		)	(7		)	(12		)
Depreciation and other items not normalized													(1		)	(2		)	(4		)	(7		)
Amortization of excess deferred income taxes (a)													(11		)	—			(30		)	—
Deferred tax impact of state tax reform (c)													—			—			9			—
Interest benefit on U.K. financing entities	(4		)	(4		)	(12		)	(13		)	(4		)	(4		)	(13		)	(12		)
Stock-based compensation	—			(1		)	(7		)	(12		)	—			—			1			(7		)
Other	(5		)	(7		)	(10		)	(9		)	—			(5		)	(3		)	(10		)
Total increase (decrease)	(49		)	(75		)	(159		)	(171		)	(12		)	(49		)	(11		)	(159		)
Total income taxes	$	116		$	139		$	321		$	510		$	103		$	116		$	362		$	321


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.


(b)	Lower income taxes in 2017 primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit iswas recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

~~(b)~~(c)

~~The U.K. Finance Act 2016, enacted in September 2016, reduces~~During the ~~U.K. statutory~~second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective ~~April~~January 1, ~~2020 from 18% to 17%. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during the three and nine months ended September 30, 2016.~~2018.

(PPL Electric)
Three Months Nine Months
2017 2016 2017 2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 56
$ 52
$ 144
$ 149
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 9
9
26
27
Depreciation not normalized (1 ) (2 ) (5 ) (5 )
Stock-based compensation —
—
(5 ) (7 )
Other —
(1 ) (1 ) (2 )
Total increase (decrease) 8
6
15
13
Total income taxes $ 64
$ 58
$ 159
$ 162

(LKE)
Three Months Nine Months
2017 2016 2017 2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 74
$ 74
$ 181
$ 189
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 8
8
19
20
Amortization of investment tax credit (1 ) (1 ) (2 ) (2 )
Stock-based compensation —
(1 ) (1 ) (2 )
Other (2 ) (1 ) (2 ) (3 )
Total increase (decrease) 5
5
14
13
Total income taxes $ 79
$ 79
$ 195
$ 202

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(LG&E)
Three Months Nine Months
2017 2016 2017 2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35% $ 36
$ 36
$ 91
$ 90
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 4
4
10
10
Other (1 ) (1 ) (2 ) (2 )
Total increase (decrease) 3
3
8
8
Total income taxes $ 39
$ 39
$ 99
$ 98


(KU)
(PPL Electric)
	Three Months						Nine Months						Three Months						Nine Months
	2017			2016			2017			2016			2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	43		$	44		$	111		$	117
Federal income tax on Income Before Income Taxes at statutory tax rate (a)													$	30		$	56		$	93		$	144
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5			5			11			12			12			9			35			26
Depreciation and other items not normalized													(1		)	(1		)	(4		)	(5		)
Amortization of excess deferred income taxes (a)													(5		)	—			(13		)	—
Stock-based compensation													—			—			—			(5		)
Other	(1		)	(1		)	(2		)	(1		)	(1		)	—			—			(1		)
Total increase (decrease)	4			4			9			11			5			8			18			15
Total income taxes	$	47		$	48		$	120		$	128		$	35		$	64		$	111		$	159


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.



(LKE)
	Three Months						Nine Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	34		$	74		$	97		$	181
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	6			8			17			19
Amortization of investment tax credit	(1		)	(1		)	(3		)	(2		)
Deferred tax impact of U.S. tax reform (a)	(2		)	—			(2		)	—
Deferred tax impact of state tax reform (c)	—			—			9			—
Amortization of excess deferred income taxes (a)	(3		)	—			(14		)	—
Other	(2		)	(2		)	(2		)	(3		)
Total increase (decrease)	(2		)	5			5			14
Total income taxes	$	32		$	79		$	102		$	195


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.


(b)	The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018.


(c)	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.



(LG&E)
	Three Months						Nine Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	18		$	36		$	50		$	91
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	3			4			9			10
Amortization of excess deferred income taxes (a)	(1		)	—			(6		)	—
Other	(2		)	(1		)	(2		)	(2		)
Total increase (decrease)	—			3			1			8
Total income taxes	$	18		$	39		$	51		$	99


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.


(b)	The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

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(KU)
	Three Months						Nine Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	21		$	43		$	60		$	111
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	3			5			10			11
Amortization of excess deferred income taxes (a)	(2		)	—			(8		)	—
Other	(1		)	(1		)	(3		)	(2		)
Total increase (decrease)	—			4			(1		)	9
Total income taxes	$	21		$	47		$	59		$	120


(a)	The U.S. federal corporate income tax rate was reduced from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.


(b)	The Kentucky corporate income tax rate was reduced from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

Kentucky State Tax Reform (All Registrants)

HB 487, which became law on April 27, 2018, provides for significant changes to the Kentucky tax code including (1) adopting mandatory combined reporting for corporate members of unitary business groups for taxable years beginning on or after January 1, 2019 (members of a unitary business group may make an eight-year binding election to file consolidated corporate income tax returns with all members of their federal affiliated group) and (2) a reduction in the Kentucky corporate income tax rate from 6% to 5% for taxable years beginning after December 31, 2017. LKE recognized a deferred tax charge of $9 million in the second quarter of 2018 primarily associated with the remeasurement of non-regulated accumulated deferred income tax balances.

6.7. Utility Rate Regulation

(All Registrants)

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

PPL PPL Electric
September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016
Current Regulatory Assets:
Environmental cost recovery $ 4
$ 6
$ —
$ —
Generation formula rate 8
11
—
—
Transmission service charge —
7
—
7
Gas supply clause 6
3
—
—
Smart meter rider 12
6
12
6
Storm costs 1
5
1
5
Other 3
1
1
1
Total current regulatory assets (a) $ 34
$ 39
$ 14
$ 19

Noncurrent Regulatory Assets:
Defined benefit plans $ 908
$ 947
$ 530
$ 549
Taxes recoverable through future rates 347
340
347
340
Storm costs 37
57
—
9
Unamortized loss on debt 55
61
30
36
Interest rate swaps 29
31
—
—
Terminated interest rate swaps 93
98
—
—
Accumulated cost of removal of utility plant 166
159
166
159
AROs 224
211
—
—
Other 10
14
—
1
Total noncurrent regulatory assets $ 1,869
$ 1,918
$ 1,073
$ 1,094



	PPL				PPL Electric
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—
Smart meter rider	16		15		16		15
Plant outage costs	7		3		—		—
Gas supply clause	3		4		—		—
Other	3		1		2		1
Total current regulatory assets (a)	$	29	$	34	$	18	$	16

Table of Contents

PPL PPL Electric
September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016
Current Regulatory Liabilities:
Generation supply charge $ 29
$ 23
$ 29
$ 23
Transmission service charge 6
—
6
—
Universal service rider 19
14
19
14
Transmission formula rate 4
15
4
15
Fuel adjustment clause 11
11
—
—
Act 129 compliance rider 7
17
7
17
Storm damage expense 7
13
7
13
Other 4
8
—
1
Total current regulatory liabilities $ 87
$ 101
$ 72
$ 83

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant $ 678
$ 700
$ —
$ —
Power purchase agreement - OVEC (b) 69
75
—
—
Net deferred tax assets 21
23
—
—
Defined benefit plans 27
23
—
—
Terminated interest rate swaps 74
78
—
—
Other 4
—
—
—
Total noncurrent regulatory liabilities $ 873
$ 899
$ —
$ —



	PPL				PPL Electric
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Noncurrent Regulatory Assets:
Defined benefit plans	$	847	$	880	$	486	$	504
Taxes recoverable through future rates	3		3		3		3
Storm costs (b)	45		33		22		—
Unamortized loss on debt	47		54		23		29
Interest rate swaps	18		26		—		—
Terminated interest rate swaps	88		92		—		—
Accumulated cost of removal of utility plant	190		173		190		173
AROs	267		234		—		—
Act 129 compliance rider	12		—		12		—
Other	8		9		2		—
Total noncurrent regulatory assets	$	1,525	$	1,504	$	738	$	709

LKE LG&E KU
September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016
Current Regulatory Assets:
Environmental cost recovery $ 4
$ 6
$ 4
$ 6
$ —
$ —
Generation formula rate 8
11
—
—
8
11
Gas supply clause 6
3
6
3
—
—
Other 2
—
1
—
1
—
Total current regulatory assets $ 20
$ 20
$ 11
$ 9
$ 9
$ 11

Noncurrent Regulatory Assets:
Defined benefit plans $ 378
$ 398
$ 235
$ 246
$ 143
$ 152
Storm costs 37
48
20
26
17
22
Unamortized loss on debt 25
25
16
16
9
9
Interest rate swaps 29
31
29
31
—
—
Terminated interest rate swaps 93
98
54
57
39
41
AROs 224
211
57
70
167
141
Plant retirement costs 2
4
—
—
2
4
Other 8
9
2
4
6
5
Total noncurrent regulatory assets $ 796
$ 824
$ 413
$ 450
$ 383
$ 374



	PPL				PPL Electric
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Generation supply charge	$	35	$	34	$	35	$	34
Transmission service charge	2		9		2		9
Environmental cost recovery	22		1		—		—
Universal service rider	23		26		23		26
Transmission formula rate	8		9		8		9
Fuel adjustment clause	7		3		—		—
TCJA customer refund (c)	26		—		—		—
Storm damage expense rider	4		8		4		8
Other	9		5		—		—
Total current regulatory liabilities	$	136	$	95	$	72	$	86

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	—	$	—
Power purchase agreement - OVEC (d)	62		68		—		—
Net deferred taxes (e)	1,846		1,853		642		668
Defined benefit plans	33		27		—		—
Terminated interest rate swaps	72		74		—		—
TCJA customer refund (f)	41		—		41		—
Other	7		5		3		—
Total noncurrent regulatory liabilities	$	2,739	$	2,704	$	686	$	668



	LKE				LG&E				KU
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Current Regulatory Assets:
Plant outage costs	$	7	$	3	$	7	$	3	$	—	$	—
Generation formula rate	—		6		—		—		—		6
Gas supply clause	3		4		3		4		—		—
Other	1		5		1		5		—		—
Total current regulatory assets	$	11	$	18	$	11	$	12	$	—	$	6

Table of Contents

LKE LG&E KU
September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016 September 30,
2017 December 31,
2016
Current Regulatory Liabilities:
Demand side management $ —
$ 3
$ —
$ 2
$ —
$ 1
Fuel adjustment clause 11
11
3
2
8
9
Other 4
4
2
1
2
3
Total current regulatory liabilities $ 15
$ 18
$ 5
$ 5
$ 10
$ 13

Noncurrent Regulatory Liabilities:
Accumulated cost of removal
of utility plant
$ 678
$ 700
$ 281
$ 305
$ 397
$ 395
Power purchase agreement - OVEC (b) 69
75
48
52
21
23
Net deferred tax assets 21
23
21
23
—
—
Defined benefit plans 27
23
—
—
27
23
Terminated interest rate swaps 74
78
37
39
37
39
Other 4
—
1
—
3
—
Total noncurrent regulatory liabilities $ 873
$ 899
$ 388
$ 419
$ 485
$ 480



	LKE				LG&E				KU
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Noncurrent Regulatory Assets:
Defined benefit plans	$	361	$	376	$	227	$	234	$	134	$	142
Storm costs	23		33		12		18		11		15
Unamortized loss on debt	24		25		15		16		9		9
Interest rate swaps	18		26		18		26		—		—
Terminated interest rate swaps	88		92		52		54		36		38
AROs	267		234		74		61		193		173
Other	6		9		2		2		4		7
Total noncurrent regulatory assets	$	787	$	795	$	400	$	411	$	387	$	384



	LKE				LG&E				KU
	September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017		September 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Environmental cost recovery	$	22	$	1	$	11	$	—	$	11	$	1
Fuel adjustment clause	7		3		—		—		7		3
Gas line tracker	2		3		2		3		—		—
TCJA customer refund (c)	26		—		12		—		14		—
Other	7		2		1		—		6		2
Total current regulatory liabilities	$	64	$	9	$	26	$	3	$	38	$	6

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	280	$	282	$	398	395
Power purchase agreement - OVEC (d)	62		68		43		47		19		21
Net deferred taxes (e)	1,204		1,185		560		552		644		633
Defined benefit plans	33		27		—		—		33		27
Terminated interest rate swaps	72		74		36		37		36		37
Other	4		5		1		1		3		4
Total noncurrent regulatory liabilities	$	2,053	$	2,036	$	920	$	919	$	1,133	$	1,117


(a)	For PPL, these amounts are included in "Other current assets" on the Balance Sheets.


(b)	Storm costs incurred in PPL Electric's territory from a March 2018 storm will be amortized from 2019 through 2021.


(c)	Relates to estimated amounts owed to LG&E and KU customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, effective January 1, 2018. Amounts owed will be distributed through the TCJA bill credit.


(d)	This liability was recorded as an offset to an intangible asset that was recorded at fair value upon the acquisition of LKE by PPL.


(e)	Primarily relates to excess deferred taxes recorded as a result of the TCJA, which reduced the U.S. federal corporate income tax rate effective January 1, 2018, requiring deferred tax balances and the associated regulatory liabilities to be remeasured as of December 31, 2017. LG&E and KU began distributing amounts through the TCJA bill credit effective April 1, 2018.

(f)

Relates to amounts owed to PPL Electric customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, for the period of January 1, 2018 through June 30, 2018 which is not yet reflected in distribution customer rates. The distribution method back to customers of this liability must be proposed to the PUC at the earlier of May 2021 or PPL Electric’s next rate case.

Regulatory Matters

Kentucky Activities

(PPL, LKE, LG&E and KU)

Rate Case Proceedings

~~In November 2016,~~On September 28, 2018, LG&E and KU filed requests with the KPSC for an increase in annual base electricity rates of approximately $112 million at KU and increases in annual base electricity and gas ~~rates. LG&E's and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program.~~

On April 19, 2017 and May 1, 2017, LG&E and KU, along with all intervening parties to the proceeding, filed with the KPSC, stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things, the proposed stipulations provided for increases in annual revenue requirements associated with KU base electricity rates of ~~$55 million, LG&E base electricity rates of $59~~approximately $35 million and $25 million, respectively, at LG&E&E. The proposed base gas rates of $8 million, reflecting a return 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.

On June 22, 2017, the KPSC issued orders approving, with certain modifications, the proposed stipulations filed in April and May 2017. On June 29, 2017, the KPSC issued further orders correcting certain revenue requirement and rate ~~calculations and making other technical corrections to the June 22, 2017 orders. The combined KPSC orders modified the stipulations to provide for~~ increases in annual revenue requirements associated with KU base electricity rates of $52 million, LG&E base electricity rates of $57 million and LG&E base gas rates of $7 million, and incorporate an authorized return on equity of 9.7%. Consistent with the stipulations, the orders approved LG&E's and KU's request for implementing a Distribution Automation program and withdrawal of a request for a CPCN for the Advanced Metering System program. The orders also approved new depreciation rates for LG&E and KU that willwould result 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 result in a base~~an electricity rate increase of ~~3.2%~~6.9% at KU and base electricity and gas rate increases of 5.2% and 2.1% at LG&E. The new base rates and all elements of the orders became effective July 1, 2017. On June 23, 2017, the KPSC also 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, replacing 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 impact of the new authorized return for ECR projects is not expected to be significant in 2017.

Table of Contents

electricity and gas rate increases of 3% and 7.5%, respectively, at LG&E. As discussed in the "TCJA Impact on LG&E and KU Rates" section below, LG&E’s and KU’s applications seek to include applicable changes associated with the TCJA in the calculation of the proposed base rates and to terminate the TCJA bill credit mechanism when the new base rates go into effect.

New rates are expected to become effective on May 1, 2019. The applications are based on a forecasted test year of May 1, 2019 through April 30, 2020 with a requested return-on-equity of 10.42%. LG&E and KU cannot predict the outcome of these proceedings.

CPCN Filing

On January 10, 2018, LG&E and KU filed an application for a CPCN with the KPSC requesting approval to implement Advanced Metering Systems across their Kentucky service territories, including gas operations for LG&E. The application projected completion in 2021 with estimated capital costs of $166 million and $155 million for LG&E and KU. On August 30, 2018, the KPSC issued an Order denying the CPCN for full deployment of the Advanced Metering Systems. The KPSC acknowledged the benefits of Advanced Metering Systems, expanded LG&E's and KU's Advanced Metering System pilot programs and encouraged LG&E and KU to consider other items to enhance the customer experience. This decision is not expected to have a significant impact on LG&E's and KU's results of operations.

TCJA Impact on LG&E and KU Rates

On December 21, 2017, Kentucky Industrial Utility Customers, Inc. submitted a complaint with the KPSC against LG&E and KU, as well as other utility companies in Kentucky, alleging that their respective rates would no longer be fair, just and reasonable following the enactment of the TCJA reducing the federal corporate tax rate from 35% to 21%. The complaint requested the KPSC to issue an Order requiring LG&E and KU to begin deferring, as of January 1, 2018, the revenue requirement effect of all income tax expense savings resulting from the federal corporate income tax reduction, including the amortization of excess deferred income taxes by recording those savings in a regulatory liability account and establishing a process by which the federal corporate income tax savings will be passed back to customers.

On January 29, 2018, LG&E, KU, Kentucky Industrial Utility Customers, Inc. and the Office of the Attorney General reached a settlement agreement to commence returning savings related to the TCJA to their customers through their ECR, DSM and LG&E's GLT rate mechanisms beginning in March 2018 and through a new bill credit mechanism from April 1, 2018 through April 30, 2019 and thereafter until tax-reform related savings are reflected in changes in base rates. The estimated impact of the rate reduction represents approximately $91 million in KU electricity revenues ($70 million through the new bill credit and $21 million through existing rate mechanisms), $69 million in LG&E electricity revenues ($49 million through the new bill credit and $20 million through existing rate mechanisms) and $17 million in LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019.

On March 20, 2018, the KPSC issued an Order approving, with certain modifications, the settlement agreement reached between LG&E, KU, Kentucky Industrial Utility Customers, Inc. and the Office of the Attorney General. The KPSC estimates that, pursuant to its modifications, electricity revenues would incorporate reductions of approximately $108 million for KU ($87 million through the new bill credit and $21 million through existing rate mechanisms) and $79 million for LG&E ($59 million through the new bill credit and $20 million through existing rate mechanisms). This represents $27 million ($17 million at KU and $10 million at LG&E) in additional reductions from the amounts proposed by the settlement. The KPSC's modifications to the settlement include certain changes in assumptions or inputs used in assessing tax reform or calculating LG&E's and KU's electricity rates. LG&E gas rate reductions were not modified significantly from the amount included in the settlement agreement.

On March 26, 2018, LG&E and KU filed a petition for reconsideration and request for hearing with the KPSC, taking exception to the KPSC's modifications and the process, and also requested certain relief from implementing the amounts represented by the additional reductions until the matter is fully resolved. On March 28, 2018, the Office of the Attorney General filed a response to the petition and gave notice of its withdrawal from the settlement agreement.

On March 28, 2018, the KPSC issued an Order granting LG&E's and KU's request for reconsideration and amending its March 20, 2018 Order by suspending the approved rates, allowing LG&E and KU, on an interim basis, to return savings related to the TCJA at the rates agreed to in the January 29, 2018 settlement.

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$74 million for LG&E electricity revenues ($54 million through the new bill credit and $20 million through existing rate mechanisms) and $16 million LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019. This represents lower revenue reduction amounts than the March 20, 2018 Order of approximately $13 million ($7 million at KU and $6 million at LG&E). LG&E and KU have been implementing interim partial rate reductions since April 2018, as authorized by the KPSC on March 28, 2018, and recording reserves up to the higher reduction amounts originally approved in the March 20, 2018 Order. The September 28, 2018 Order is not expected to have a material adverse impact on LG&E's and KU's financial condition or results of operations.

Additionally, on January 8, 2018, the VSCC ordered KU, as well as other utilities in Virginia, to accrue regulatory liabilities reflecting the Virginia jurisdictional revenue requirement impacts of the reduced federal corporate tax rate. On March 22, 2018, KU reached a settlement agreement regarding its rate case in Virginia. New rates, inclusive of TCJA impacts, were effective June 1, 2018. The settlement also stipulates that actual tax savings for the five month period prior to new rates taking effect would be addressed through KU's annual information filing for calendar year 2018. On May 8, 2018, the VSCC approved the settlement agreement. The TCJA and rate case are not expected to have a significant impact on KU's financial condition or results of operations related to Virginia.

On March 15, 2018, the FERC issued a Notice of Inquiry seeking information on whether and how it should address changes relating to accumulated deferred income taxes and bonus depreciation resulting from passage of the TCJA on FERC-jurisdictional rates. LG&E and KU have not made any submission in response to the Notice of Inquiry, but do not anticipate the impact of the TCJA related to their FERC-jurisdictional rates to be significant.

Gas Franchise (LKE and LG&E)

LG&E’s gas franchise agreement for the Louisville/Jefferson County service area expired in March 2016. In August 2016, LG&E and Louisville/Jefferson County entered into a revised franchise agreement with a 5-year term (with renewal options). The franchise fee may be modified at Louisville/Jefferson County's election upon 60 days' notice. However, any franchise fee is capped at 3% of gross receipts for natural gas service within the franchise area. The agreement further provides that if the KPSC determines that the franchise fee should be recovered from LG&E's Louisville/Jefferson county customers in the franchise areas as a separate line item on their bill, the franchise fee will revert to zero. In August 2016, LG&E filed an application ~~in a~~requesting the KPSC ~~proceeding~~ to review and rule upon the recoverability of the franchise fee.

In August 2016, Louisville/Jefferson County submitted a motion to dismiss the proceeding filed by LG&E and, in November 2016, filed an amended complaint against LG&E relating to these issues. LG&E submitted KPSC filings to respond to, request dismissal of and consolidate certain claims or aspects of the proceedings. In January 2017,On March 14, 2018, the KPSC issued an ~~order denying~~Order authorizing the franchise fee to be recovered only from LG&E's Louisville/Jefferson ~~County's motion~~County customers in the franchise area. As a result, the franchise fee will continue to ~~dismiss, consolidating~~be zero in accordance with the ~~matter~~terms of the August 2016, 5-year gas franchise agreement.

(PPL and PPL Electric)

Pennsylvania Activities

TCJA Impact on PPL Electric Rates

On February 12, 2018, the PUC issued a Secretarial Letter requesting certain information from regulated utilities and inviting comment from interested parties on potential revision to customer rates as a result of enactment of the TCJA. PPL Electric submitted its response to the Secretarial Letter on March 9, 2018. On March 15, 2018, the PUC issued a Temporary Rates Order to allow time to determine the manner in which rates could be adjusted in response to the TCJA. The PUC issued another Temporary Rates Order on May 17, 2018 to address the impact of the TCJA and indicated that utilities without a currently pending general rate proceeding would receive a utility specific order. The PUC issued an Order specific to PPL Electric on May 17, 2018 which required PPL Electric to file a tariff or tariff supplement by June 15, 2018 to establish (a) temporary rates to include a negative surcharge of 0.56%, which was based on PPL Electric's 2017 taxable income, to be effective July 1, 2018, and (b) to record a deferred regulatory liability to reflect the tax savings associated with ~~LG&E's filed application and establishing a procedural schedule~~the TCJA for the ~~case.~~period January 1 through June 30, 2018. On ~~September 28, 2017, oral arguments were heard~~June 8, 2018, PPL Electric submitted a petition to the PUC to increase the negative surcharge proposed in the May 17, 2018 Order from 0.56% to 7.05% to reflect the estimated 2018 tax savings associated with the TCJA. The PUC approved PPL Electric's petition on June 14, 2018 and PPL Electric filed a tariff on June 15, 2018 reflecting the increased negative surcharge. The estimated 2018 full year impact of the rate reduction is $72 million in PPL Electric's operating revenues, of which $39 million relates to the period January 1, 2018 through June 30, 2018 and was recorded as a noncurrent regulatory liability in the second quarter of 2018 to be distributed to customers pursuant to a future rate adjustment. The remaining $33 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and is being passed back to customers through the negative surcharge which began on July 1, 2018.

Table of Contents

On March 15, 2018, the FERC issued a Notice of Inquiry seeking information on whether and how it should address changes to FERC-jurisdictional rates relating to accumulated deferred income taxes and bonus depreciation resulting from passage of the TCJA. On March 16, 2018, PPL Electric filed a waiver request, pursuant to Rule 207(a)(5) of the Rules of Practice and Procedure of the FERC, to accelerate incorporation of the changes to the federal corporate income tax rate in its transmission formula rate commencing on June 1, 2018 rather than allowing the TCJA tax rate reduction to be initially incorporated in PPL Electric's June 1, 2019 transmission formula rate. The waiver was approved on April 23, 2018 and PPL Electric submitted its transmission formula rate, reflecting the TCJA rate reduction, on April 27, 2018. In addition, on May 21, 2018, PPL Electric, as part of a PJM Transmission Owners joint filing, submitted comments in response to the FERC's March 15, 2018 Notice of Inquiry. The filing requested guidance on how the reduction in accumulated deferred income taxes, resulting from the TCJA reduced federal corporate income tax rate, should be treated for ratemaking purposes. PPL Electric is currently awaiting FERC's decision on this matter. The changes, related to accumulated deferred income taxes impacting the transmission formula rate revenues, have not been significant since the new rate went into effect on June 1, 2018.

Federal Matters

(PPL, LKE, LG&E and KU)

FERC Transmission Rate Filing

On August 3, 2018, LG&E and KU submitted an application 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 seeks termination of LG&E’s and KU’s commitment to provide mitigation for certain horizontal market power concerns arising out of the 1998 merger for certain transmission service between MISO and LG&E and KU. The affected transmission customers are a limited number of municipal entities in Kentucky or Tennessee. The amounts at issue are generally waivers or credits for either LG&E and KU or for MISO transmission charges depending upon the direction of transmission service incurred by the ~~KPSC~~municipalities. LG&E and ~~a final order is expected~~KU estimate that such charges may average approximately $22 million annually, depending upon actual transmission customer and market volumes, structures and prices, with such charges allocated according to LG&E's and KU’s respective transmission system ownership ratio. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. LG&E and KU currently receive recovery of such expenses in ~~2017. Until the KPSC issues a final order in this proceeding,~~other rate mechanisms. LG&E and KU cannot predict the ~~ultimate~~ outcome of ~~this matter but does not anticipate that it will have a material effect~~the proceeding, including any effects on ~~its~~their financial condition or results of ~~operation. LG&E continues to provide gas service to customers in this franchise area at existing rates, but without collecting or remitting a franchise fee.~~operations.

Transmission Customer Complaint

On September 21, 2018, a transmission customer filed a complaint with the FERC against LG&E and KU alleging LG&E and KU have violated and continue to violate their obligations under an existing rate schedule to credit this customer for certain transmission charges from MISO. On October 11, 2018, LG&E and KU filed an answer to the complaint arguing such MISO transmission transactions are not covered by the rate schedule, and the amounts in question are not eligible for credits. LG&E and KU cannot predict the outcome of the proceeding, but believe that any potential required credits would be subject to rate recovery.

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 the three and nine months ended September 30, 2018, PPL Electric purchased $334 million and $1 billion of accounts receivable from alternate suppliers. During the three and nine months ended September 30, 2017, PPL Electric purchased $324 million and $968 million of accounts receivable from alternate suppliers.

7.Table of Contents

8. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and ~~provide~~act as 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. The amounts borrowed below are recorded as "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. The following credit facilities were in place at:


	September 30, 2017									December 31, 2016				September 30, 2018									December 31, 2017
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		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)	Jan. 2022	£	210	£	155	£	—	£	54	£	160	£	—	Jan. 2023	£	210	£	154	£	—	£	54	£	148	£	—
Term Loan Facility (b)	Dec. 2017	230		230		—		—		—		—		Dec. 2018	130		130		—		—		—		—
WPD (South West)
Syndicated Credit Facility (c)	July 2021	245		—		—		245		110		—
Syndicated Credit Facility														July 2021	245		—		—		245		—		—
WPD (East Midlands)
Syndicated Credit Facility ~~(d)~~(c)	July 2021	300		116		—		184		9		—		July 2021	300		93		—		207		180		—
WPD (West Midlands)
Syndicated Credit Facility(d)	July 2021	300		—		—		300		—		—		July 2021	300		50		—		250		120		—
Uncommitted Credit Facilities ~~(e)~~		100		70		4		26		60		4			130		—		4		126		—		4
Total U.K. Credit Facilities ~~(f)~~(e)		£	1,385	£	571	£	4	£	809	£	339	£	4		£	1,315	£	427	£	4	£	882	£	448	£	4
U.S.
PPL Capital Funding
Syndicated Credit Facility														Jan. 2023	$	950	$	—	$	691	$	259	$	—	$	230
Syndicated Credit Facility														Nov. 2018	300		—		—		300		—		—
Bilateral Credit Facility														Mar. 2019	100		—		20		80		—		18
Total PPL Capital Funding Credit Facilities															$	1,350	$	—	$	711	$	639	$	—	$	248

PPL Electric
Syndicated Credit Facility														Jan. 2023	$	650	$	—	$	1	$	649	$	—	$	1

LKE
Syndicated Credit Facility														Oct. 2018	$	75	$	—	$	—	$	75	$	—	$	—

LG&E
Syndicated Credit Facility														Jan. 2023	$	500	$	—	$	176	$	324	$	—	$	199
Term Loan Credit Facility														Oct. 2019	200		200		—		—		100		—
Total LG&E Credit Facilities															$	700	$	200	$	176	$	324	$	100	$	199

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	September 30, 2017									December 31, 2016				September 30, 2018									December 31, 2017
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2022	$	950	$	—	$	285	$	665	$	—	$	20
Syndicated Credit Facility	Nov. 2018	300		—		—		300		—		—
Bilateral Credit Facility	Mar. 2018	150		—		18		132		—		17
Total PPL Capital Funding Credit Facilities		$	1,400	$	—	$	303	$	1,097	$	—	$	37

PPL Electric
Syndicated Credit Facility	Jan. 2022	$	650	$	—	$	1	$	649	$	—	$	296

LKE
Syndicated Credit Facility	Oct. 2018	$	75	$	—	$	—	$	75	$	—	$	—

LG&E
Syndicated Credit Facility	Jan. 2022	$	500	$	—	$	190	$	310	$	—	$	169

KU
Syndicated Credit Facility	Jan. 2022	$	400	$	—	$	—	$	400	$	—	$	16	Jan. 2023	$	400	$	—	$	128	$	272	$	—	$	45
Letter of Credit Facility	Oct. 2020	198		—		198		—		—		198		Oct. 2020	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	198	$	400	$	—	$	214		$	598	$	—	$	326	$	272	$	—	$	243


(a)	The amounts borrowed at September 30, ~~2017~~2018 and December 31, ~~2016~~2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at ~~2.06%~~2.90% and ~~1.43%~~2.17%. The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed.


(b)	The amount borrowed at September 30, ~~2017~~2018 was a GBP-denominated borrowing which equated to ~~$296~~$168 million and bore interest at ~~1.50%~~1.97%.


(c)	The ~~amount~~amounts borrowed at September 30, 2018 and December 31, ~~2016 was a~~2017 were GBP-denominated ~~borrowing~~borrowings which equated to ~~$137~~$121 millionand $244 million and bore interest at ~~0.66%~~1.09% and 0.89%.


(d)	The amounts borrowed at September 30, ~~2017~~2018 and December 31, ~~2016~~2017 were GBP-denominated borrowings which equated to ~~$150~~$65 millionand ~~$11~~$162 million and bore interest at ~~0.65%~~1.12% and ~~0.66%~~0.89%.


(e)	~~The amounts borrowed at September 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $90 million and $75 million and bore interest at 1.29% and 1.26%.~~


~~(f)~~	At September 30, ~~2017,~~2018, the unused capacity under the U.K. credit facilities was ~~$1.0~~$1.1 billion.

~~(PPL, LKE and LG&E)~~

In October ~~2017, LG&E entered into a $200~~2018, LKE's $75 million ~~term loan~~ credit facility ~~expiring in 2019. On October 26, 2017, LG&E borrowed $100~~expired. LKE increased its revolving line of credit with a PPL Energy Funding subsidiary by $75 million ~~under this facility bearing interest~~to a limit of ~~1.74%. The proceeds will be used to repay short-term debt and~~$375 million. See Note 11 for ~~general corporate purposes.~~

~~(All Registrants)~~additional information.

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. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's Syndicated Credit Facility. The following commercial paper programs were in place at:

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	September 30, 2017							December 31, 2016			September 30, 2018							December 31, 2017
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances		Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	1.41%	$	1,000	$	285	$	715	1.10%	$	20	2.38%	$	1,000	$	691	$	309	1.64%	$	230
PPL Electric		650		—		650		1.05%	295			650		—		650			—
LG&E	1.38%	350		190		160		0.94%	169		2.34%	350		176		174		1.83%	199
KU		350		—		350		0.87%	16		2.34%	350		128		222		1.97%	45
Total		$	2,350	$	475	$	1,875		$	500		$	2,350	$	995	$	1,355		$	474

(PPL Electric, LKE, ~~LG&E~~ and ~~KU)~~LG&E)

See Note 1011 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

In March ~~2017,~~2018, WPD (South Wales) issued ~~£50~~£30 million of 0.01% Index-linked Senior Notes due ~~2029.~~2036. WPD (South Wales) received proceeds of ~~£53~~£31 million, which equated to ~~$64~~$44 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 ~~September 2017,~~May 2018, WPD (West Midlands) issued £30 million of 0.01% Index-linked Senior Notes due 2028. WPD (West Midlands) received proceeds of £31 million, which equated to $41 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 2018, PPL Capital Funding repaid the entire $250 million principal amount of its 1.90% Senior Notes upon maturity.

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In October 2018, WPD plc issued ~~$500~~£350 million of ~~4.00%~~3.5% Senior Notes due ~~2047. PPL Capital Funding~~2026. WPD plc received proceeds of ~~$490~~£346 million, which equated to $456 million at the time of issuance, net of fees and a discount. The proceeds will be used for general corporate purposes.

(PPL and PPL Electric)

In June 2018, PPL Electric issued $400 million of 4.15% First Mortgage Bonds due 2048. PPL Electric received proceeds of $394 million, net of a discount and underwriting fees, which were used to repay short-term debt ~~obligations~~ and for general corporate purposes.

~~(PPL and PPL Electric)~~

In May 2017, PPL Electric issued $475 million of 3.95% First Mortgage Bonds due 2047. PPL Electric received proceeds of $466 million, net of a discount and underwriting fees, which were used to repay short-term debt incurred primarily for capital expenditures.

In August 2017, the LCIDA remarketed $108 million of Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project), Series 2016B due 2027 previously issued on behalf of PPL Electric. The bonds were remarketed at a long-term rate and will bear interest at 1.80% through their mandatory purchase date of August 15, 2022.

In September 2017, the LCIDA remarketed $116 million of Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project), Series 2016A due 2029 previously issued on behalf of PPL Electric. The bonds were remarketed at a long-term rate and will bear interest at 1.80% through their mandatory purchase date of September 1, 2022.

(PPL, LKE and LG&E)

In ~~April 2017,~~March 2018, the ~~Louisville/Jefferson~~ County ~~Metro Government~~ of Trimble, Kentucky remarketed ~~$128~~$28 million of Pollution Control Revenue Bonds, ~~2003~~2001 Series A (Louisville Gas and Electric Company Project) due ~~2033~~2026 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at ~~1.50%~~2.30% through their mandatory purchase date of ~~April~~September 1, ~~2019.~~2021.

In ~~June 2017,~~May 2018, the County of Trimble, Kentucky ~~issued $60~~remarketed $35 million of ~~Environmental Facilities~~Pollution Control Revenue ~~Refunding~~ Bonds, 2017 Series A (Louisville Gas and Electric Company Project) 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, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued

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~~on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25% through their mandatory purchase date of June 3, 2019.~~

~~In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $35 million of Environmental Facilities Revenue Refunding Bonds, 2007~~2001 Series B (Louisville Gas and Electric Company Project) due ~~2033~~2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at ~~1.25%~~2.55% through their mandatory purchase date of ~~June~~May 3, ~~2019.~~2021.

In May 2018, the County of Jefferson, Kentucky remarketed $35 million of Pollution Control Revenue Bonds, 2001 Series B (Louisville Gas and Electric Company Project) due 2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 2.55% through their mandatory purchase date of May 3, 2021.

(LKE)

In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028. The proceeds were used to repay its outstanding notes payable to a PPL Energy Funding subsidiary. See Note 11 for additional information related to intercompany borrowings.

(PPL)

Equity Securities

Equity Forward Contracts

In May 2018, PPL completed a registered underwritten public offering of 55 million shares of its common stock. In conjunction with that offering, the underwriters exercised an option to purchase 8.25 million additional shares of PPL common stock solely to cover over-allotments.

In connection with the registered public offering, PPL entered into forward sale agreements with two counterparties covering the 63.25 million shares of PPL common stock. Full settlement of these forward sale agreements will occur no later than November 2019. Upon any physical settlements of any forward sale agreement, PPL will issue and deliver to the applicable forward counterparty shares of its common stock in exchange for cash proceeds per share equal to the forward sale price. The forward sale price will be calculated based on an initial forward price of $26.7057 per share reduced during the period the applicable forward contract is outstanding as specified in such forward sale agreement. PPL may, in certain circumstances, elect cash settlement or net share settlement for all or a portion of its rights or obligations under each forward sale agreement. The forward sale agreements are classified as equity transactions. PPL only receives proceeds and issues shares of common stock upon any settlements of the forward sale agreements. PPL intends to use net proceeds that it receives upon any settlement for general corporate purposes.

In September 2018, PPL settled a portion of the initial forward sale agreements by issuing 20 million shares of PPL common stock, resulting in net cash proceeds of $520 million. For the unsettled portion of the agreements, the only impact to the financial statements will be the inclusion of incremental shares within the calculation of diluted EPS using the Treasury Stock Method. See Note 5 for information on the forward sale agreements impact on the calculation of diluted EPS.

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ATM Program

In February ~~2015,~~2018, PPL entered into ~~two separate~~an 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. For~~stock through an at-the-market offering program; including a forward sales component. The compensation paid to the ~~periods~~selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. PPL issued 4.2 million shares of common stock and received gross proceeds of $119 million for the nine months ended September 30, ~~PPL issued the following:~~

Three Months Nine Months
2017 2016 2017 2016
Number of shares (in thousands) 2,049
710
5,526
710
Average share price $ 39.04
$ 35.23
$ 38.49
$ 35.23
Net Proceeds $ 79
$ 25
$ 211
$ 25
2018.

Distributions

In August ~~2017,~~2018, PPL declared a quarterly common stock dividend, payable October ~~2, 2017,~~1, 2018, of ~~39.5~~41.0 cents per share (equivalent to ~~$1.58~~$1.64 per annum). Future dividends, declared at the discretion of the Board of Directors, will depend upon future earnings, cash flows, financial and legal requirements and other factors.

8.9. Defined Benefits

(PPL, LKE and LG&E)

Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense and regulatory assets, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended September 30:

Pension Benefits
Three Months Nine Months
U.S. U.K. U.S. U.K.
2017 2016 2017 2016 2017 2016 2017 2016
PPL
Service cost $ 17
$ 16
$ 20
$ 17
$ 49
$ 49
$ 57
$ 53
Interest cost 42
44
45
58
126
131
132
182
Expected return on plan assets (58 ) (57 ) (130 ) (124 ) (173 ) (171 ) (382 ) (389 )
Amortization of:
Prior service cost 2
2
—
—
7
6
—
—
Actuarial loss 18
12
36
34
52
37
107
107
Net periodic defined benefit costs (credits) before settlements and special termination benefits 21
17
(29 ) (15 ) 61
52
(86 ) (47 )
Settlements (a) 7
3
—
—
7
3
—
—
Special termination benefits (b) —
—
—
—
1
—
—
—
Net periodic defined benefit costs (credits) $ 28
$ 20
$ (29 ) $ (15 ) $ 69
$ 55
$ (86 ) $ (47 )

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	Pension Benefits
	Three Months												Nine Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	17		$	21		$	20		$	46		$	49		$	63		$	57
Interest cost	39			42			46			45			117			126			140			132
Expected return on plan assets	(62		)	(58		)	(145		)	(130		)	(186		)	(173		)	(445		)	(382		)
Amortization of:
Prior service cost	2			2			—			—			7			7			—			—
Actuarial loss	22			18			37			36			63			52			114			107
Net periodic defined benefit costs (credits) before settlements and special termination benefits	16			21			(41		)	(29		)	47			61			(128		)	(86		)
Settlements (a)	—			1			—			—			—			1			—			—
Special termination benefits (b)	—			—			—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	16		$	22		$	(41	)	$	(29	)	$	47		$	63		$	(128	)	$	(86	)

(a)

~~2017 includes settlement charges~~Due to the amount of ~~$5 million~~lump sum payment distributions from the LG&E qualified pension plan, ~~and $2 million from the PPL non-qualified pension plan and 2016 includes~~ a settlement charge of $3$1 million ~~from the PPL non-qualified pension plan. These settlements resulted from lump sum payments that exceeded service cost~~ and ~~interest cost components of net periodic pension cost~~$5 million for the ~~year.~~three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 2017 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.


(b)	Enhanced pension benefits offered to certain PPL Electric bargaining unit employees under a one-time voluntary retirement window offered as part of the new five year IBEW contract ratified in March 2017.

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Pension Benefits
Three Months Nine Months
2017 2016 2017 2016
LKE
Service cost $ 6
$ 6
$ 18
$ 18
Interest cost 17
18
51
53
Expected return on plan assets (23 ) (23 ) (69 ) (68 )
Amortization of:
Prior service cost 2
2
6
6
Actuarial loss (a) 8
5
23
15
Net periodic defined benefit costs before settlements 10
8
29
24
Settlements (b) 5
—
5
—
Net periodic defined benefit costs $ 15
$ 8
$ 34
$ 24

LG&E
Service cost $ —
$ —
$ 1
$ 1
Interest cost 3
4
9
11
Expected return on plan assets (5 ) (5 ) (16 ) (15 )
Amortization of:
Prior service cost 1
1
3
3
Actuarial loss (a) 3
2
7
5
Net periodic defined benefit costs before settlements 2
2
4
5
Settlements (b) 5
—
5
—
Net periodic defined benefit costs $ 7
$ 2
$ 9
$ 5



	Pension Benefits
	Three Months						Nine Months
	2018			2017			2018			2017
LKE
Service cost	$	6		$	6		$	18		$	18
Interest cost	16			17			48			51
Expected return on plan assets	(25		)	(23		)	(76		)	(69		)
Amortization of:
Prior service cost	3			2			7			6
Actuarial loss (a)	8			8			26			23
Net periodic defined benefit costs (b)	$	8		$	10		$	23		$	29

(a)

As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LKE's accounting policy and actuarial loss calculated using a 15-year amortization period was $2 million and $8 million for the three and nine months ended September 30, 2018 and $3 million and $8 million for the three and nine months ended September 30, ~~2017 and $4 million for the nine months ended September 30, 2016. The~~2017. This difference between actuarial loss calculated in accordance with LG&E's accounting policy and actuarial loss calculated using a 15-year amortization period was $1 million and $3 million for the three and nine months ended September 30, 2017 and $1 million for the three months ended September 30, 2016. These differences areis recorded as a regulatory ~~assets.~~

asset.

(b)

Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $1 million and $5 million for the three and nine months ended September 30, 2018 and $5 million for the three and nine months ended September 30, 2017 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.

Other Postretirement Benefits
Three Months Nine Months
2017 2016 2017 2016
PPL
Service cost $ 2
$ 2
$ 6
$ 6
Interest cost 5
6
17
19
Expected return on plan assets (6 ) (6 ) (17 ) (17 )
Amortization of prior service cost —
—
(1 ) —
Amortization of actuarial loss 1
1
1
1
Net periodic defined benefit costs $ 2
$ 3
$ 6
$ 9



	Pension Benefits
	Three Months						Nine Months
	2018			2017			2018			2017
LG&E
Service cost	$	—		$	—		$	1		$	1
Interest cost	3			3			9			9
Expected return on plan assets	(6		)	(5		)	(17		)	(16		)
Amortization of:
Prior service cost	1			1			4			3
Actuarial loss (a)	2			3			5			7
Net periodic defined benefit costs (b)	$	—		$	2		$	2		$	4

(a)

As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LG&E's accounting policy and actuarial loss calculated using a 15-year amortization period was $1 million for the nine months ended September 30, 2018 and $1 million and $3 million for the three and nine months ended September 30, 2017. This difference is recorded as a regulatory asset.

(b)



	Other Postretirement Benefits
	Three Months						Nine Months
	2018			2017			2018			2017
PPL
Service cost	$	1		$	2		$	5		$	6
Interest cost	5			5			15			17
Expected return on plan assets	(4		)	(6		)	(17		)	(17		)
Amortization of prior service cost	—			—			—			(1		)
Amortization of actuarial loss	—			1			—			1
Net periodic defined benefit costs	$	2		$	2		$	3		$	6

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	Other Postretirement Benefits												Other Postretirement Benefits
	Three Months						Nine Months						Three Months						Nine Months
	2017			2016			2017			2016			2018			2017			2018			2017
LKE
Service cost	$	1		$	1		$	3		$	3		$	1		$	1		$	3		$	3
Interest cost	2			2			6			7			2			2			6			6
Expected return on plan assets	(2		)	(2		)	(5		)	(5		)	(2		)	(2		)	(6		)	(5		)
Amortization of prior service cost	1			1			1			2
Amortization of:
Prior service cost													—			1			1			1
Actuarial gain													—			—			(1		)	—
Net periodic defined benefit costs	$	2		$	2		$	5		$	7		$	1		$	2		$	3		$	5

(PPL Electric, LG&E and KU)

In addition to the specific plan it sponsors, LG&E is allocated costs of defined benefit plans sponsored by LKE. PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric is allocated costs of defined benefit plans sponsored by PPL Services and KU is allocated costs of defined benefit plans sponsored by LKE. LG&E and KU are also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 1011 for ~~more~~additional information on costs allocated to LG&E and KU from LKS. These allocations are based on participation in those plans, which management believes are reasonable. For the periods ended September 30, PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU:


	Three Months				Nine Months				Three Months				Nine Months
	2017		2016		2017		2016		2018		2017		2018		2017
PPL Electric	$	6	$	6	$	19	$	17	$	5	$	6	$	12	$	19
LG&E	3		2		8		7		1		3		5		8
KU	2		2		7		8		1		2		3		7

~~Expected Cash Flows - U.K. Pension Plans~~(All Registrants)

~~(PPL)~~

~~For~~The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the ~~nine months ended September 30, 2017, WPD contributed $485 million to its U.K. pension plans. These contributions fund all~~Statements of ~~2017 contributions and a portion of 2018 contributions. WPD does not expect to make~~Income. See Note 12 for additional ~~contributions in 2017.~~information.

9.10. Commitments and Contingencies

Legal Matters

(All Registrants)

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

~~WKE Indemnification~~Claim by Former Affiliate( (PPL)

On October 29, 2018, Talen Montana, LLC ("Talen Montana") filed a complaint against PPL and ~~LKE)~~

certain of its affiliates and current and former officers and directors in the First Judicial District of the State of Montana, County of Lewis & Clark. On the same day, Talen Montana Retirement Plan and certain other creditors of Talen Montana filed a complaint against PPL and certain of its affiliates and current and former officers and directors in the Sixteenth Judicial District of the State of Montana, Rosebud County. Talen Montana became a wholly owned subsidiary of Talen Energy as a result of the June 2015 spinoff of PPL Energy Supply. Talen Energy has owned and operated Talen Montana's business since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. See ~~footnote (e)~~Note 8 to the ~~table~~Consolidated Financial Statements in ~~"Guarantees~~PPL's 2017 Form 10-K for a description of the 2015 spinoff of PPL Energy Supply. Riverstone subsequently acquired the remaining interests in Talen Energy in 2016.

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The complaints allege that in 2014 PPL and ~~Other Assurances" below for information on an LKE indemnity relating~~its officers and directors improperly distributed $733 million of the proceeds from the November 2014 sale of Talen Montana's (then PPL Montana's) hydroelectric generating facilities to PPL's subsidiaries. The complaints also allege that PPL and certain current and former officers and directors of PPL and its ~~former WKE lease, including related legal proceedings.~~subsidiaries breached their fiduciary duties in connection with the 2014 distribution. PPL believes that the referenced 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent upon the 2014 distribution. Additionally, in the agreements entered into with respect to the spinoff, affiliates of Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds from the November 2014 sale of PPL Montana's hydroelectric generating facilities. PPL believes that it has good and meritorious defenses to these claims and fully plans to vigorously defend against these actions. At this time, PPL cannot predict the outcome 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, LKE and LG&E)

In December 2013, six 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 ~~RCRA. In addition, these plaintiffs assert~~ 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

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for a class consisting of residents within four miles of the Cane Run ~~plant.~~plant, which retired three coal-fired units in 2015. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In ~~response to a motion to dismiss filed by PPL and LG&E, in~~ July 2014, the court dismissed the ~~plaintiffs'~~ RCRA claims and all but one 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~~Order dismissing PPL as a defendant and dismissing the final federal claim against LG~~&E under~~&E. In April 2017, the Clean Air Act, and directed the parties to submit briefs regarding whether the court should continue to exercise supplemental jurisdiction regarding the remaining state law-only claims. On April 13, 2017, theU.S. District Court issued an ~~order~~Order declining to exercise supplemental jurisdiction on the state law claims and ~~dismissing~~dismissed the case in its ~~entirety, subject to certain federal appeals or state court re-filing rights of the parties. On~~entirety. In June ~~16,~~ 2017, the plaintiffs filed a class action complaint in Jefferson County, Kentucky Circuit Court, ~~Kentucky,~~ against LG&E ~~regarding the~~alleging state law nuisance, negligence and trespass tort claims. The plaintiffs seek compensatory and punitive damages for alleged property damage due to purported plant emissions on behalf of a class of residents within one to three miles of the plant. Proceedings are currently underway regarding potential class certification, for which a decision may occur in late 2018 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~~matter and ~~the remaining two coal-fired units at the plant in June 2015.~~an estimate or range of possible losses cannot be determined.

E.W. Brown Environmental Claims (PPL, LKE and KU)

On July 12, 2017, the Kentucky Waterways Alliance and the Sierra Club filed a citizen suit complaint against KU in the U.S. District Court for the Eastern District of Kentucky (U.S. District Court) alleging discharges at the E.W. Brown plant in violation of the Clean Water Act and the plant’s water discharge permit and alleging contamination that may present an imminent and substantial endangerment in violation of the RCRA. The plaintiffs’ suit relates to prior notices of intent to file a citizen suit submitted in October and November 2015 and October 2016. These plaintiffs ~~seek~~sought injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act ~~violations,~~and RCRA, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also ~~seek~~sought assessment of civil penalties and an award of litigation costs and attorney fees. On December 28, 2017 the U.S. District Court issued an Order dismissing the Clean Water Act and RCRA complaints against KU in their entirety. On January 26, 2018, the plaintiffs appealed the dismissal Order to the U.S. Court of Appeals for the Sixth Circuit. The case has been briefed and oral argument was presented on August 2, 2018. On September 24, 2018, the U.S. Court of Appeals for the Sixth Circuit issued its ruling affirming the lower court's decision to dismiss the Clean Water Act claims and reversing its dismissal of the RCRA claims against KU and remanding the latter to the U.S. District Court. On October 9, 2018, KU filed a petition for rehearing to the U.S. Court of Appeals for the Sixth Circuit regarding the RCRA claims. PPL, LKE and KU cannot predict the outcome of ~~this matter~~these matters and an estimate or ~~the potential impact on the operations~~range of possible losses cannot be determined.

KU is undertaking extensive remedial measures at the E.W. Brown plant including ~~increased capital or operating costs, if any.~~

~~(PPL, LKE, LG&E~~closure of the former ash pond, implementation of a groundwater remedial action plan and ~~KU)~~

~~Trimble County Water Discharge Permit~~

~~In May 2010, the Kentucky Waterways Alliance~~performance of a corrective action plan including aquatic study of adjacent surface waters and ~~other environmental groups filed~~risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a ~~petition~~2017 agreed Order with the Kentucky Energy and Environment Cabinet (KEEC) ~~challenging the Kentucky Pollutant Discharge Elimination System permit issued~~. KU conducted sampling of Herrington Lake in ~~April 2010, which covers water discharges from the Trimble County plant. In November 2010,~~late 2017 through mid-2018. A final report of KU’s findings is expected to be submitted to the KEEC ~~issued a final order upholding~~in 2019. KU believes that current and planned measures for the ~~permit, which was subsequently appealed~~E.W. Brown plant, including closure of impoundments, cessation of certain discharges, and deployment of new discharge controls, are sufficient to ensure compliance with applicable requirements. However, until completion of the aquatic study and related assessments and issuance of regulatory determinations by the ~~environmental groups. In September 2013,~~KEEC, PPL, LKE and KU are unable to determine whether additional remedial measures will be required at the ~~Franklin Circuit Court reversed the KEEC order upholding the permit and remanded the permit to the agency for further proceedings. LG&E and the KEEC appealed the order to the Kentucky Court~~E.W. Brown plant.

Table of Appeals. In July 2015, the Court of Appeals upheld the lower court ruling. LG&E and the KEEC moved for discretionary 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.Contents

~~Trimble County Landfill~~

Various state and federal permits and regulatory approvals are required in order to construct a landfill at the Trimble County plant to be used for disposal of CCRs. In October 2016, the Kentucky Division of Water issued a water quality certification and in February 2017, the Kentucky Division of Waste Management issued a “special waste” landfill permit. In March 2017, the Sierra Club and a resident adjacent to the plant filed administrative challenges to the landfill permit which were subsequently dismissed by agreed order entered in August 2017. In June 2017, the U.S. Army Corps of Engineers issued a dredge and fill permit, the final approval required for construction of the landfill. PPL, LKE, LG&E and KU believe that all permits and regulatory approvals issued for the project comply with applicable state and federal laws.

Regulatory Issues (All Registrants)

See Note 67 for information on regulatory matters related to utility rate regulation.

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Electricity - Reliability Standards

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

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

PPL Electric, LG&E 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 ~~cannot~~an estimate aor range of ~~reasonably~~ possible losses ~~if any.~~cannot be determined.

Environmental Matters

(All Registrants)

Due to the environmental issues discussed below or other environmental matters, it may be necessary for the Registrants to modify, curtail, replace or cease operation of certain facilities or performance of certain operations to comply with statutes, regulations and other requirements of regulatory bodies or courts. In addition, legal challenges to new environmental permits or rules add to the uncertainty of estimating the future cost of these permits and rules. Finally, the regulatory reviews specified in the President's March 2017 Executive Order (the March 2017 Executive Order) promoting energy independence and economic growth could result in future regulatory changes and additional uncertainty.

WPD's distribution businesses are subject to certain statutory and regulatory environmental requirements. It may be necessary for WPD to incur significant compliance costs, which costs may be recoverable through rates subject to the approval of Ofgem. PPL believes that WPD has taken and continues to take measures to comply with all applicable environmental laws and regulations.

LG&E and KU are entitled to recover, through the ECR mechanism, certain costs of complying with the Clean Air Act, as amended, and those federal, state or local environmental requirements applicable to coal combustion wastes and by-products from facilities that generate electricity from coal in accordance with approved compliance plans. Costs not covered by the ECR mechanism for LG&E and KU and all such costs for PPL Electric are subject to rate recovery before the companies' respective state regulatory authorities, or the FERC, if applicable. Because neither WPD nor PPL Electric owns any generating plants, their exposure to related environmental compliance costs is reduced. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.

Air

(PPL, LKE, LG&E and KU)

NAAQS

The Clean Air Act, which regulates air pollutants from mobile and stationary sources in the United States, has a significant impact on the operation of fossil fuel generation plants. Among other things, the Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six pollutants to protect public health and welfare. The six pollutants are carbon monoxide, lead, nitrogen dioxide, ozone (contributed to by nitrogen oxide emissions), particulate matter

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and sulfur dioxide. The established concentration levels for these six pollutants are known as NAAQS. Under the Clean Air Act, the EPA is required to reassess the NAAQS on a five-year schedule.

Federal environmental regulations of these six pollutants require states to adopt implementation plans, known as state implementation plans, which detail how the state will attain the standards that are mandated by the relevant law or regulation.

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Each state identifies the areas within its boundaries that meet the NAAQS (attainment areas) and those that do not (non-attainment areas), and must develop a state implementation plan both to bring non-attainment areas into compliance with the NAAQS and to maintain good air quality in attainment areas. In addition, for attainment of ozone and fine particulates standards, states in the eastern portion of the country, including Kentucky, are subject to a regional program developed by the EPA known as the Cross-State Air Pollution Rule. The NAAQS, future revisions to the NAAQS and state implementation plans, or future revisions to regional programs, may require installation of additional pollution controls, the costs of which PPL, LKE, LG&E and KU believe are subject to cost recovery.

Although PPL, LKE, LG&E and KU do not anticipate significant costs to comply with these programs, changes in market or operating conditions could result in different costs than anticipated.

Ozone

The EPA issued the current ozone standard in October 2015. ~~Under the Clean Air Act, the~~The states and the EPA are required to determine (based on ambient air monitoring data) those areas that meet the standard and those that are in ~~non-attainment.~~nonattainment. The EPA was scheduled to designate areas as being in attainment or nonattainment of the current ozone standard by no later than October 2017 which was to be followed by further regulatory proceedings identifying compliance measures and deadlines. However, the current implementation and compliance schedule is uncertain because the EPA failed to make nonattainment ~~demonstrations~~designations by the applicable deadline. In addition, some industry groups have requested the EPA to defer implementation of the 2015 ozone standard, but the EPA has not yet acted on this request. ~~While~~Although implementation of the 2015 ozone standard could potentially require the addition of SCRs at some LG&E and KU generating units, PPL, LKE, LG&E and KU are currently unable to determine what the compliance measures and deadlines may ultimately be with respect to the new standard.

States are also obligated to address interstate transport issues associated with ozone standards through the establishment of "good neighbor" state implementation plans for those states that are found to contribute significantly to another state's non-attainment. As a result of a partial consent decree addressing claims regarding federal implementation, the EPA and several states, including Kentucky, ~~are evaluating~~have evaluated the need for further nitrogen oxide reductions from fossil-fueled plants to address interstate impacts. ~~While~~On August 23, 2018, Kentucky submitted a proposed state implementation plan finding that no additional reductions beyond existing and planned controls set forth in Kentucky's existing State Implementation Plan are necessary to prevent Kentucky from contributing significantly to any other state’s nonattainment. On September 14, 2018, the EPA announced its denial of petitions filed by Maryland and Delaware alleging that states including Kentucky and Pennsylvania contribute to nonattainment in the petitioning states. PPL, LKE, LG&E and KU are unable to predict the outcome of ongoing and future evaluations by the EPA and the states, or whether such evaluations could potentially result in requirements for nitrogen oxide reductions beyond those currently required under the ~~Cross State~~Cross-State Air Pollution Rule.

Sulfur Dioxide

In 2010, the EPA issued the current NAAQS for sulfur dioxide and required states to identify areas that meet those standards and areas that are in ~~"non-attainment".~~nonattainment. In July 2013, the EPA finalized ~~non-attainment~~nonattainment designations for parts of the country, including part of Jefferson County in Kentucky. ~~Attainment must be achieved by 2018.~~ As a result of scrubber replacements completed by LG&E at the Mill Creek plant in 2016, all Jefferson County monitors now indicate compliance with the sulfur dioxide standards. Additionally, LG&E accepted a new sulfur dioxide emission limit to ensure continuing compliance with the NAAQS. PPL, LKE, LG&E and KU do not anticipate any further measures to achieve compliance with the new sulfur dioxide standards.

Climate Change

There is continuing world-wide attention focused on issues related to climate change. In June 2016, President Obama announced that the United States, Canada and Mexico established the North American Climate, Clean Energy, and Environment Partnership Plan, which specifies actions to promote clean energy, address climate change and protect the environment. The plan includes a goal to provide 50% of the energy used in North America from clean energy sources by 2025. The plan does not impose any nation-specific requirements.

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In December 2015, 195 nations, including the U.S., signed the Paris Agreement on Climate, which establishes a comprehensive framework for the reduction 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 ~~Clean Power Plan described below,~~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.

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Additionally, ~~in March 2017,~~ the ~~President issued an Executive Order (the~~ March 2017 Executive ~~Order) directing~~Order directed the EPA to review ~~proposed and final~~its 2015 greenhouse gas rules ~~relating to GHG reductions~~ for consistency with certain policy directives and suspend, revise, or rescind those rules as appropriate. The March 2017 Executive Order also directs rescission of specified guidance, directives, and prior Presidential actions regarding climate change. PPL, LKE, LG&E and KU cannot predict the outcome of such regulatory actions or the impact, if any, on plant operations, rate treatment or future capital or operating needs.

The U.K. has enacted binding carbon reduction requirements that are applicable to WPD. Under the U.K. law, WPD must purchase carbon allowances to offset emissions associated with WPD's operations. The cost of these allowances is not significant and is included in WPD's current operating expenses.

The EPA's Rules under Section 111 of the Clean Air Act, including the EPA's Proposed Affordable Clean ~~Power Plan~~Energy Rule

~~As further described below, in~~In 2015, the EPA finalized rules imposing GHG emission standards for both new and existing power ~~plants. The EPA has also issued~~plants and proposed a ~~proposed~~ federal implementation plan that would apply to any states that ~~fail~~failed to submit an acceptable state implementation plan ~~under these rules.~~to reduce GHG emissions on a state-by-state basis (the 2015 EPA Rules).

On August 21, 2018, the EPA proposed the Affordable Clean Energy Act (ACE) Rule as a replacement for the 2015 EPA Rules pertaining to existing sources. The ~~future~~EPA took this action following legal challenges to the 2015 EPA Rules, a stay of ~~these~~those rules is uncertain. The EPA's authority to promulgate these regulations under Section 111 of the Clean Air Act has been challenged in the D.C. Circuit Court by several states, industry groups and individual companies, including LKE. The D.C. Circuit has temporarily held the litigation in abeyance in light of the EPA's ongoing review of the Clean Power Plan. In February 2016, the U.S. Supreme Court stayed the rule for existing plants (the Clean Power Plan) pending the D.C. Circuit Court's review and subsequent review by the U.S. Supreme Court, if a ~~writ of certiorari is filed and granted. In addition, the President's~~ March 2017 Executive Order ~~requires~~requiring the EPA to review those rules and the ~~rules for new plants and existing power plants and suspend, revise or rescind them as appropriate. In~~EPA’s October 2017 ~~the EPA proposed~~proposal to rescind the ~~rule and may seek comment on~~rules. The ACE Rule would give states broad latitude in establishing emission guidelines providing for plant-specific efficiency upgrades or “heat-rate improvements” that would reduce GHG emissions per unit of electricity generated. The ACE Rule proposes a ~~possible replacement rule.~~

~~The EPA's rule for new~~list of “candidate technologies” that would be considered in establishing standards of performance at individual power plants imposes separate emission standards for coal and natural gas units based on the application of different technologies. The coal standard is based on the application of partial carbon capture and sequestration technology, but because this technology is not presently commercially viable, the rule effectively precludes the construction of new coal-fired plants. The ~~standard~~ACE Rule also proposes new criteria for ~~NGCC power plants is the same as what the EPA proposed in 2012~~determining whether such efficiency projects would trigger New Source Review and ~~is not continuously achievable under all operating modes, such as frequent start-ups and shutdowns. The preclusion of new coal-fired plants could have a significant industry-wide impact.~~

The EPA's rule for existing power plants, referred to as the Clean Power Plan, was published in the Federal Register in October 2015. The Clean Power Plan contains state-specific rate-based and mass-based reduction goals and guidelines for the development, submission and implementation of state implementation plans to achieve the state goals. State-specific goals were calculated from 2012 data by applying the EPA's broad interpretation and definition of the BSER, resulting in the most stringent targets to be met in 2030, with interim targets to be met beginning in 2022. The EPA believes it has offered some flexibility to the states as to how their compliance plans can be crafted, including the option to use a rate-based approach (limit emissions per megawatt hour) or a mass-based approach (limit total tons of emissions per year), and the option to demonstrate compliance through emissions trading and multi-state collaborations. Under the rate-based approach, Kentucky would need to make a 41% reduction from its 2012 emissions rate and under a mass-based approach it would need to make a 36% reduction. These reductions are significantly greater than initially proposed and present significant challenges to the state. If the Clean Power Plan ultimately remains in place in its current form, and Kentucky fails to develop an approvable implementation plan by the applicable deadline, the EPA may impose a federal implementation plan that could be more stringent than what the state plan might provide. Depending on the provisions of the Kentucky implementation plan, LG&E and KU may need to modify their current portfolio of generating assets during the next decade and/or participate in an allowance trading program.

LG&E and KU are monitoring developments at the state and federal level. PPL, LKE, LG&E and KU cannot predict the outcome of the pending litigation, any changes in regulations, interpretations, or litigation positions that may be implemented by the U.S. presidential administration or the potential impact, if any, on plant operations, or future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, wouldthus be subject to ~~cost recovery.~~more stringent emission controls.

In April 2014, the Kentucky General Assembly passed legislation limiting the measures that the Kentucky Energy and Environment Cabinet may consider in setting performance standards to comply with the ~~EPA's regulations governing GHG emissions from existing sources,~~2015 EPA Rules, if enacted. The legislation provides that such state GHG performance standards will be based on emission reductions, efficiency measures and other improvements available at each power plant, rather than renewable energy, end-use energy efficiency, fuel switching and re-dispatch. These statutory restrictions ~~may make it more difficult for Kentucky to achieve~~are broadly consistent with the ~~GHG reduction levels~~EPA's proposed ACE Rule.

LG&E and KU are monitoring developments at the state and federal level. Until the ACE Rule is finalized and the state determines implementation measures PPL, LKE, LG&E and KU cannot predict the potential impact, if any, on plant operations, future capital or operating costs. PPL, LKE, LG&E and KU believe that the ~~EPA has established for Kentucky, if enacted.~~

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costs, which could be significant, would be subject to rate recovery.

Sulfuric Acid Mist Emissions (PPL, LKE and LG&E)

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. Discussions between the EPA and LG&E are ongoing. The parties have entered into a tolling agreement with respect to this matter through December 2018. PPL, LKE and LG&E are unable to predict the outcome of this matter or the potential impact on operations of the Mill Creek plant, including increased capital or operating costs, and potential civil penalties or remedial measures, if any.

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Water/Waste

(PPL, LKE, LG&E and KU)

CCRs

In April 2015, the EPA published its final rule regulating CCRs. CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes. The rule became effective in October 2015. It imposes extensive new requirements, including location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements on CCR impoundments and landfills that are located on active power plants in the United States and not closed. Under the rule, CCRs are regulated as non-hazardous under Subtitle D of RCRA and beneficial use of CCRs is allowed, with some restrictions. The rule's requirements for covered CCR impoundments and landfills include implementation of groundwater monitoring and commencement or completion of closure activities generally between three and ten years from certain triggering events. The rule requires posting of compliance documentation on a publicly accessible website. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which are pending before the D.C. Circuit Court of Appeals.

~~Recently enacted federal legislation has authorized~~ On March 1, 2018, the EPA proposed amendments to ~~approve equally protective state programs~~the CCR rule primarily relating to impoundment closure and remediation requirements. On July 30, 2018, the EPA published in the Federal Register a final rule extending the deadline for closure of certain impoundments to October 2020 and adopting substantive changes relating to certifications, suspensions of groundwater monitoring and groundwater protection standards for certain constituents. The EPA has announced that ~~would operate~~additional amendments to the rule will be proposed in ~~lieu~~late 2018. On August 21, 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR ~~Rule.~~ rule including provisions allowing unlined impoundments to continue operating and exempting inactive impoundments at inactive plants from regulation. PPL, LKE, LG&E and KU are unable to predict the outcome of the ongoing rulemaking 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 matters, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. In May 2017, a resident adjacent to LG&E's and KU's Trimble County plant filed a lawsuit in ~~state court~~Franklin County, Kentucky Circuit Court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. ~~PPL, LKE,~~On January 31, 2018, the state court issued an opinion invalidating certain procedural elements of the new rule but finding the substantive requirements of the new rule to be consistent with those of the federal CCR rule. This ruling was not appealed by any party to the litigation and is now final. Accordingly, LG&E and KU ~~cannot predict the outcome of the litigation, but anticipate continued operation~~presently operate their facilities under continuing permits authorized via the former program and do not currently anticipate material impacts as a result of the judicial ruling. Separately, in December 2016, federal legislation was enacted that authorized the EPA to approve equally protective state programs that would operate in lieu of the CCR rule. The Kentucky Energy and Environmental Cabinet has indicated it may propose rules under such authority in the ~~event that the new rule is struck down.~~future.

LG&E and KU ~~have~~ received KPSC approval for a compliance plan providing for ~~construction of additional landfill capacity at~~ the ~~E.W. Brown station,~~ closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, ~~requirements,~~ 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 requirements. See Note 6 in~~law. On January 26, 2018, KU filed an application requesting a CPCN and approval of amendments to the ~~Registrants' 2016 Form 10-K~~second phase of its compliance plan for ~~additional information.~~the landfill at the E.W. Brown station.On July 9, 2018, the KPSC granted approval to KU for amendments to the second phase of its compliance plan for the landfill at the E.W. Brown station.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs ~~during~~beginning in 2015 ~~2016~~ and ~~2017.~~continue to record adjustments as required. See Note 1516 below and Note 19 in the Registrants' ~~2016~~2017 Form 10-K 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 subject to rate recovery.

Clean Water Act

Regulations under the federal Clean Water Act dictate permitting and mitigation requirements for facilities and construction projects in the United States. Many of those requirements relate to power plant operations, including requirements related to 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, standards intended to protect aquatic organisms that

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become trapped at or pulled through cooling water intake structures at generating facilities. The requirements could impose significant costs for LG&E and KU, which are subject to rate recovery.

~~Table~~Litigation is currently pending in various courts relating to whether Clean Water Act jurisdiction covers discharges of ~~Contents~~

contaminated groundwater that reach surface water via a direct hydrologic connection. Courts in different jurisdictions have come to contrary conclusions in the past. On February 20, 2018, the EPA issued a notice requesting comment on the scope of discharges subject to regulation under the Clean Water Act. Specifically, the EPA seeks comments on whether Clean Water Act jurisdiction should cover discharges to groundwater that reach surface water via a direct hydrologic connection. Extending Clean Water Act jurisdiction to such discharges could potentially subject certain releases from CCR impoundments to additional permitting and remediation requirements. PPL, LKE, LG&E and KU are unable to predict the future regulatory developments or potential impacts on current LG&E and KU compliance plans.

ELGs

In September 2015, the EPA released its final ELGs for wastewater discharge permits for new and existing steam electric generating facilities. The rule provides strict technology-based discharge limitations for control of pollutants in scrubber wastewater, fly ash and bottom ash transport water, mercury control wastewater, gasification wastewater and combustion residual leachate. The new guidelines require deployment of additional control technologies providing physical, chemical and biological treatment of wastewaters. The guidelines also mandate operational changes including "no discharge" requirements for fly ash and bottom ash transport waters and mercury control wastewaters. The implementation date for individual generating stations will be determined by the states on a case-by-case basis according to criteria provided by the EPA. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which have been 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 published in the Federal Register a proposed rule that would postpone the compliance date for requirements relating to bottom ash transport waters and scrubber wastewaters discharge limits. The EPA expects to complete its reconsideration of best available technology standards by the fall of 2020. Upon completion of the ongoing regulatory proceedings, the rule will be implemented by the states in the course of their normal permitting activities. LG&E and KU are developing compliance strategies and schedules. PPL, LKE, LG&E and KU are unable to predict the outcome of the EPA's pending reconsideration of the rule or fully estimate compliance costs or timing. Additionally, 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. Costs to comply with ELGs or other discharge limits, which are expected to be significant, are subject to rate recovery.

Seepages and Groundwater Infiltration

~~Seepages or groundwater infiltration have been detected at active and retired wastewater basins and landfills at various LG&E and KU plants.~~In addition to the actions described above, LG&E and KU have completed, or are completing, assessments of seepages or groundwater infiltration at various facilities and have completed, or are working with agencies to implement, further testing, monitoring or abatement measures, where applicable. ~~A range of reasonably possible costs cannot currently be estimated.~~ Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant. LG&E and KU cannot currently estimate a possible loss or range of possible losses related to this matter.

(All Registrants)

Other Issues

In June 2016, the "Frank Lautenberg Chemical Safety Act" took effect as an amendment to the Toxic Substance Control Act (TSCA). The Act made no changes to the pre-existing TSCA rules as it pertains to polychlorinated biphenyls (PCB). The EPA continues to reassess its PCB regulations as part of the 2010 Advanced Notice of Proposed Rulemaking (ANPRM). The EPA's ANPRM rulemaking is to occur in two phases. Only the second part of the rule ~~currently scheduled for November 2017,~~ is applicable to PPL operations. This part of the rule relates to the use of PCBs in electrical equipment and natural gas pipelines, as well as continued use of PCB-contaminated porous surfaces. Although the first rulemaking will not directly affect the Registrants' operations, it may indicate certain approaches or principles to occur in the later rulemaking which may affect Registrants' facilities in the United States, including phase-out of some or all equipment containing PCBs. Should such a phase-out be required, the costs, which are subject to rate recovery, could be significant. Currently, the EPA is planning to undertake the second phase of the rulemaking later in 2018.

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Superfund and Other Remediation

PPL Electric, is potentially responsible for a share of the costs at several sites listed by the EPA under the federal Superfund program, including the Columbia Gas Plant site and the Brodhead site. Clean-up actions have been or are being undertaken at all of these sites, the costs of which have not been, and are not expected to be, significant to PPL Electric.

~~PPL Electric,~~ LG&E and KU are potentially responsible for investigating, responding to agency inquiries, implementing various preventative measures, and/or remediating ~~or have completed~~contamination under programs other than those described in the ~~remediation of, several sites that were not addressed under a regulatory program such as Superfund, but for which PPL Electric, LG&E and KU may be liable for remediation.~~sections above. These include a number of former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated or currently owned by predecessors or affiliates of PPL Electric, LG&E and KU. To date, the costs of these sites have not been significant.

There are additional sites, formerly owned or operated by PPL Electric, LG&E and KU predecessors or affiliates. PPL Electric, LG&E and KU lack sufficient information onabout such additional sites ~~and are therefore unable~~ to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

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~~At September 30, 2017 and December 31, 2016,~~ PPL Electric ~~had~~is potentially responsible for a ~~recorded liability of $10 million representing its best estimate~~share of the ~~probable loss incurred to remediate~~costs at several sites listed by the EPA under the federal Superfund program, including the Columbia Gas Plant site and the Brodhead site. Clean-up actions have been or are being undertaken at all of these sites, ~~noted above. Depending on~~ the ~~outcome~~costs of ~~investigations at sites where investigations~~which have not ~~begun or~~ been, ~~completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred; however, such costs~~and are not expected to be, ~~significant.~~significant to PPL Electric.

The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result of the EPA's evaluation, individual states may establish stricter standards for water quality and soil cleanup. This could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of reasonably possible losses, if any, related to these matters.

From time to time, PPL's subsidiaries in the United States undertake testing, monitoring or remedial action in response to notices of violations, spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary ~~for compliance~~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 Electric, LG&E and KU.

As of September 30, 2018 and December 31, 2017, PPL Electric had a recorded liability of $11 million and $10 million representing its best estimate of the probable loss incurred to remediate the sites noted in this section. Depending on the outcome of investigations at 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; however, such costs are not expected to be significant.

Future cleanup or remediation work ~~at sites under review, or~~ at sites not yet identified may result in significant additional costs for PPL, PPL Electric, LKE, LG&E and KU. Insurance policies maintained by LKE, LG&E and KU may be ~~applicable~~available to cover certain of the costs or other obligations related to these matters but the amount of insurance coverage or reimbursement cannot be estimated or assured.

Other

Labor Union Agreements

~~(PPL and PPL Electric)~~

In March 2017, members of the IBEW ratified a new five-year labor agreement with PPL. The contract covers nearly 1,400 employees and was effective May 22, 2017. The terms of the new labor agreement are not expected to have a significant impact on the financial results of PPL or PPL Electric.

(LKE and KU)

KU has 68 employees that are represented by the IBEW labor union. In August ~~2017,~~2018, KU and the ~~United Steelworkers of America~~IBEW ratified a three-year labor agreement through August ~~2020.~~2021. The agreement ~~covers approximately 53 employees.~~includes a wage reopener in 2020. The terms of the new labor agreement are not expected to have a significant impact on the financial results of LKE or KU.

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Separation Benefits

(PPL and PPL Electric)

In June 2018, PPL EU Services announced it was reorganizing its IT organization into the following new areas: planning, operations, data and information management and IT transformation. Organizational plans and staffing selections for the new IT organization were substantially completed in the third quarter of 2018 which reduced the number of contractors and PPL EU Services’ employees in IT. Affected employees had the option of joining a managed services vendor, applying for a newly created position in IT or opting for severance. As a result, for the nine months ended September 30, 2018, estimated charges for separation benefits of $6 million, which were primarily allocated to PPL Electric, relating to 86 displaced PPL EU Services’ IT employees, was recorded in “Other operation and maintenance” on the Statement of Income and in “Other current liabilities” on the Balance Sheet. The separation benefits include cash severance compensation, lump sum COBRA reimbursement payments, outplacement services and accelerated stock award vesting which are expected to be primarily paid out over various dates into 2019.

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. Such agreements include, for example, guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.

(PPL)

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

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(All Registrants)

The table below details guarantees provided as of September 30, ~~2017.~~2018. "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.~~entities." The total recorded liability at September 30, ~~2017~~2018 was ~~$21~~$6 million for PPL and ~~$16 million~~not significant for LKE. The total recorded liability at December 31, ~~2016~~2017 was ~~$22~~$17 million for PPL and ~~$17~~$11 million for LKE. ~~See footnote (e) below for information regarding a settlement in principle for certain LKE indemnifications.~~ For reporting purposes, on a consolidated basis, all guarantees of PPL Electric, LKE, LG&E and KU also apply to PPL, and all guarantees of LG&E and KU also apply to LKE.

Exposure at
September 30, 2017

Expiration
Date

Exposure at
September 30, 2018

Expiration
Date

PPL

Indemnifications related to the WPD Midlands acquisition

(a)

WPD indemnifications for entities in liquidation and sales of assets

(b)

2019

(b)

2020

WPD guarantee of pension and other obligations of unconsolidated entities

(c)

PPL Electric

Guarantee of inventory value

(d)

2018

(d)

2020

LKE

Indemnification of lease termination and other divestitures

301

(e)

2021 - 2023

200

(e)

2021

LG&E and KU

LG&E and KU guarantee of shortfall related to OVEC

(f)

(a)

Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum ~~exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.~~

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exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.

(b)

Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or are not explicitly stated in the agreements. The indemnifications generally expire two to seven years subsequent to the date of dissolution of the entities. The exposure noted only includes those cases where the agreements provide for specific limits.

In connection with their sales of various businesses, WPD and its affiliates have provided the purchasers with indemnifications that are standard for such transactions, 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 condition that the purchasers make reasonable efforts to terminate the guarantees. Additionally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties.

(c)

Relates to certain obligations of discontinued or modified electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At September 30, ~~2017,~~2018, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.


(d)	A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold.

(e)

LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Another WKE-related LKE guarantee covers other indemnifications related to the purchase price of excess power, has a term expiring in 2023, and a maximum exposure of $100 million. In May 2012, LKE's indemnitee received an unfavorable arbitration panel's decision interpreting this matter. In October 2014, LKE's indemnitee filed a motion for discretionary review with the Kentucky Supreme Court seeking to overturn the arbitration decision, and such motion was denied by the court in September 2015. In September 2015, the counterparty issued a demand letter to LKE's indemnitee. In February 2016, the counterparty filed a complaint in Henderson, Kentucky Circuit Court, seeking an award of damages in the matter. The proceeding is currently in the discovery phase. LKE does not believe appropriate contractual, legal or commercial grounds exist for the claim made. LKE believes its indemnifications in the WKE matter remain subject to various uncertainties, including additional legal and contractual developments, as well as future prices, availability and demand for the subject excess power. Although the parties have conducted certain settlement discussions and reached a settlement in principle to resolve all claims for an aggregate amount within LKE's recorded liability, the ultimate outcomes of the WKE termination-related indemnifications cannot be predicted at this time. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant ~~losses above the amounts recorded.~~losses.

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(f)

Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. LKE's proportionate share of OVEC's outstanding debt was ~~$118~~$114 million at September 30, ~~2017,~~2018, consisting of LG&E's share of ~~$82~~$79 million and KU's share of ~~$36~~$35 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LKE's, LG&E's and KU's ~~2016~~2017 Form 10-K for additional information on the OVEC power purchase contract. In connection with recent credit market related developments at OVEC or certain of its sponsors, such parties, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs. The ultimate outcome of these matters, including any potential impact on LG&E's and KU's obligations relating to OVEC debt under the power purchase contract cannot be predicted.

In March 2018, a sponsor with a pro-rata share of certain OVEC obligations of 4.85% 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 certain sponsors are appealing this action, in addition to pursuing appropriate rejection claims in the bankruptcy proceeding. OVEC and certain of its sponsors, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs, establishing or continuing debt reserve accounts or other changes involving OVEC's existing short and long-term debt. The ultimate outcome of these matters, including the sponsor bankruptcy and related proceedings and any other potential impact on LG&E's and KU's obligations relating to OVEC debt under the power purchase contract cannot be predicted.

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.

~~10.~~11. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other ~~as applicable,~~ with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and 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 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 periods ended September 30, 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.

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Three Months Nine Months
2017 2016 2017 2016
PPL Electric from PPL Services $ 43
$ 33
$ 138
$ 98
LKE from PPL Services 4
4
15
13
PPL Electric from PPL EU Services 15
17
48
50
LG&E from LKS 38
40
120
128
KU from LKS 43
46
134
151



	Three Months				Nine Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	14	$	43	$	45	$	138
LKE from PPL Services	5		4		19		15
PPL Electric from PPL EU Services	34		15		110		48
LG&E from LKS	36		38		113		120
KU from LKS	42		43		127		134

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 ~~overhead costs~~overheads associated with union and hourly employees performing work for the other company, charges related to ~~jointly owned~~jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a ~~$400 million~~ revolving line of credit with a PPL Electric subsidiary. AtIn June 2018, the revolving line of credit was increased by $250 million and the limit as of September 30, ~~2017, $2 million~~2018 was ~~outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet.~~$650 million. No balance was outstanding at September 30, 2018 and December 31, ~~2016.~~2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread. ~~The interest rate on the outstanding borrowing at September 30, 2017 was 2.98%.~~

~~Table of Contents~~

(LKE)

LKE maintains a ~~$225~~$300 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. In October 2018, the revolving line of credit was increased by $75 million to a limit of $375 million. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At September 30, ~~2017~~2018 and December 31, ~~2016, $159~~2017, $80 million and ~~$163~~$225 million were outstanding and reflected in "Notes payable with ~~affiliate"~~affiliates" on the Balance Sheets. The interest rates on the outstanding ~~borrowing~~borrowings at September 30, ~~2017~~2018 and December 31, ~~2016~~2017 were ~~2.73%~~3.61% and ~~2.12%~~2.87%.

LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market based rates. No balance was outstanding at September 30, 2018 and December 31, 2017. The interest rate on the loan is based on the PPL affiliates credit rating and equal to one-month LIBOR plus a spread.

LKE maintains a $400 million ten-year note with a PPL affiliate with an interest rate of 3.5%. At September 30, ~~2017~~2018 and December 31, ~~2016,~~2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets.

~~(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 million~~ ~~at an interest rate based on a market index of commercial paper issues. At September 30, 2017,~~ ~~$10 million~~ was outstanding and was reflected in "Notes payable with affiliate" on the Balance Sheet. No balances were outstanding at December 31, 2016. The interest rate on the outstanding borrowings at September 30, 2017 was ~~1.46%~~. Interest expense ~~incurred~~ on ~~the money pool agreement with KU~~this note was ~~not significant~~$4 million and $11 million for the three and nine months ~~ended~~ending September 30, 2018 and 2017.

~~(KU)~~

~~KU participates~~In May 2018, LKE borrowed $250 million from a PPL affiliate through the issuance of a 4% ten-year note due 2028 with interest due in ~~an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues.~~May and November. At September 30, ~~2017, KU had no payable balance outstanding, but had a $10 million receivable balance outstanding, which~~2018, the note was reflected in ~~"Notes receivable from~~"Long-term debt to affiliate" on the Balance ~~Sheet. No balances~~Sheets. The proceeds were used to repay its outstanding ~~at December 31, 2016. The interest rate~~notes payable with a PPL Energy Funding subsidiary. Interest expense on ~~the outstanding receivable at September, 30, 2017~~this note was ~~1.46%. Interest income incurred on the money pool agreement with LG&E was not significant~~$3 million and $4 million for the three and nine months ~~ended~~ending September 30, ~~2017.~~2018.

Other (PPL Electric, LG&E and KU)

See Note 89 for discussions regarding intercompany allocations associated with defined benefits.

See Note 10 for discussions regarding separation benefits.

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~~11.~~12. Other Income (Expense) - net

(PPL)

~~"Other~~The details of "Other Income (Expense) - net" for the ~~three and nine months~~periods ended September 30, ~~2017 and 2016 consisted primarily~~were:



	Three Months					Nine Months
	2018		2017			2018		2017
Other Income
Economic foreign currency exchange contracts (Note 14)	$	40	$	(81	)	$	92	$	(237	)
Defined benefit plans - non-service credits (Note 9)	61		41			195		123
Interest income	3		1			5		2
AFUDC - equity component	5		5			15		11
Miscellaneous	2		2			3		11
Total Other Income	111		(32		)	310		(90		)
Other Expense
Charitable contributions	1		1			6		6
Miscellaneous	4		2			7		16
Total Other Expense	5		3			13		22
Other Income (Expense) - net	$	106	$	(35	)	$	297	$	(112	)

(PPL Electric)

The details of ~~gains (losses) on foreign currency contracts to economically hedge PPL's translation risk related to its GBP denominated earnings in~~"Other Income (Expense) - net" for the ~~U.K. See Note 13 for additional information on these derivatives.~~periods ended September 30, were:



	Three Months				Nine Months
	2018		2017		2018		2017
Other Income
AFUDC - equity component	$	5	$	5	$	15	$	11
Defined benefit plans - non-service credits (Note 9)	1		—		4		—
Miscellaneous	—		—		1		—
Total Other Income	6		5		20		11
Other Expense
Charitable contributions	1		1		2		2
Miscellaneous	—		—		—		1
Total Other Expense	1		1		2		3
Other Income (Expense) - net	$	5	$	4	$	18	$	8

~~12.~~13. Fair Value Measurements

(All Registrants)

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. Transfers between levels are recognized at end-of-reporting-period values. During the three and nine months ended September 30, ~~2017~~2018 and ~~2016,~~2017, there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's ~~2016~~2017 Form 10-K for information on the levels in the fair value hierarchy.

Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

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	September 30, 2017								December 31, 2016								September 30, 2018								December 31, 2017
	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
Assets
Cash and cash equivalents	$	676	$	676	$	—	$	—	$	341	$	341	$	—	$	—	$	842	$	842	$	—	$	—	$	485	$	485	$	—	$	—
Restricted cash and cash equivalents (a)	24		24		—		—		26		26		—		—		22		22		—		—		26		26		—		—
Special use funds (a)																	63		63		—		—		—		—		—		—
Price risk management assets (b):
Foreign currency contracts	164		—		164		—		211		—		211		—		174		—		174		—		163		—		163		—
Cross-currency swaps	160		—		160		—		188		—		188		—		123		—		123		—		101		—		101		—
Total price risk management assets	324		—		324		—		399		—		399		—		297		—		297		—		264		—		264		—
Total assets	$	1,024	$	700	$	324	$	—	$	766	$	367	$	399	$	—	$	1,224	$	927	$	297	$	—	$	775	$	511	$	264	$	—

Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	31	$	—	$	31	$	—	$	31	$	—	$	31	$	—	$	19	$	—	$	19	$	—	$	26	$	—	$	26	$	—
Foreign currency contracts	167		—		167		—		27		—		27		—		30		—		30		—		148		—		148		—
Total price risk management liabilities	$	198	$	—	$	198	$	—	$	58	$	—	$	58	$	—	$	49	$	—	$	49	$	—	$	174	$	—	$	174	$	—

PPL Electric
Assets
Cash and cash equivalents	$	243	$	243	$	—	$	—	$	13	$	13	$	—	$	—	$	414	$	414	$	—	$	—	$	49	$	49	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—		2		2		—		—		2		2		—		—
Total assets	$	245	$	245	$	—	$	—	$	15	$	15	$	—	$	—	$	416	$	416	$	—	$	—	$	51	$	51	$	—	$	—

LKE
Assets
Cash and cash equivalents	$	40	$	40	$	—	$	—	$	13	$	13	$	—	$	—	$	29	$	29	$	—	$	—	$	30	$	30	$	—	$	—
Cash collateral posted to counterparties (c)	1		1		—		—		3		3		—		—
Total assets	$	41	$	41	$	—	$	—	$	16	$	16	$	—	$	—	$	29	$	29	$	—	$	—	$	30	$	30	$	—	$	—

Liabilities
Price risk management liabilities:
Interest rate swaps	$	29	$	—	$	29	$	—	$	31	$	—	$	31	$	—	$	19	$	—	$	19	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	29	$	—	$	29	$	—	$	31	$	—	$	31	$	—	$	19	$	—	$	19	$	—	$	26	$	—	$	26	$	—

LG&E
Assets
Cash and cash equivalents	$	9	$	9	$	—	$	—	$	5	$	5	$	—	$	—	$	11	$	11	$	—	$	—	$	15	$	15	$	—	$	—
Cash collateral posted to counterparties (c)	1		1		—		—		3		3		—		—
Total assets	$	10	$	10	$	—	$	—	$	8	$	8	$	—	$	—	$	11	$	11	$	—	$	—	$	15	$	15	$	—	$	—

Liabilities
Price risk management liabilities:
Interest rate swaps	$	29	$	—	$	29	$	—	$	31	$	—	$	31	$	—	$	19	$	—	$	19	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	29	$	—	$	29	$	—	$	31	$	—	$	31	$	—	$	19	$	—	$	19	$	—	$	26	$	—	$	26	$	—

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	September 30, 2017								December 31, 2016								September 30, 2018								December 31, 2017
	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
KU
Assets
Cash and cash equivalents	$	31	$	31	$	—	$	—	$	7	$	7	$	—	$	—	$	18	$	18	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	31	$	31	$	—	$	—	$	7	$	7	$	—	$	—	$	18	$	18	$	—	$	—	$	15	$	15	$	—	$	—


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


(b)	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.


~~(c)~~	Included in "Other noncurrent assets" on the Balance Sheets. Represents cash collateral posted to offset the exposure with counterparties related to certain interest rate swaps under master netting arrangements that are not offset.

Special Use Funds

(PPL)

The special use funds are investments restricted for paying active union employee medical costs. 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. The funds are invested primarily in money market funds.

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 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.


	September 30, 2017				December 31, 2016				September 30, 2018				December 31, 2017
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	19,558	$	23,357	$	18,326	$	21,355	$	20,254	$	23,023	$	20,195	$	23,783
PPL Electric	3,298		3,724		2,831		3,148		3,693		3,899		3,298		3,769
LKE	5,068		5,592		5,065		5,439		5,501		5,783		5,159		5,670
LG&E	1,619		1,768		1,617		1,710		1,808		1,879		1,709		1,865
KU	2,328		2,602		2,327		2,514		2,320		2,467		2,328		2,605


(a)	Amounts are net of debt issuance costs.

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

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~~13.~~14. Derivative Instruments and Hedging Activities

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

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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.

Interest Rate Risk

PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and WPD hold 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 for certain plans at WPD due to the recovery methods in place.

Foreign Currency Risk (PPL)

PPL is 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 ~~exposed~~required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk ~~from its obligation as PLR; however,~~is insignificant and mitigated through its PUC-approved cost recovery mechanism ~~substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to commodity price risk by entering into~~and full-requirement supply agreements to serve its PLR ~~customers. These supply agreements~~customers which transfer the ~~commodity price~~ risk ~~associated with the PLR obligation~~ to ~~the~~ energy suppliers.

LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and ~~fuel-related expenses.~~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

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

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WPD is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control ~~period,~~regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's ~~2016~~2017 Form 10-K 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.

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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 derivatives with financial institutions, 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.

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 ~~LG&E)~~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 ~~$17~~$25 million obligation to return cash collateral under master netting arrangements at September 30, ~~2017~~2018 and a ~~$19~~$20 million obligation to return cash collateral under master netting arrangements at December 31, ~~2016.~~2017.

PPL had no obligation to post cash collateral under master netting arrangements at September 30, 2018 and December 31, 2017.

LKE, LG&E and ~~LG&E~~KU had no obligation to return cash collateral under master netting arrangements at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

~~PPL,~~ LKE, ~~and~~ LG&E ~~posted $1 million~~ and ~~$3 million of~~KU had no cash collateral posted under master netting arrangements at September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

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 ~~portfolio,~~portfolios, adjust the duration of the debt ~~portfolio~~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

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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. At September 30, ~~2017,~~2018, PPL held an

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aggregate notional value in interest rate swap contracts of ~~£188~~£75 million (approximately ~~$242~~$97 million based on spot rates) that mature in ~~2027~~2026 to hedge the interest payments of ~~anticipated~~ WPD plc's October 2018 debt ~~issuances. These swaps require a mandatory early redemption on or before November 30, 2017.~~issuance.

For the three and nine months ended September 30, 2018 and 2017, PPL had no hedge ineffectiveness associated with interest rate derivatives. For the three months ended September 30, 2016, PPL had no hedge ineffectiveness associated with interest rate derivatives and for the nine months ended September 30, 2016, PPL had an insignificant amount of hedge ineffectiveness associated with interest rate derivatives.

At September 30, ~~2017,~~2018, PPL held an aggregate notional value in cross-currency interest rate swap contracts of ~~$802~~$702 million that range in maturity from ~~2017~~2021 through 2028 to hedge the interest payments and principal of WPD's U.S. dollar-denominated senior notes.

For the three and nine months ended September 30, ~~2017~~2018 and ~~2016,~~2017, PPL had no hedge ineffectiveness associated with cross-currency interest rate swap derivatives.

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

For the three and nine months ended September 30, ~~2017,~~2018, PPL had ~~an insignificant amount of~~no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and nine months ended September 30, ~~2016~~,2017, PPL had noan insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At September 30, ~~2017,~~2018, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded.

Economic Activity (PPL, LKE and LG&E)

LG&E enters into interest rate swap contracts that economically hedge interest payments on variable rate debt. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At September 30, ~~2017,~~2018, LG&E held contracts with a notional amount of $147 million that range in maturity through 2033.

Foreign Currency Risk

(PPL)

PPL is exposed to foreign currency risk, primarily through investments in and earnings of 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 and net investments. In addition, PPL enters into financial instruments to protect against foreign currency translation risk of expected GBP earnings.

Net Investment Hedges

PPL enters into foreign currency contracts on behalf of a subsidiary to protect the value of a portion of its net investment in WPD. ~~The~~There were no contracts outstanding at September 30, ~~2017 had a notional amount of £92 million (approximately $125 million based on contracted rates). These contracts mature in December 2017.~~2018.

At September 30, ~~2017~~2018 and December 31, ~~2016,~~2017, PPL had ~~$22~~$30 million and ~~$21~~$22 million of accumulated net investment hedge after tax gains (losses) that were included in the foreign currency translation adjustment component of AOCI.

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Economic Activity

PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings. At September 30, ~~2017,~~2018, the total exposure hedged by PPL was approximately ~~£2.7~~£1.8 billion (approximately ~~$3.7~~$2.5 billion based on contracted rates). These contracts ~~had~~have termination dates ranging from October ~~2017~~2018 through ~~April~~October 2020.

Accounting and Reporting

(All Registrants)

All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts 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 September 30, ~~2017~~2018 and December 31, ~~2016.~~2017.

See Note 1 in each Registrant's ~~2016~~2017 Form 10-K 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.


	September 30, 2017								December 31, 2016								September 30, 2018								December 31, 2017
	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:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	$	—	$	2	$	—	$	5	$	—	$	—	$	—	$	4	$	—	$	—	$	—	$	4	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	28		—		—		—		32		—		—		—		5		—		—		—		4		—		—		—
Foreign currency contracts	1		—		28		86		—		—		31		21		—		—		86		22		—		—		45		67
Total current	29		2		28		91		32		—		31		25		5		—		86		26		4		—		45		71
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		24		—		—		—		27		—		—		—		15		—		—		—		22
Cross-currency swaps (b)	132		—		—		—		156		—		—		—		118		—		—		—		97		—		—		—
Foreign currency contracts	—		—		135		81		—		—		180		6		—		—		88		8		—		—		118		81
Total noncurrent	132		—		135		105		156		—		180		33		118		—		88		23		97		—		118		103
Total derivatives	$	161	$	2	$	163	$	196	$	188	$	—	$	211	$	58	$	123	$	—	$	174	$	49	$	101	$	—	$	163	$	174


(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.

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the periods ended September 30, ~~2017.~~2018.

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							Three Months						Nine Months																	Three Months								Nine Months
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)			Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)				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)				Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
Derivative Relationships	Three Months		Nine Months									Three Months								Nine Months									Location of Gain (Loss) Recognized in Income on Derivative
Cash Flow Hedges:						Location of Gain (Loss) Recognized in Income on Derivative
Interest rate swaps	$	—	$	(2	)	Interest expense	$	(2	)	$	—				$	(6	)		$	(1	)		$	—			$	—		Interest expense		$	(2	)		$	—			$	(6	)		$	—
Cross-currency swaps	1		(34		)	Interest expense	1			—			1				—				27				26				Interest expense	1				—				1				—
						Other income (expense) - net	2			—			(24		)		—												Other income (expense) - net	18				—				30				—
Total	$	1	$	(36	)		$	1		$	—		$	(29	)		$	(1	)		$	27			$	26				$	17			$	—			$	25			$	—
Net Investment Hedges:
Foreign currency contracts	$	1	$	1																	$	—			$	11


Derivatives Not Designated as	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Nine Months			Income on Derivative	Three Months			Nine Months
Foreign currency contracts	Other income (expense) - net	$	(81	)	$	(237	)	Other income (expense) - net	$	40		$	92
Interest rate swaps	Interest expense	(1		)	(4		)	Interest expense	(1		)	(4		)
	Total	$	(82	)	$	(241	)	Total	$	39		$	88
Derivatives Not Designated as	Location of Gain (Loss) Recognized as							Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Nine Months			Regulatory Liabilities/Assets	Three Months			Nine Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	2		Regulatory assets - noncurrent	$	2		$	7

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the periods ended September 30, ~~2016.~~2017.


							Three Months						Nine Months																	Three Months								Nine Months
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)			Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)				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)				Gain (Loss) Reclassified from AOCI into Income (Effective Portion)				Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)
Derivative Relationships	Three Months		Nine Months									Three Months								Nine Months									Location of Gain (Loss) Recognized in Income on Derivative
Cash Flow Hedges:						Location of Gain (Loss) Recognized in Income on Derivative
Interest rate swaps	$	—	$	(21	)	Interest expense	$	(2	)	$	—				$	(5	)		$	—			$	—			$	(2	)	Interest expense		$	(2	)		$	—			$	(6	)		$	(1	)
Cross-currency swaps	78		87			Interest expense	2			—			2				—				1				(34		)		Interest expense	1				—				1				—
						Other income (expense) - net	86			—			80				—												Other income (expense) - net	2				—				(24		)		—
Total	$	78	$	66			$	86		$	—		$	77			$	—			$	1			$	(36	)			$	1			$	—			$	(29	)		$	(1	)
Net Investment Hedges:
Foreign currency contracts	$	—	$	4																	$	1			$	1



Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Nine Months
Foreign currency contracts	Other income (expense) - net	$	(81	)	$	(237	)
Interest rate swaps	Interest expense	(1		)	(4		)
	Total	$	(82	)	$	(241	)
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Nine Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	2

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Derivatives Not Designated as Location of Gain (Loss) Recognized in
Hedging Instruments Income on Derivative Three Months Nine Months
Foreign currency contracts Other income (expense) - net $ 49
$ 280
Interest rate swaps Interest expense (2 ) (6 )
Total $ 47
$ 274
Derivatives Not Designated as Location of Gain (Loss) Recognized as
Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months
Interest rate swaps Regulatory assets - noncurrent $ 2
$ (7 )

(LKE and LG&E)

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


	September 30, 2017				December 31, 2016				September 30, 2018				December 31, 2017
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4	$	—	$	4	$	—	$	4
Total current	—		5		—		4		—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		24		—		27		—		15		—		22
Total noncurrent	—		24		—		27		—		15		—		22
Total derivatives	$	—	$	29	$	—	$	31	$	—	$	19	$	—	$	26

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, ~~2017.~~2018.


	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Nine Months			Income on Derivatives	Three Months			Nine Months
Interest rate swaps	Interest expense	$	(1	)	$	(4	)	Interest expense	$	(1	)	$	(4	)
	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Nine Months			Regulatory Assets	Three Months			Nine Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	2		Regulatory assets - noncurrent	$	2		$	7

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the periods ended September 30, ~~2016.~~2017.


	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Nine Months			Income on Derivatives	Three Months			Nine Months
Interest rate swaps	Interest expense	$	(2	)	$	(6	)	Interest expense	$	(1	)	$	(4	)
	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Nine Months			Regulatory Assets	Three Months			Nine Months
Interest rate swaps	Regulatory assets - noncurrent	$	2		$	(7	)	Regulatory assets - noncurrent	$	1		$	2

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(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.

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Assets Liabilities
Eligible for Offset Eligible for Offset
Gross
Derivative
Instruments

Cash
Collateral
Received
Net Gross
Derivative
Instruments

Cash
Collateral
Pledged
Net
September 30, 2017
Treasury Derivatives
PPL $ 324
$ 138
$ 17
$ 169
$ 198
$ 138
$ 1
$ 59
LKE —
—
—
—
29
—
1
28
LG&E —
—
—
—
29
—
1
28


December 31, 2016
																	Assets								Liabilities
																			Eligible for Offset								Eligible for Offset
																	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
September 30, 2018
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28	$	297	$	28	$	25	$	244	$	49	$	28	$	—	$	21
LKE	—		—		—		—		31		—		3		28		—		—		—		—		19		—		—		19
LG&E	—		—		—		—		31		—		3		28		—		—		—		—		19		—		—		19



December 31, 2017
Treasury Derivatives
PPL	$	264	$	107	$	20	$	137	$	174	$	107	$	—	$	67
LKE	—		—		—		—		26		—		—		26
LG&E	—		—		—		—		26		—		—		26

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.

(PPL, LKE and LG&E)

At September 30, ~~2017,~~2018, 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:

~~Table of Contents~~


	PPL		LKE		LG&E		PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	43	$	11	$	11	$	8	$	6	$	6
Aggregate fair value of collateral posted on these derivative instruments	1		1		1		—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	42		10		10		8		6		6


(a)	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

~~14. Goodwill and Other Intangible Assets~~

~~(PPL)~~

~~The change in the carrying amount of goodwill for the nine months ended September 30, 2017 was due to the effect of foreign currency exchange rates on the U.K. Regulated segment.~~

The change in the carrying amount of other intangible assets for the nine months ended September 30, 2017 was primarily due to a change in WPD’s approach in acquiring rights-of-way relating to WPD equipment impacting landowners' property. A shorter term agreement at a lower cost is now being offered which has also reduced the estimated liability for claims not yet settled.

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15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

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

PPL LKE LG&E KU
Balance at December 31, 2016 $ 488
$ 433
$ 145
$ 288
Accretion 16
15
5
10
Effect of foreign exchange rates 2
—
—
—
Changes in estimated timing or cost (70 ) (63 ) (12 ) (51 )
Obligations settled (30 ) (30 ) (20 ) (10 )
Balance at September 30, 2017 $ 406
$ 355
$ 118
$ 237

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 910 for information on the ~~final~~ CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with ~~approved ECR~~certain CCR projects ~~for CCRs~~ are amortized to expense ~~over a period of 10 to 25 years based on retirement expenditures made related to the obligation.~~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.

LKE recorded decreases of $66 million ($56 million at KU and $10 million at LG&E) to the existing AROs during the nine months ended September 30, 2017 related to the closure of CCR impoundments. These revisions are the result ofThe changes in ~~closure plans related to expected costs and timing~~the carrying amounts of ~~closures. Further changes to~~ AROs ~~capital plans or operating costs may be required~~were as ~~estimates of future cash flows are refined based on closure developments and regulatory or legal proceedings.~~follows.



	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	14			13			5			8
Obligations incurred	8			8			—			8
Effect of foreign exchange rates	(2		)	—			—			—
Changes in estimated timing or cost	(6		)	(14		)	(2		)	(12		)
Obligations settled	(46		)	(46		)	(17		)	(29		)
Balance at September 30, 2018	$	365		$	317		$	107		$	210

~~Table of Contents~~

16. Accumulated Other Comprehensive Income (Loss)

(PPL and LKE)

The after-tax changes in AOCI by component for the periods ended September 30 were as follows.


	Foreign currency translation adjustments			Unrealized gains (losses) on qualifying derivatives								Defined benefit plans											Foreign currency translation adjustments				Unrealized gains (losses) on qualifying derivatives							Defined benefit plans
	Foreign currency translation adjustments						Equity investees' AOCI				Prior service costs				Actuarial gain (loss)				Total							Equity investees' AOCI					Prior service costs			Actuarial gain (loss)				Total
PPL				Unrealized gains (losses) on qualifying derivatives																							Unrealized gains (losses) on qualifying derivatives
June 30, 2018																							Foreign currency translation adjustments	$	(1,223	)		$	(21	)		$	—		$	(7	)		$	(2,244	)		$	(3,495	)
Amounts arising during the period																							(187		)		22				—			—				(8		)		(173		)
Reclassifications from AOCI																							—				(14		)		—			—				34				20
Net OCI during the period																							(187		)		8				—			—				26				(153		)
September 30, 2018																							$	(1,410	)		$	(13	)		$	—		$	(7	)		$	(2,218	)		$	(3,648	)

December 31, 2017																							$	(1,089	)		$	(13	)		$	—		$	(7	)		$	(2,313	)		$	(3,422	)
Amounts arising during the period																							(321		)		21				—			(1		)		(9		)		(310		)
Reclassifications from AOCI																							—				(21		)		—			1				104				84
Net OCI during the period																							(321		)		—				—			—				95				(226		)
September 30, 2018																							$	(1,410	)		$	(13	)		$	—		$	(7	)		$	(2,218	)		$	(3,648	)

June 30, 2017	$	(1,420	)	$	(13	)		$	—			$	(7	)		$	(2,083	)		$	(3,523	)	$	(1,420	)		$	(13	)		$	—		$	(7	)		$	(2,083	)		$	(3,523	)
Amounts arising during the period	(12		)	1				—				—				(3		)		(14		)	(12		)		1				—			—				(3		)		(14		)
Reclassifications from AOCI	—			—				—				—				34				34			—				—				—			—				34				34
Net OCI during the period	(12		)	1				—				—				31				20			(12		)		1				—			—				31				20
September 30, 2017	$	(1,432	)	$	(12	)		$	—			$	(7	)		$	(2,052	)		$	(3,503	)	$	(1,432	)		$	(12	)		$	—		$	(7	)		$	(2,052	)		$	(3,503	)

December 31, 2016	$	(1,627	)	$	(7	)		$	(1	)		$	(8	)		$	(2,135	)		$	(3,778	)
Amounts arising during the period	195			(29		)		—				—				(14		)		152
Reclassifications from AOCI	—			24				1				1				97				123
Net OCI during the period	195			(5		)		1				1				83				275
September 30, 2017	$	(1,432	)	$	(12	)		$	—			$	(7	)		$	(2,052	)		$	(3,503	)

June 30, 2016	$	(716	)	$	(5	)		$	(1	)		$	(5	)		$	(2,130	)		$	(2,857	)
Amounts arising during the period	(641		)	62				—				—				(6		)		(585		)
Reclassifications from AOCI	—			(69		)		—				—				31				(38		)
Net OCI during the period	(641		)	(7		)		—				—				25				(623		)
September 30, 2016	$	(1,357	)	$	(12	)		$	(1	)		$	(5	)		$	(2,105	)		$	(3,480	)

December 31, 2015	$	(520	)	$	(7	)		$	—			$	(6	)		$	(2,195	)		$	(2,728	)
Amounts arising during the period	(837		)	57				—				—				(4		)		(784		)
Reclassifications from AOCI	—			(62		)		(1		)		1				94				32
Net OCI during the period	(837		)	(5		)		(1		)		1				90				(752		)
September 30, 2016	$	(1,357	)	$	(12	)		$	(1	)		$	(5	)		$	(2,105	)		$	(3,480	)

LKE
June 30, 2017								$	—			$	(7	)		$	(70	)		$	(77	)
Amounts arising during the period								—				—				(1		)		(1		)
Reclassifications from AOCI								—				—				1				1
Net OCI during the period								—				—				—				—
September 30, 2017								$	—			$	(7	)		$	(70	)		$	(77	)

December 31, 2016								$	(1	)		$	(8	)		$	(61	)		$	(70	)
Amounts arising during the period								—				—				(12		)		(12		)
Reclassifications from AOCI								1				1				3				5
Net OCI during the period								1				1				(9		)		(7		)
September 30, 2017								$	—			$	(7	)		$	(70	)		$	(77	)

June 30, 2016								$	(1	)		$	(9	)		$	(33	)		$	(43	)
Reclassifications from AOCI								—				—				1				1
Net OCI during the period								—				—				1				1
September 30, 2016								$	(1	)		$	(9	)		$	(32	)		$	(42	)

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	Foreign currency translation adjustments	Unrealized gains (losses) on qualifying derivatives						Defined benefit plans											Foreign currency translation adjustments				Unrealized gains (losses) on qualifying derivatives								Defined benefit plans
			Equity investees' AOCI				Prior service costs				Actuarial gain (loss)				Total							Equity investees' AOCI					Prior service costs				Actuarial gain (loss)				Total
December 31, 2015					$	—			$	(10	)		$	(36	)		$	(46		)
December 31, 2016																			$	(1,627	)				$	(7	)		$	(1	)		$	(8	)		$	(2,135	)		$	(3,778	)
Amounts arising during the period				—				—				1				1			195				(29		)		—				—				(14		)		152
Reclassifications from AOCI				(1		)		1				3				3			—				24				1				1				97				123
Net OCI during the period				(1		)		1				4				4			195				(5		)		1				1				83				275
September 30, 2016				$	(1	)		$	(9	)		$	(32	)		$	(42	)
September 30, 2017																			$	(1,432	)		$	(12	)		$	—			$	(7	)		$	(2,052	)		$	(3,503	)

LKE
June 30, 2018																											$	—			$	(8	)		$	(78	)		$	(86	)
Reclassifications from AOCI																											—				1				1				2
Net OCI during the period																											—				1				1				2
September 30, 2018																											$	—			$	(7	)		$	(77	)		$	(84	)

December 31, 2017																											$	—			$	(9	)		$	(79	)		$	(88	)
Reclassifications from AOCI																											—				2				2				4
Net OCI during the period																											—				2				2				4
September 30, 2018																											$	—			$	(7	)		$	(77	)		$	(84	)

June 30, 2017																											$	—			$	(7	)		$	(70	)		$	(77	)
Amounts arising during the period																											—				—				(1		)		(1		)
Reclassifications from AOCI																											—				—				1				1
Net OCI during the period																											—				—				—				—
September 30, 2017																											$	—			$	(7	)		$	(70	)		$	(77	)

December 31, 2016																											$	(1	)		$	(8	)		$	(61	)		$	(70	)
Amounts arising during the period																											—				—				(12		)		(12		)
Reclassifications from AOCI																											1				1				3				5
Net OCI during the period																											1				1				(9		)		(7		)
September 30, 2017																											$	—			$	(7	)		$	(70	)		$	(77	)

(PPL)

The following table presents ~~the~~PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended September 30. The defined benefit plan components of AOCI are not reflected in their entirety in the Statement of Income during the periods; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 8 for additional information.


	Three Months						Nine Months						Affected Line Item on the	Three Months						Nine Months						Affected Line Item on the
Details about AOCI	2017			2016			2017			2016			Statements of Income	2018			2017			2018			2017			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(7	)	$	(5	)	Interest Expense	$	(2	)	$	(2	)	$	(6	)	$	(7	)	Interest Expense
Cross-currency swaps	2			86			(24		)	80			Other Income (Expense) - net	18			2			30			(24		)	Other Income (Expense) - net
	1			2			1			2			Interest Expense	1			1			1			1			Interest Expense
Total Pre-tax	1			86			(30		)	77				17			1			25			(30		)
Income Taxes	(1		)	(17		)	6			(15		)		(3		)	(1		)	(4		)	6
Total After-tax	—			69			(24		)	62				14			—			21			(24		)

Equity investees' AOCI	—			—			(1		)	1			Other Income (Expense) - net
Total Pre-tax	—			—			(1		)	1
Income Taxes	—			—			—			—
Total After-tax	—			—			(1		)	1

Defined benefit plans
Prior service costs	(1		)	(1		)	(2		)	(2		)
Net actuarial loss	(44		)	(41		)	(125		)	(121		)
Total Pre-tax	(45		)	(42		)	(127		)	(123		)
Income Taxes	11			11			29			28
Total After-tax	(34		)	(31		)	(98		)	(95		)

Total reclassifications during the period	$	(34	)	$	38		$	(123	)	$	(32	)

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	Three Months						Nine Months						Affected Line Item on the
Details about AOCI	2018			2017			2018			2017			Statements of Income
Equity investees' AOCI	—			—			—			(1		)	Other Income (Expense) - net
Total Pre-tax	—			—			—			(1		)
Income Taxes	—			—			—			—
Total After-tax	—			—			—			(1		)

Defined benefit plans
Prior service costs (a)	(1		)	(1		)	(2		)	(2		)
Net actuarial loss (a)	(42		)	(44		)	(130		)	(125		)
Total Pre-tax	(43		)	(45		)	(132		)	(127		)
Income Taxes	9			11			27			29
Total After-tax	(34		)	(34		)	(105		)	(98		)

Total reclassifications during the period	$	(20	)	$	(34	)	$	(84	)	$	(123	)


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

17. New Accounting Guidance Pending Adoption

(All Registrants)

~~Accounting for Revenue from Contracts with Customers~~

In May 2014, the Financial Accounting Standards Board (FASB) issued accounting guidance that establishes a comprehensive new model for the recognition of revenue from contracts with customers. This model is based on the core principle that revenue should be recognized to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

The Registrants have completed an assessment of substantially all of their revenue under this new guidance and, for those assessments that have been completed, have determined it will not have a material impact on their current revenue recognition policies. The Registrants' operating revenues are derived primarily from tariff-based sales that result from providing electricity and natural gas to customers with no defined contractual term. Tariff-based sales are within the scope of the new guidance, and operating revenues under the new guidance will be equivalent to the electricity and natural gas delivered and billed in that

~~Table of Contents~~

period (including estimated billings), which is consistent with current practice. Management is still assessing the impact of the new standard on certain revenues in the U.K. Regulated segment and does not expect there to be a material impact to current practice, however, the assessment is still ongoing.

The disclosure requirements included in the standard will result in increased information being provided to enable the users of the financial statements to understand the nature, amount, timing and uncertainty of revenue arising from contracts with customers. These disclosures will include disaggregation of revenues by geographic location, customer class or type of service, as applicable for each Registrant. Some revenue arrangements, including alternative revenue programs and lease income, are excluded from the scope of the new guidance and will be accounted for and disclosed separately from revenues from contracts with customers. The Registrants will also be required to disclose the opening and closing balances of accounts receivable and any contract assets or contract liabilities resulting from contracts with customers.

For public business entities, this guidance can be applied using either a full retrospective or modified retrospective transition method, beginning in annual reporting periods after December 15, 2017 and interim periods within those years. The Registrants will adopt this guidance effective January 1, 2018 and will determine the transition method they will apply once they have completed their assessments and the implications of using either the full retrospective or modified retrospective transition methods are known.

Accounting for Leases

In February 2016, the ~~FASB~~Financial Accounting Standards Board (FASB) issued accounting guidance for leases. This new guidance requires lessees to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). For income statement purposes, the FASB retained a dual model for lessees, requiring leases to be classified as either operating or finance. Operating leases will result in straight-line expense (similar to current operating leases) while finance leases will result in a front-loaded expense pattern (similar to current capital leases). Classification will be based on criteria that are largely similar to those applied in current lease accounting, but without explicit bright line tests.

Lessor accounting under the new guidance is similar to the current model, but updated to align with certain changes to the lessee model and the new revenue recognition standard. Similar to current practice, lessors will classify leases as operating, direct financing, or sales-type.

The standard is effective for public business entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. The new standard must be adopted using a modified retrospective transition ~~and~~method with transition applied either retrospectively to each prior reporting period presented in the financial statements or as of the beginning of the period of adoption. The standard also provides for certain practical expedients. ~~Transition will require application~~One of these practical expedients allows entities to elect to (1) not reassess whether existing contracts contain leases, (2) carryforward the ~~new~~existing lease classification, and (3) not reassess initial direct costs associated with existing leases. In January 2018, the FASB also issued additional guidance atthat provides for a practical expedient that allows entities to elect to not evaluate land easements as leases that exist or expired before the ~~beginning of the earliest comparative period presented.~~adoption date and were not previously accounted for as leases under current lease guidance. The Registrants plan to elect these practical expedients.

The Registrants are currently assessing the impact of adopting this ~~guidance. The Registrants~~guidance and will adopt this ~~guidance effective~~standard as of the beginning of the period adopted, which will be January 1, 2019. Key implementation activities in process of being completed include identifying and implementing new controls and processes and compiling the required disclosure information. The Registrants expect an increase in assets and liabilities, which are still being quantified, but do not expect an impact to the Statements of Cash Flows or Statements of Income. Additional qualitative and quantitative disclosures around the nature of the Registrants’ leasing activity and information surrounding the amount, timing and uncertainty of cash flows arising from leases will also be provided upon adoption.

Accounting for Financial Instrument Credit Losses

In June 2016, the FASB issued accounting guidance that requires the use of a current expected credit loss (CECL) model for the measurement of credit losses on financial instruments within the scope of this guidance, which includes accounts receivable.

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The CECL model requires an entity to measure credit losses using historical information, current information and reasonable and supportable forecasts of future events, rather than the incurred loss impairment model required under current GAAP.

For public business entities, this guidance will be applied using a modified retrospective approach and is effective for fiscal years beginning after December 15, 2019, and interim periods within those years. All entities may early adopt this guidance ~~in annual reporting periods~~ beginning after December 15, 2018, including interim periods within those years.

The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it.

~~Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost~~

In March 2017, the FASB issued accounting guidance that changes the income statement presentation of net periodic benefit cost. This new guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during

~~Table of Contents~~

the period. The other components of net periodic benefits will be presented separately from the line items that include the service cost and outside of any subtotal of operating income. Only the service cost component is eligible for capitalization.

For public business entities, the guidance on the presentation of the components of net periodic benefit costs will be applied retrospectively. The guidance that limits the capitalization to the service cost component of net periodic benefit costs will be applied prospectively. This guidance is effective for fiscal years beginning after December 15, 2017 and interim periods within those years. The Registrants will adopt this guidance effective January 1, 2018.

For PPL’s, LKE’s and LG&E’s U.S. defined benefit pension and PPL's and LKE's other postretirement benefit plans, the adoption of this new guidance is not expected to have a material impact on either the presentation on the income statements or the amounts capitalized and related impact to expense, as the difference between the service cost and the non-service cost components of net periodic benefit costs has not historically been and is not expected to be material in 2018.

For PPL’s U.K. defined benefit pension plans, the non-service cost components of net periodic benefit cost has been in a net-credit position for the current reporting periods and is expected to continue to be in a net-credit position for 2018. Therefore, the estimated impact of adopting this new guidance related to the non-service cost component credits to be reclassified from “Other operation and maintenance” to “Other Income (Expense)-net” on the Statements of Income is approximately $130 million and $90 million for the nine months ended 2017 and 2016.

~~The Registrants are continuing to assess the expected 2018 impacts of adopting the guidance as the amounts will be affected by market conditions and assumptions selected at December 31, 2017.~~

Improvements to Accounting for Hedging Activities

In August 2017, the FASB issued accounting guidance that reduces complexity when applying hedge accounting as well as improves transparency about an entity's risk management activities. This guidance eliminates recognizing hedge ineffectiveness for cash flow and net investment hedges and provides for the ability to perform subsequent effectiveness assessments qualitatively. The guidance also makes certain changes to allowable methodologies such as allowing entities to apply the short-cut method to partial-term fair value hedges of interest rate risk as well as expands the ability to apply the critical terms match method to cash flow hedges of groups of forecasted transactions. ~~The guidance also updates certain recognition and presentation requirements as well as disclosure requirements.~~

For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. This standard must be adopted using a modified retrospective approach and provides for certain transition elections that must be made prior to the first effectiveness testing date after adoption.

The adoption of this guidance requires additional disclosures around the income statement impacts of hedging activities as well as removing disclosures related to ineffectiveness. Other impacts of adopting this guidance are not expected to be material. The Registrants will adopt this guidance effective January 1, 2019.

Accounting for Implementation Costs in a Cloud Computing Service Arrangement

In August 2018, the FASB issued accounting guidance that requires a customer in a cloud computing hosting arrangement that is a service contract to capitalize implementation costs consistent with internal-use software guidance for non-service arrangements. Prior guidance had not addressed these implementation costs. The guidance requires these capitalized implementation costs to be amortized over the term of the hosting arrangement to the statement of income line item where the service arrangement costs are recorded. The guidance also prescribes the financial statement classification of the capitalized implementation costs and cash flows associated with the arrangement. Additional quantitative and qualitative disclosures are also required.

For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted. This standard must be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption.

The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it.

(PPL, LKE, LG&E and KU)

Simplifying the Test for Goodwill Impairment

In January 2017, the FASB issued accounting guidance that simplifies the test for goodwill impairment by eliminating the second step of the quantitative test. The second step of the quantitative test requires a calculation of the implied fair value of goodwill, which is determined in the same manner as the amount of goodwill in a business combination. Under this new guidance, an entity will now compare the estimated fair value of a reporting unit with its carrying value and recognize an impairment charge for the amount the carrying amount exceeds the fair value of the reporting unit.

For public business entities, this guidance will be applied prospectively and is effective for annual or any interim goodwill impairment tests for fiscal years beginning after December 15, 2019. All entities may early adopt this guidance for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017.

The Registrants are currently assessing the impact of adopting this guidance and the period they will adopt it.

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(PPL and LKE)

Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income

In February 2018, the FASB issued accounting guidance that gives entities the option to reclassify tax effects stranded within AOCI as a result of the TCJA to retained earnings. The reclassification applies only to those stranded tax effects arising from the TCJA enactment. Certain disclosures related to the stranded tax effects, including a description of the accounting policy for releasing income tax effects from AOCI, are required.

For all entities, this guidance is effective for fiscal years beginning after December 15, 2018 and interim periods within those fiscal years. Early adoption is permitted, including adoption in any interim period. The amendments should be applied either in the period of adoption or retrospectively to each period in which the effect of the change in the U.S. federal corporate income tax rate in the TCJA is recognized.

The adoption of this guidance will result in PPL and LKE reclassifying $50 million and $18 million of deferred tax effects (primarily related to pension and other post-retirement benefits) stranded in AOCI as a result of the TCJA to retained earnings. The Registrants are assessing the period in which they will adopt this guidance.

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

Results of Operations

(All Registrants)

This "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by PPL, PPL Electric, 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' Condensed Consolidated Financial Statements and the accompanying Notes and with the Registrants' ~~2016~~2017 Form 10-K. Capitalized terms and abbreviations are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted.

"Management's Discussion and Analysis of Financial Condition and Results of Operations" includes the following information:

"Overview" provides a description of each Registrant's business strategy and a discussion of important financial and operational developments.

"Results of Operations" for all Registrants includes a "Statement of Income Analysis" which discusses significant changes in principal line items on the Statements of Income, comparing the three and nine months ended September 30, ~~2017~~2018 with the same periods in ~~2016.~~2017. 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 ~~"2017~~"2018 Outlook" discussion identifies key factors expected to impact ~~2017~~2018 earnings. For PPL Electric, LKE, LG&E and KU, a summary of earnings and adjusted gross 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 rating agency actions.

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

Overview

Introduction

(PPL)

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

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

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PPL Corporation*

PPL Capital Funding

● Provides financing for the operations of PPL and certain subsidiaries

PPL Global

● Engages in the regulated distribution of electricity in the U.K.

LKE*

PPL Electric*

● Engages in the regulated transmission and distribution of electricity in Pennsylvania

LG&E*

● Engages in the regulated generation, transmission, distribution and sale of electricity and regulated distribution and sale of natural gas in Kentucky

KU*

● Engages in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky

U.K.

Regulated Segment

Kentucky

Regulated Segment

Pennsylvania

Regulated Segment

PPL's reportable segments' results primarily represent the results of PPL Global, LKE and PPL Electric, except that the reportable segments are also allocated certain corporate level financing and other costs that are not included in the results of PPL Global, LKE and PPL Electric. ~~Although~~ PPL Global is not a ~~Registrant, unaudited~~Registrant. Unaudited annual consolidated financial statements for the U.K. Regulated segment are furnished on a Form 8-K with the SEC.

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

(PPL Electric)

PPL Electric, headquartered in Allentown, Pennsylvania, is a ~~direct~~ wholly owned subsidiary of PPL and a regulated public utility that is an electricity transmission and distribution service provider in eastern and central Pennsylvania. PPL Electric is subject to regulation as a public utility by the 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.

(LKE)

LKE, 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 engages in the distribution and sale of natural gas. LG&E and KU maintain separate corporate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name and in Tennessee under the KU name.

(LG&E)

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

(KU)

KU, headquartered in Lexington, Kentucky, is a wholly owned subsidiary of LKE and a regulated utility engaged in the generation, transmission, distribution and sale of electricity in Kentucky, Virginia and Tennessee. KU is subject to regulation as

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a public utility by the KPSC, the VSCC and ~~the Tennessee Public Utility Commission, and~~ certain of its transmission and wholesale power activities are subject to the jurisdiction of the FERC under the Federal Power Act. KU serves its Virginia customers under the Old Dominion Power name and its Kentucky and Tennessee customers under the KU name.

Business Strategy

(All Registrants)

PPL ~~is a~~operates seven fully regulated, ~~business consisting of seven diverse,~~ high-performing utilities. These utilities are located in the U.K., Pennsylvania and Kentucky, ~~and each jurisdiction has different~~constructive regulatory jurisdictions with distinct regulatory structures and customer classes. ~~The Company~~PPL believes this ~~diverse~~business portfolio provides strong earnings and dividend growth potential that will create significant value for its shareowners and positions PPL well for continued growth and success.

PPL's ~~businesses of WPD, PPL Electric, LG&E~~strategy is to deliver best-in-sector operational performance, invest in a sustainable energy future, maintain a strong financial foundation, and KUengage and develop its people. PPL's business plan is designed to achieve growth by providing efficient, reliable and safe operations and strong customer service, maintaining constructive regulatory relationships and achieving timely recovery of costs. These businesses are expected to achieve strong, long-term growth in rate base in the U.S. and RAV ~~as applicable,~~in the U.K. Rate base growth is being driven by planned significant capital expenditures to maintain existing assets and improve system reliability and, for LKE, LG&E and KU, to comply with federal and state environmental regulations related to coal-fired electricity generation facilities. ~~Additionally, significant transmission rate base growth is expected through at least 2020 at PPL Electric.~~

For the U.S. businesses, central to our strategy is ~~to recover~~recovering capital project costs efficiently through various rate-making mechanisms, including periodic base rate case proceedings using forward test years, annual FERC formula rate mechanisms and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, the KPSC has adopted a series of regulatory mechanisms (ECR, DSM, GLT, fuel adjustment clause, gas supply clause and recovery on construction work-in-progress) that reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs. In 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~~expenditures 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 place to reduce regulatory lag and provide for timely recovery of and a return on, as appropriate, prudently incurred costs.

Rate base growth in the domestic utilities is expected to result in earnings growth for the foreseeable future. ~~In 2017, earnings from the U.K. Regulated segment are expected to decline mainly due to the unfavorable impact of lower GBP to U.S. dollar exchange rates.~~ RAV growth is expected in the U.K. Regulated segment ~~through~~during the RIIO-ED1 price control period, which ends on March 31, 2023, and to result in earnings growth ~~after 2017~~in 2018 through at least 2020 ~~at WPD.~~. See "Item 1. Business - Segment Information - U.K. Regulated Segment" ofin PPL's ~~2016~~2017 Form 10-K for additional information on RIIO-ED1.

To manage financing costs and access to credit markets, and to fund capital expenditures, a key objective of the Registrants is to maintain their investment grade credit ratings and adequate liquidity positions. In addition, the Registrants have financial and operational risk management programs that, among other things, are designed to monitor and manage exposure to earnings and cash flow volatility, as applicable, related to changes in interest rates, foreign currency exchange rates and counterparty credit quality. To manage these risks, PPL generally uses contracts such as forwards, options and swaps. See "Financial Condition - Risk Management" below for further information.

Earnings generated by PPL's U.K. subsidiaries are subject to foreign currency translation risk. Because WPD's earnings represent such a significant portion of PPL's consolidated earnings, PPL enters into foreign currency contracts to economically hedge the value of the GBP versus the U.S. dollar. These hedges do not receive hedge accounting treatment under GAAP. See "Financial and Operational Developments - U.K. Membership in European Union" for additional discussion of the U.K. earnings hedging activity.

The U.K. subsidiaries also have currency exposure to the U.S. dollar to the extent of their U.S. dollar denominated debt. To manage these risks, PPL generally uses contracts such as forwards, options and cross-currency swaps that contain characteristics of both interest rate and foreign currency exchange contracts.

As discussed above, a key component of this strategy is to maintain constructive relationships with regulators in all jurisdictions in which we operate (U.K., U.S. federal and state). This is supported by our strong culture of integrity and delivering on

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commitments to customers, regulators and shareowners, and a commitment to continue to improve our customer service, reliability and ~~efficiency of operations.~~

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operational efficiency.

Financial and Operational Developments

Equity Forward Contracts (PPL)

In September 2018, PPL settled a portion of the initial forward sale agreements by issuing 20 million shares of PPL common stock, and received net cash proceeds of $520 million. For the unsettled portion of the agreements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the Treasury Stock Method.

See Note 8 to the Financial Statements for additional information.

U.S. Tax Reform (All Registrants)

In the third quarter of 2018, PPL filed its consolidated federal income tax return, which was prepared using guidance issued by the U.S. Treasury Department and the IRS since the filing of each Registrant’s 2017 Form 10-K. Accordingly, the Registrants have updated the following provisional amounts and now consider them to be complete: (1) the amount of the deemed dividend and associated foreign tax credits relating to the transition tax imposed on accumulated foreign earnings as of December 31, 2017; (2) the amount of accelerated 100% “bonus” depreciation PPL is eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on the changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of PPL's U.S. regulated operations. See Note 6 to the Financial Statements for the final amounts reported in PPL's 2017 federal income tax return, provisional adjustment amounts for the year ended December 31, 2017, the related measurement period adjustments and the resulting tax impact for the three and nine months ended September 30, 2018.

Kentucky State Tax Reform (All Registrants)

~~Tax reform has been discussed as~~HB 487, which became law on April 27, 2018, provides for significant changes to the Kentucky tax code including (1) adopting mandatory combined reporting for corporate members of unitary business groups for taxable years beginning on or after January 1, 2019 (members of a ~~high priority~~unitary business group may make an eight-year binding election to file consolidated corporate income tax returns with all members of their federal affiliated group) and (2) a reduction in the Kentucky corporate income tax rate from 6% to 5% for taxable years beginning after December 31, 2017. LKE recognized a deferred tax charge of $9 million

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in the second quarter of 2018 primarily associated with the remeasurement of non-regulated accumulated deferred income tax balances.

As indicated in Note 1 in the Registrants' 2017 Form 10-K, LG&E's and KU's accounting for income taxes is impacted by rate regulation. Therefore, reductions in regulated accumulated deferred income tax balances due to the reduction in the Kentucky corporate income tax rate to 5% under the provisions of HB 487 may result in amounts previously collected from utility customers for these deferred taxes to be refundable to such customers in future periods. In the second quarter of 2018, LG&E and KU recorded the impact of the ~~U.S. presidential administration. Significant uncertainty exists as~~reduced tax rate, related to the ~~ultimate changes that may be made,~~remeasurement of deferred income taxes, as an increase in regulatory liabilities of $16 million and $19 million. In a separate regulatory proceeding, LG&E and KU have requested to begin returning state excess deferred income taxes to customers in conjunction with the ~~timing of those changes and the~~2018 Kentucky base rate case, which was filed on September 28, 2018. See Note 7 for additional information related ~~impact~~ to the ~~Registrants' financial condition~~rate case proceedings. PPL is evaluating the impact, if any, of unitary or results of operations. The Registrants are working with industry groups and carefully monitoring related developments in an effort both to have input to the legislative process where possible and plan effectively to respond to any forthcoming changes in a manner that will optimize value for ratepayers and shareowners.elective consolidated income tax reporting on all its Registrants.

U.K. Membership in European Union (PPL)

On March 29, 2017, the U.K. formally notified the European Council 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 50 of the Lisbon Treaty. Article 50 specifies that if a member state decides to withdraw from the EU, it must notify the European Council of its intention to leave the EU, negotiate the terms of withdrawal and establish the legal grounds for its future relationship with the EU. Article 50 provides two years from the date of the Article 50 notification to conclude negotiations. Failure to complete negotiations within two years, unless negotiations are extended, would result in the treaties governing the EU no longer being applicable to the U.K. with there being no agreement in place governing the U.K.'s relationship with the EU. Under the terms of Article 50, negotiations can only be extended beyond two years if all of the 27 remaining EU states agree to an extension. Any withdrawal agreement will need to be approved by ~~both~~the European Parliament, the European Council and by the ~~European~~U.K. Parliament. There remains significant uncertainty as to the ultimate outcome of the withdrawal negotiations and the related impact on the U.K. economy and the GBP to U.S. dollar exchange rate.

PPL has executed hedges to mitigate the foreign exchange risk to the Company's U.K. earnings. As of October ~~18, 2017,~~26, 2018, PPL's foreign exchange exposure related to budgeted earnings is 100% hedged for the remainder of ~~2017 at an average rate of $1.22 per GBP, 99% hedged for~~ 2018 at an average rate of ~~$1.32~~$1.31 per GBP, 100% hedged for 2019 at an average rate of $1.39 per GBP and ~~15%~~50% hedged for 2020 at an average rate of ~~$1.47~~$1.49 per GBP.

PPL cannot predict either the short-term or long-term impact to foreign exchange rates or long-term impact on PPL's financial condition that may be experienced as a result of the actions taken by the U.K. government to withdraw from the EU, although such impacts could be significant.

Regulatory Requirements

(All Registrants)

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

TCJA Impact on LG&E and KU Rates(PPL, LKE, LG&E and KU)

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million through existing rate mechanisms), $69 million in LG&E electricity revenues ($49 million through the new bill credit and $20 million through existing rate mechanisms) and $17 million in LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019.

On September 28, 2018, the KPSC issued an Order on reconsideration, implementing rates reflecting electricity revenue reductions of $101 million for KU ($80 million through the new bill credit and $21 million through existing rate mechanisms), $74 million for LG&E electricity revenues ($54 million through the new bill credit and $20 million through existing rate mechanisms) and $16 million LG&E gas revenues (substantially all through the new bill credit) for the period January 2018 through April 2019. This represents lower revenue reduction amounts than the March 20, 2018 Order of approximately $13 million ($7 million at KU and $6 million at LG&E). LG&E and KU have been implementing interim partial rate reductions since April 2018, as authorized by the KPSC on March 28, 2018, and recording reserves up to the higher reduction amounts originally approved in the March 20, 2018 Order. The September 28, 2018 Order is not expected to have a material adverse impact on LG&E's and KU's financial condition or results of operations.

(PPL and PPL Electric)

TCJA Impact on PPL Electric Rates

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and (b) to record a deferred regulatory liability to reflect the tax savings associated with the TCJA for the period January 1 through June 30, 2018. On June 8, 2018, PPL Electric submitted a petition to the PUC to increase the negative surcharge proposed in the May 17, 2018 Order from 0.56% to 7.05% to reflect the estimated 2018 tax savings associated with the TCJA. The PUC approved PPL Electric's petition on June 14, 2018 and PPL Electric filed a tariff on June 15, 2018 reflecting the increased negative surcharge. The estimated 2018 full year impact of the rate reduction is $72 million in PPL Electric's operating revenues, of which $39 million relates to the period January 1, 2018 through June 30, 2018 and was recorded as a noncurrent regulatory liability in the second quarter of 2018 to be distributed to customers pursuant to a future rate adjustment. The remaining $33 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and is being passed back to customers through the negative surcharge which began on July 1, 2018.

Pennsylvania Alternative Ratemaking

On June 28, 2018, Governor Tom Wolf signed House Bill 1782 (now known as Act 58 of 2018, and to be codified at 66 Pa. C.S. § 1330) authorizing public utilities to implement alternative rates and rate mechanisms in base rate proceedings before the PUC. The effective date of Act 58 is August 27, 2018.

Under the new law, a public utility can file an application to establish alternative rates and rate mechanisms in a base rate proceeding. These alternative rates and rate mechanisms include, but are not limited to the following: decoupling mechanisms, performance-based rates, formula rates, multiyear rate plans, or a combination of those mechanisms or other mechanisms.

The alternative rate mechanisms can include reconcilable surcharges and rates established under current law, including returns on and return of capital investments. Act 58 explicitly provides that it does not invalidate or void any rate mechanisms approved by the PUC prior to the legislation's effective date. Act 58 also specifies customer notice requirements concerning the utility's application for alternative rates or rate mechanisms.

On August 23, 2018, the PUC issued a Tentative Implementation Order seeking comments on its proposed interpretation and implementation of Act 58, Section 1330 of the Public Utility Code, 66 Pa. C.S. 1330. PPL Electric and various other parties filed comments on October 8, 2018. This matter remains pending before the PUC.

PPL Electric views the passage of Act 58 to be a favorable regulatory development that is expected to expand the rate-making mechanisms available to Pennsylvania regulated utility companies.

(PPL)

RIIO-ED1 Mid-period Review

In ~~July~~December 2017, Ofgem ~~published~~initiated a consultation on a potential RIIO-ED1 mid-period review (MPR). The RIIO framework allows for an ~~open letter commencing~~MPR of outputs halfway through the price control. Ofgem was consulting on three potential approaches:

whether to implement an MPR as currently defined;

whether to implement an MPR with an extension for WPD rail electrification; and

whether to implement an MPR with a significant extension of scope to include financial parameters.

Ofgem's initial assessment as set forth in its December 2017 consultation publication was that an MPR as currently defined under RIIO-ED1 was not required. In addition, Ofgem recognized that the U.K. rail electrification program applicable in the WPD distribution areas was outside the scope of the MPR and that implementing an MPR to include financial parameters could

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undermine the stability of the regulatory regime. The consultation, however, requested interested party comments on those conclusions. The period for submission of comments to the consultation closed on February 2, 2018. Formal consultation responses were submitted by PPL and WPD. On April 30, 2018, Ofgem announced its decision not to conduct an MPR.

RIIO-2 Framework Review

On March 7, 2018, Ofgem issued its consultation document on the RIIO-2 framework, ~~review,~~ which covers all U.K. gas and electricity transmission and distribution price controls. The current electricity distribution price control, RIIO-ED1, continues through March 31, 2023 and will not be impacted by this RIIO-2 consultation process. Ofgem consulted on a wide range of issues, including cost of debt and equity methodologies, the length of the price control period, indexation methodologies, innovation, stakeholder engagement in the business planning process and performance incentive mechanisms. The purpose of ~~this~~the RIIO-2 framework ~~review is~~consultation was to build on lessons learned from the current price controls while supporting low costs to consumers, improved customer service and reliability, and the U.K.'s continued shift to ~~develop~~ a ~~framework that will be adaptable to meeting the needs of an evolving U.K. energy sector.~~

~~The letter sets out the context for the development of the next price controls, RIIO-2, and seeks views from stakeholders~~low-carbon future. Comments on the RIIO-2 ~~framework. Responses to the open letter~~framework were due in May 2018. On July 30, 2018, Ofgem published ~~in September 2017 and will be used to guide the full~~its decision following their RIIO-2 framework consultation after consideration of comments received. Ofgem confirmed the following points in the decision document:

There will be a five-year default length for the price control period, compared to eight years in the current RIIO-ED1 price control.

There is intent to shift the inflation index used for calculating RAV and allowed returns from RPI to CPIH. Ofgem stated overall, consumers and investors as a whole will be neither better nor worse off in net present value terms as a result of the shift to CPIH and a transition period may be required.

There will be no change to the existing depreciation policy of using economic asset lives as the basis for depreciating RAV as part of base revenue calculations. WPD is currently transitioning to 45 year asset lives for new additions in RIIO-ED1 based on Ofgem’s extensive review of asset lives in RIIO-ED1.

Ofgem will retain the option for fast-tracking for electricity distribution companies only. Fast tracking will be furtherconsidered as part of the electricity distribution sector specific consultation.

A new enhanced engagement model will be introduced which will require distribution companies to set up a customer engagement group to provide Ofgem with a public report of their views on the companies’ business plans from the perspective of local stakeholders. Ofgem will also establish an independent RIIO-2 challenge group comprised of consumer experts to provide Ofgem with a public report on companies’ business plans.

Ofgem intends to expand the role of competition for projects that are new, separable and high value. WPD does not currently have any planned projects that would meet the high value threshold.

A focus of RIIO-2 will be on whole-system outcomes. Ofgem envisions network companies and system operators working together to ensure the energy system as a whole is efficient and delivers best value to consumers. Ofgem is undertaking further work to clarify the definition of whole-system and the appropriate roles of the network companies in supporting the energy transition.

Ofgem also indicated further work is needed on other price control principles, including but not limited to, cost of equity, cost of debt, financeability and incentives with decisions on these items expected to be ~~published~~made in the ~~first quarter of 2018.~~sector specific consultations or within the individual company business plan submissions. The promulgation of sector specific price controls ~~will~~is expected to begin with the gas and electricity transmission networks in December 2018, with electricity distribution price control work scheduled to begin in 2020, at which time Ofgem plans to publish its RIIO-ED2 strategy consultation document.

~~The current~~ Although the electricity distribution ~~price control, RIIO-ED1, continues through March 31, 2023 and will~~consultation does not ~~be impacted by this~~commence until 2020, WPD is ensuring that they are included in any RIIO-2 ~~consultation process.~~related engagement. PPL cannot predict the outcome of this process or the long-term impact it or the final RIIO-ED2 regulations will have on its financial condition or results of operations.

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

On August 3, 2018, LG&E and KU submitted an application 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 seeks termination of LG&E’s and KU’s commitment to provide mitigation for certain horizontal market power concerns arising out of the 1998 merger for certain transmission service between MISO and LG&E and KU. The affected transmission customers are a limited number of municipal entities in Kentucky or Tennessee. The amounts at issue are generally waivers or credits for either LG&E and KU or for MISO transmission charges depending upon the direction of transmission service incurred by the municipalities. LG&E and KU estimate that such charges may average approximately $22 million annually, depending upon actual transmission customer and market volumes, structures and prices, with such charges allocated according to LG&E's and KU’s respective transmission system ownership ratio. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate.

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LG&E and KU currently receive recovery of such expenses in other rate mechanisms. LG&E and KU cannot predict the outcome of the proceeding, including any effects on their financial condition or results of operations.

Rate Case Proceedings

(PPL, LKE, LG&E and KU)

~~The businesses of LKE,~~On September 28, 2018, LG&E and KU ~~are subject~~filed requests with the KPSC for an increase in annual base electricity rates of approximately $112 million at KU and increases in annual base electricity and gas rates of approximately $35 million and $25 million at LG&E. The proposed base rate increases would result in an electricity rate increase of 6.9% at KU and electricity and gas rate increases of 3% and 7.5% at LG&E. As discussed in the "TCJA Impact on LG&E and KU Rates" section below, LG&E’s and KU’s applications seek to ~~extensive federal, state and local environmental laws, rules and regulations, including those pertaining to CCRs, GHGs and ELGs. See Note 9 to~~include applicable changes associated with the ~~Financial Statements for a discussion~~TCJA in the calculation of the ~~other significant environmental matters.~~proposed base rates and to terminate the TCJA bill credit mechanism when the new base rates go into effect.

~~Rate Case Proceedings~~New rates are expected to become effective on May 1, 2019. The applications are based on a forecasted test year of May 1, 2019 through April 30, 2020 with a requested return-on-equity of 10.42%. LG&E and KU cannot predict the outcome of these proceedings.

(LKE and KU)

OnIn September ~~29,~~ 2017, KU filed a request seeking approval from the VSCC to increase annual Virginia base electricity revenue by $7 million, representing an increase of 10.4%. ~~KU's request is based~~On March 22, 2018, KU reached a settlement agreement regarding the case, including the impact of the TCJA on rates, resulting in an ~~authorized 10.42% return on equity. Subject to regulatory review and approval, new~~increase in annual Virginia base electricity revenue by $2 million. This represents an increase of 2.8% with rates ~~would become~~ effective ~~July~~June 1, 2018. On May 8, 2018, the VSCC issued an Order approving the settlement agreement.

(Acquisition of Solar Energy Solution Provider ~~PPL, LKE and KU)~~(PPL)

~~In October 2016, KU filed~~During the second quarter of 2018, PPL completed the acquisition of all the outstanding membership interests of Safari Energy, LLC (Safari Energy), a ~~request~~privately held provider of solar energy solutions for commercial customers in the U.S. For its clients, Safari Energy develops highly structured turnkey solutions, managing projects through all phases of development, from inception to financing, design, engineering, permitting, construction, interconnection and asset management. Headquartered in New York City, Safari Energy has completed over 200 solar projects in 19 states, with over 80 projects underway. The acquisition is not material to PPL and the ~~FERC to modify its formula rates to provide for the recovery~~financial results of CCR impoundment closure costs from its departing municipal customers. In December 2016, the FERC accepted the revised rate schedules providing recovery of the costs effective December 31, 2016, subject to refund,Safari Energy are reported within Corporate and established limited hearing and settlement judge procedures relating to determining the applicable amortization period. In March 2017, the parties reached a settlement in principle regarding a suitable amortization period. In June 2017, a FERC judge issued an order implementing the settlement's rates on an interim basis, effective July 1, 2017. In August 2017, the FERC issued a final order approving the settlement.Other.

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 the three and nine months ended September 30, ~~2017~~2018 with the same periods in ~~2016.~~2017. 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 ~~"2017~~"2018 Outlook" discussion identifies key factors expected to impact ~~2017~~2018 earnings.

Tables analyzing changes in amounts between periods within "Statement of Income Analysis," "Segment Earnings" and ~~"Margins"~~"Adjusted Gross Margins" are presented on a constant GBP to U.S. dollar exchange rate basis, where applicable, in order to isolate the impact of the change in the exchange rate on the item being explained. Results computed on a constant GBP to U.S. dollar exchange rate basis are calculated by translating current year results at the prior year weighted-average GBP to U.S. dollar exchange rate.

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(PPL Electric, LKE, LG&E and KU)

A "Statement of Income Analysis, Earnings and Adjusted Gross Margins" 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 the three and nine months ended September 30, ~~2017~~2018 with the same periods in ~~2016.~~2017. The "Earnings" discussion provides a summary of earnings. The ~~"Margins"~~"Adjusted Gross Margins" discussion includes a reconciliation of non-GAAP financial measures to "Operating Income."

(All Registrants)

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

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PPL: Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the periods ended September 30 includes the following results.


	Three Months								Nine Months								Three Months								Nine Months
	2017			2016		$ Change			2017			2016		$ Change			2018		2017			$ Change			2018		2017			$ Change
Operating Revenues	$	1,845		$	1,889	$	(44	)	$	5,521		$	5,685	$	(164	)	$	1,872	$	1,845		$	27		$	5,846	$	5,521		$	325
Operating Expenses
Operation
Fuel	202			227		(25		)	576			607		(31		)	206		202			4			609		576			33
Energy purchases	143			151		(8		)	494			531		(37		)	149		143			6			538		494			44
Other operation and maintenance	397			417		(20		)	1,217			1,292		(75		)	479		438			41			1,453		1,340			113
Depreciation	257			232		25			745			692		53			275		257			18			817		745			72
Taxes, other than income	69			76		(7		)	214			229		(15		)	77		69			8			234		214			20
Total Operating Expenses	1,068			1,103		(35		)	3,246			3,351		(105		)	1,186		1,109			77			3,651		3,369			282
Other Income (Expense) - net	(76		)	49		(125		)	(235		)	284		(519		)	106		(35		)	141			297		(112		)	409
Interest Expense	230			223		7			669			671		(2		)	244		230			14			718		669			49
Income Taxes	116			139		(23		)	321			510		(189		)	103		116			(13		)	362		321			41
Net Income	$	355		$	473	$	(118	)	$	1,050		$	1,437	$	(387	)	$	445	$	355		$	90		$	1,412	$	1,050		$	362

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Operating Revenues

The increase (decrease) in operating revenues for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Domestic:
PPL Electric Distribution price (a)	$	16		$	46		$	(6	)	$	5
PPL Electric Distribution volume	(20		)	(30		)	17			49
PPL Electric PLR Revenue (b)	(1		)	(32		)
PPL Electric PLR (b)							5			31
PPL Electric Transmission Formula Rate(c)	20			25			3			53
PPL Electric TCJA refund (d)							(20		)	(57		)
LKE Volumes(e)							19			122
LKE Base rates	31			31			—			58
LKE Volumes(e)	(41		)	(86		)
LKE ECR							5			18
LKE TCJA refund (d)							(30		)	(109		)
LKE DSM							(2		)	(13		)
LKE Fuel and other energy prices	(8		)	10			(8		)	(15		)
Other	(3		)	(2		)	4			14
Total Domestic	(6		)	(38		)	(13		)	156
U.K.:
Price	(3		)	74			19			19
Volume	(12		)	(24		)	(2		)	2
Foreign currency exchange rates	(21		)	(183		)	8			117
Engineering recharge income							18			37
Other	(2		)	7			(3		)	(6		)
Total U.K.	(38		)	(126		)	40			169
Total	$	(44	)	$	(164	)	$	27		$	325


(a)	Distribution ~~rider prices resulted in increases of $16 million and $40 million for~~price variance is primarily due to reconcilable cost recovery mechanisms approved by the ~~three and nine months ended September 30, 2017.~~PUC.


(b)	~~Decrease for the nine months ended September 30, 2017 compared with 2016,~~The increases were primarily due to higher energy volumes, partially offset by lower energy ~~prices at PPL Electric.~~prices.

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(c)	Transmission Formula Rate revenues include the impacts of the TCJA which reduced the new revenue requirement that went into effect June 1, 2018.


(d)	Represents the estimated income tax savings owed to or already returned to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 7 to the Financial Statements for additional information.


(e)	Increases were primarily due to favorable weather in 2018.

Fuel

Fuel ~~decreased~~increased $~~25 million~~ ~~for the three months ended~~ ~~September 30, 2017~~ ~~compared with~~ ~~2016, primarily due to a $16 million decrease in volumes driven by milder weather in the third quarter of 2017 and a $9 million decrease in market prices for coal.~~

~~Fuel decreased~~ ~~$31~~33 million for the nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017, primarily due to a ~~$28~~$40 million ~~decrease~~increase in volumes driven by ~~milder~~ weather in ~~2017 and a $4~~2018, partially offset by an $8 million decrease in ~~market prices for coal.~~commodity costs.

Energy Purchases

Energy purchases ~~decreased $8~~increased $6 million for the three months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to a ~~$12~~$17 million ~~decrease~~increase in PLR volumes, partially offset by a $6$7 million ~~increase~~decrease in PLR prices at PPL Electric.

Energy purchases ~~decreased $37~~increased $44 million for the nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to a ~~$24~~$42 million increase in PLR volumes, partially offset by a $9 million decrease in PLR prices at PPL Electric and an ~~$11~~$18 million increase in natural gas volumes driven by weather in 2018, partially offset by a $6 million decrease in ~~PLR volumes~~market prices for natural gas at ~~PPL Electric.~~LG&E.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:

Three Months Nine Months
Domestic:
PPL Electric Act 129 $ 3
$ 11
PPL Electric payroll-related costs (5 ) (6 )
PPL Electric vegetation management (4 ) (7 )
PPL Electric bad debts (4 ) (10 )
Other (1 ) 1
U.K.:
Pension (a) (17 ) (52 )
Foreign currency exchange rates (2 ) (18 )
Network maintenance 4
(4 )
Third-party engineering (1 ) 5
Other 7
5
Total $ (20 ) $ (75 )
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~~(a)~~	~~The decreases were primarily due to increases in expected returns on higher asset balances and lower interest costs due to a lower discount rate.~~



	Three Months			Nine Months
Domestic:
LKE storm costs	$	8		$	10
LKE timing and scope of generation maintenance outages	—			7
LKE vegetation management	2			5
LKE gas distribution maintenance and compliance	1			4
PPL Electric vegetation management	(1		)	(11		)
PPL Electric storm costs	(1		)	15
PPL Electric payroll-related costs	3			(11		)
PPL Electric Act 129	(1		)	(3		)
PPL Electric bad debts	2			9
PPL Electric Act 129 Smart Meter	—			4
Other	11			16
U.K.:
Foreign currency exchange rates	2			23
Network maintenance	2			6
Third-party engineering	14			29
Other	(1		)	10
Total	$	41		$	113

Depreciation

Depreciation increased ~~$25 million and $53~~$18 million for the three ~~and nine~~ months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to additional assets placed into service, net of retirements, related to the ongoing efforts to ensure the reliability of the delivery system, the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program at PPL Electric and additional assets placed into service, net of retirements at LG&E and KU.

Depreciation increased $72 million for the nine months ended September 30, 2018 compared with 2017, primarily due to additional assets placed into service, net of retirements, related to the ongoing efforts to ensure the reliability of the delivery system, the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program at PPL Electric, higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements at LG&E and KU ~~partially offset by~~and the impact of foreign currency exchange rates at WPD.

Other Income (Expense) - net

Other income (expense) - net ~~decreased $125 million and $519~~increased $141 million for the three ~~and nine~~ months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017 primarily due to ~~changes in~~higher realized and unrealized gains ~~(losses)~~ on foreign currency contracts to economically hedge GBP denominated earnings from ~~WPD.~~WPD of $121 million and an increase in non-service cost credits from defined benefit plans of $20 million.

~~Table~~Other income (expense) - net increased $409 million for the nine months ended September 30, 2018 compared with 2017, primarily due to higher realized and unrealized gains on foreign currency contracts to economically hedge GBP denominated earnings from WPD of ~~Contents~~

$329 million and an increase in non-service cost credits from defined benefit plans of $72 million.

Interest Expense

The increase (decrease) in interest expense for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months		Nine Months
Long-term debt interest expense	$	9		$	22		$	11	$	27
Foreign currency exchange rates							2		19
Short-term debt interest expense	2			6			1		6
Foreign currency exchange rates	(4		)	(31		)
Other	—			1			—		(3		)
Total	$	7		$	(2	)	$	14	$	49

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Income Taxes

The increase (decrease) in income taxes for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Change in pre-tax income at current period tax rates	$	(56	)	$	(198	)
Change in pre-tax income							$	28		$	136
Reduction in U.S. federal income tax rate (a)							(40		)	(128		)
Valuation allowances adjustments	—			(4		)	1			8
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(7		)	(21		)
Impact of U.K. Finance Acts (b)	39			30
U.S. income tax on foreign earnings - net of foreign tax credit (b)							9			26
Impact of U.K. Finance Acts							(1		)	5
Amortization of excess deferred income taxes (a)							(11		)	(30		)
Kentucky state tax reform (c)							—			9
Stock-based compensation	1			5			—			8
Other	—			(1		)	1			7
Total	$	(23	)	$	(189	)	$	(13	)	$	41


(a)	~~Lower~~The decreases are related to the impact of the U.S. federal corporate income ~~taxes~~tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.


(b)	The increases are primarily due to the tax benefit of accelerated pension contributions made in the first quarter of 2017. The related tax benefit iswas recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

~~(b)~~(c)

~~The U.K. Finance Act 2016, enacted in September 2016, reduces~~During the ~~U.K. statutory~~second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective ~~April~~January 1, ~~2020 from 18%~~2018. See Note 6 to ~~17%. As a result, PPL reduced its net deferred tax liabilities and recognized a deferred tax benefit during~~ the ~~three and nine months ended September 30, 2016.~~Financial Statements for additional information.

Segment Earnings

PPL's net income by reportable segments for the periods ended September 30 were as follows:


	Three Months								Nine Months									Three Months								Nine Months
	2017		2016			$ Change			2017			2016			$ Change			2018			2017		$ Change			2018			2017			$ Change
U.K. Regulated	$	126	$	281		$	(155	)	$	560		$	915		$	(355	)	$	245		$	126	$	119		$	836		$	560		$	276
Kentucky Regulated	125		126			(1		)	299			314			(15		)	122			125		(3		)	332			299			33
Pennsylvania Regulated	95		91			4			251			263			(12		)	112			95		17			335			251			84
Corporate and Other (a)	9		(25		)	34			(60		)	(55		)	(5		)	(34		)	9		(43		)	(91		)	(60		)	(31		)
Net Income	$	355	$	473		$	(118	)	$	1,050		$	1,437		$	(387	)	$	445		$	355	$	90		$	1,412		$	1,050		$	362

(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. ~~The changes~~Income taxes were $25 million and $7 million higher for the three and nine months ended in ~~2017~~2018 compared with ~~2016 are~~2017, primarily due to the ~~timing impact~~utilization of ~~recording~~an estimated tax rate, which required tax benefits realized in the first quarter of 2017 to be recognized over the annual ~~estimated taxes. This impact is expected to continue to reverse through~~period. Interest expense was $5 million and $13 million higher for the ~~remainder of the year.~~three and nine months ended in 2018 compared with 2017.

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 effective tax rate of the entity where the activity is recorded. Special items include:

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• Unrealized gains or losses on foreign currency economic hedges (as discussed below).

• 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.

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• Other charges or credits that are, in management's view, non-recurring or otherwise not reflective of the company's ongoing operations.

Unrealized gains or losses on foreign currency economic hedges include the changes in fair value of foreign currency contracts used to hedge GBP-denominated anticipated earnings. The changes in fair value of these contracts are recognized immediately within GAAP earnings. Management believes that excluding these amounts from Earnings from Ongoing Operations until settlement of the contracts provides a better matching of the financial impacts of those contracts with the economic value of PPL's underlying hedged earnings. See Note 1314 to the Financial Statements and "Risk Management" below for additional information on foreign currency economic activity.

PPL's Earnings from Ongoing Operations by reportable segment for the periods ended September 30 were as follows:


	Three Months								Nine Months									Three Months								Nine Months
	2017		2016			$ Change			2017			2016			$ Change			2018			2017		$ Change			2018			2017			$ Change
U.K. Regulated	$	163	$	235		$	(72	)	$	682		$	741		$	(59	)	$	214		$	163	$	51		$	730		$	682		$	48
Kentucky Regulated	125		126			(1		)	300			314			(14		)	120			125		(5		)	339			300			39
Pennsylvania Regulated	95		91			4			251			263			(12		)	117			95		22			340			251			89
Corporate and Other	5		(25		)	30			(64		)	(53		)	(11		)	(29		)	5		(34		)	(86		)	(64		)	(22		)
Earnings from Ongoing Operations	$	388	$	427		$	(39	)	$	1,169		$	1,265		$	(96	)	$	422		$	388	$	34		$	1,323		$	1,169		$	154

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

U.K. Regulated Segment

The U.K. Regulated segment consists of PPL Global, which primarily includes WPD's regulated electricity distribution operations, the results of hedging the translation of WPD's earnings from GBP into U.S. dollars, and certain costs, such as U.S. income taxes, administrative costs and certain acquisition-related financing costs. The U.K. Regulated segment represents ~~53%~~59% of PPL's Net Income for the nine months ended September 30, ~~2017~~2018 and 39% of PPL's assets at September 30, ~~2017.~~2018.

Net Income and Earnings from Ongoing Operations for the periods ended September 30 include the following results.


	Three Months								Nine Months								Three Months							Nine Months
	2017			2016		$ Change			2017			2016		$ Change			2018		2017			$ Change		2018		2017			$ Change
Operating revenues	$	477		$	515	$	(38	)	$	1,547		$	1,673	$	(126	)	$	517	$	477		$	40	$	1,716	$	1,547		$	169
Other operation and maintenance	69			78		(9		)	195			260		(65		)	131		113			18		400		326			74
Depreciation	58			58		—			170			178		(8		)	61		58			3		186		170			16
Taxes, other than income	33			34		(1		)	94			104		(10		)	33		33			—		101		94			7
Total operating expenses	160			170		(10		)	459			542		(83		)	225		204			21		687		590			97
Other Income (Expense) - net	(80		)	50		(130		)	(236		)	283		(519		)	102		(36		)	138		284		(105		)	389
Interest Expense	103			100		3			294			310		(16		)	106		103			3		310		294			16
Income Taxes	8			14		(6		)	(2		)	189		(191		)	43		8			35		167		(2		)	169
Net Income	126			281		(155		)	560			915		(355		)	245		126			119		836		560			276
Less: Special Items	(37		)	46		(83		)	(122		)	174		(296		)	31		(37		)	68		106		(122		)	228
Earnings from Ongoing Operations	$	163		$	235	$	(72	)	$	682		$	741	$	(59	)	$	214	$	163		$	51	$	730	$	682		$	48

The following after-tax gains (losses), which management considers special items, impacted the U.K. Regulated segment's results and are excluded from Earnings from Ongoing Operations during the periods ended September 30.

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Income Statement Line Item Three Months Nine Months
2017 2016 2017 2016
Foreign currency economic hedges, net of tax of $20, $103, $66, $34 (a) Other Income (Expense) - net $ (37 ) $ (193 ) $ (122 ) $ (65 )
Settlement of foreign currency contracts, net of tax of $0, ($108), $0, ($108) (b) Other Income (Expense) - net —
202
—
202
Change in U.K. tax rate (c) Income Taxes —
37
—
37
Total Special Items $ (37 ) $ 46
$ (122 ) $ 174



	Income Statement Line Item	Three Months					Nine Months
	Income Statement Line Item	2018		2017			2018		2017
Foreign currency economic hedges, net of tax of ($7), $20, ($27), $66 (a)	Other Income (Expense) - net	$	28	$	(37	)	$	103	$	(122	)
U.S. tax reform (b)	Income Taxes	3		—			3		—
Total Special Items		$	31	$	(37	)	$	106	$	(122	)


(a)	Represents unrealized gains (losses) on contracts that economically hedge anticipated GBP-denominated earnings. ~~The three and nine months ended September 30, 2016 include the reversal of $310 million ($202 million after-tax) of unrealized gains related to the settlement of 2017 and 2018 contracts.~~

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(b)	~~In the third quarter of 2016, PPL settled 2017 and 2018 foreign currency contracts, resulting in $310 million of cash received ($202 million after-tax).~~

~~The settlement did not have a material impact on net income as the contracts were previously marked to fair value and~~Represents adjustments to certain provisional amounts recognized ~~in "Other Income (Expense) - net" on the Statements of Income.~~

~~(c)~~

The U.K. Finance Act 2016, enacted in September 2016, reduced the U.K.'s statutory income tax rate effective April 1, 2020 from 18% to 17%. As a result, PPL reduced its net deferred tax liability and recognized an income tax benefit of $42 million in the ~~third quarter~~December 31, 2017 Statement of ~~2016. Of this amount, $37 million relates~~Income relating to ~~deferred taxes recorded~~the enactment of the TCJA. See "Tax Cuts and Jobs Act (TCJA)" in ~~prior years and was treated as a special item.~~Note 6 to the Financial Statements for additional information.

The changes in the components of the U.K. Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as U.K. Adjusted Gross Margins, the items that management considers special and the effects of movements in foreign currency exchange, including the effects of foreign currency hedge contracts, on separate lines and not in their respective Statement of Income line items.


	Three Months			Nine Months			Three Months			Nine Months
U.K.
Gross margins	$	(17	)	$	52
U.K. Adjusted Gross Margins							$	21		$	24
Other operation and maintenance	7			50			(1		)	(12		)
Depreciation	(3		)	(12		)	(2		)	(4		)
Other Income (Expense) - net							16			46
Interest expense	(7		)	(15		)	(1		)	3
Other	(2		)	(4		)	(2		)	(3		)
Income taxes	(2		)	2			1			(17		)
U.S.
Interest expense and other	1			3			(3		)	(6		)
Income taxes	(3		)	28			(1		)	(47		)
Foreign currency exchange, after-tax	(46		)	(163		)	23			64
Earnings from Ongoing Operations	(72		)	(59		)	51			48
Special items, after-tax	(83		)	(296		)	68			228
Net Income	$	(155	)	$	(355	)	$	119		$	276

U.K.

See ~~"Margins~~"Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of U.K. Adjusted Gross Margins.

~~Lower~~Higher other ~~operation and maintenance expense~~income (expense) - net for the three and nine month ~~period~~periods primarily ~~due to $17 million~~ from ~~lower~~higher pension ~~expense~~income due to an increase in expected returns on higher asset ~~balances and lower interest costs due to a lower discount rate, partially offset by $4 million from higher network maintenance expense.~~balances.

Lower other operation and maintenance expense for the nine month period primarily due to $52 million from lower pension expense due to an increase in expected returns on higher asset balances and lower interest costs due to a lower discount rate.U.S.

Higher ~~interest expense for the three and nine month periods primarily due to higher interest expense on indexed linked bonds.~~

~~Higher income taxes for the three month period primarily due to $9 million related to tax rate changes to deferred taxes, partially offset by a decrease of $4 million from lower pre-tax income.~~

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~~Lower~~ income taxes for the nine month period primarily due to ~~decreases of $10~~a $35 million ~~related to accelerated tax deductions and $6 million from 2016 expense related to the finalization of U.K. tax returns, partially offset by increases of $14 million from higher pre-tax income.~~

~~U.S.~~

~~Lower income taxes for the nine month period primarily due to the~~ tax benefit on accelerated pension contributions ~~made~~ in the first quarter of ~~2017.~~2017 and a $13 million increase from a reduction in tax benefits on interest deductibility due to the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

Kentucky Regulated Segment

The Kentucky Regulated segment consists primarily of LKE'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 ~~28%~~24% of PPL's Net Income for the nine months ended September 30, ~~2017~~2018 and ~~35%~~34% of PPL's assets at September 30, ~~2017.~~2018.

Net Income and Earnings from Ongoing Operations for the periods ended September 30 include the following results.

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Three Months Nine Months
2017 2016 $ Change 2017 2016 $ Change
Operating revenues $ 818
$ 835
$ (17 ) $ 2,350
$ 2,382
$ (32 )
Fuel 202
227
(25 ) 576
607
(31 )
Energy purchases 22
24
(2 ) 120
118
2
Other operation and maintenance 199
197
2
598
603
(5 )
Depreciation 114
102
12
324
301
23
Taxes, other than income 17
16
1
49
46
3
Total operating expenses 554
566
(12 ) 1,667
1,675
(8 )
Other Income (Expense) - net 1
(3 ) 4
(5 ) (9 ) 4
Interest Expense 65
65
—
196
194
2
Income Taxes 75
75
—
183
190
(7 )
Net Income 125
126
(1 ) 299
314
(15 )
Less: Special Items —
—
—
(1 ) —
(1 )
Earnings from Ongoing Operations $ 125
$ 126
$ (1 ) $ 300
$ 314
$ (14 )



	Three Months								Nine Months
	2018		2017			$ Change			2018			2017			$ Change
Operating revenues	$	802	$	818		$	(16	)	$	2,417		$	2,350		$	67
Fuel	206		202			4			609			576			33
Energy purchases	22		22			—			135			120			15
Other operation and maintenance	216		197			19			632			594			38
Depreciation	119		114			5			354			324			30
Taxes, other than income	18		17			1			53			49			4
Total operating expenses	581		552			29			1,783			1,663			120
Other Income (Expense) - net	—		(1		)	1			(2		)	(9		)	7
Interest Expense	69		65			4			205			196			9
Income Taxes	30		75			(45		)	95			183			(88		)
Net Income	122		125			(3		)	332			299			33
Less: Special Items	2		—			2			(7		)	(1		)	(6		)
Earnings from Ongoing Operations	$	120	$	125		$	(5	)	$	339		$	300		$	39

The following after-tax ~~gain (loss)~~gains (losses), which management considers a special ~~item,~~items, impacted the Kentucky Regulated segment's results and isare excluded from Earnings from Ongoing Operations during the periods ended September 30.


	Income Statement Line Item	Three Months				Nine Months					Income Statement Line Item	Three Months				Nine Months
	Income Statement Line Item	2017		2016		2017			2016		Income Statement Line Item	2018		2017		2018			2017
Adjustment to investment, net of tax of $0, $0, $0, $0 (a)	Other Income (Expense) - net	$	—	$	—	$	(1	)	$	—	Other Income (Expense) - net	$	—	$	—	$	—		$	(1	)
Kentucky state tax reform (b)											Income Taxes	—		—		(9		)	—
U.S. tax reform (c)											Income Taxes	2		—		2			—
Total Special Items		$	—	$	—	$	(1	)	$	—		$	2	$	—	$	(7	)	$	(1	)


(a)	KU recorded a write-off of an equity method investment.


(b)	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.


(c)	Represents adjustments to certain provisional amounts recognized in the December 31, 2017 Statement of Income relating to the enactment of the TCJA. See "Tax Cuts and Jobs Act (TCJA)" in Note 6 to the Financial Statements for additional information.

The changes in the components of the Kentucky Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as Kentucky Adjusted Gross Margins and the ~~item~~items that management considers special on separate lines and not in their respective Statement of Income line items.



	Three Months			Nine Months
Kentucky Adjusted Gross Margins	$	(19	)	$	24
Other operation and maintenance	(23		)	(46		)
Depreciation	(3		)	(26		)
Taxes, other than income	—			(5		)
Other Income (Expense) - net	1			6
Interest Expense	(4		)	(9		)
Income Taxes	43			95
Earnings from Ongoing Operations	(5		)	39
Special items, after-tax	2			(6		)
Net Income	$	(3	)	$	33

See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Kentucky Adjusted Gross Margins.

Higher other operation and maintenance expense for the three month period primarily due to an $8 million increase in storm costs, a $2 million increase in vegetation management expense and increases in other costs that were not individually significant in comparison to the prior year.

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Three Months Nine Months
Kentucky Gross Margins $ 10
$ (13 )
Other operation and maintenance (5 ) 6
Depreciation (10 ) (15 )
Taxes, other than income —
(2 )
Other Income (Expense) - net 4
5
Interest Expense —
(2 )
Income Taxes —
7
Earnings from Ongoing Operations (1 ) (14 )
Special items, after-tax —
(1 )
Net Income $ (1 ) $ (15 )

~~See "Margins - Changes~~Higher other operation and maintenance expense for the nine month period primarily due to a $10 million increase in ~~Margins" for an explanation~~storm costs, a $7 million increase in costs related to the timing and scope of ~~Kentucky Gross Margins.~~generation maintenance outages, a $5 million increase in vegetation management expenses, a $4 million increase in costs related to gas distribution maintenance and compliance and increases in other costs that were not individually significant in comparison to the prior year.

Higher depreciation expense for the ~~three and~~ nine month ~~periods primarily~~period due to a $14 million increase related to additional assets placed into service, net of retirements and a $12 million increase related to higher depreciation rates effective July 1, ~~2017,~~2017.

Higher interest expense for the nine month period due to higher interest rates and ~~additions~~increased borrowings under LG&E's term loan credit facility and KU's commercial paper program.

Lower income taxes for the three month period primarily due to ~~PP&E, net~~a $21 million decrease related to the impact of ~~retirements.~~the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018, an $18 million decrease related to lower pre-tax income.

Lower income taxes for the nine month period primarily due to a $60 million decrease related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018, a $22 million decrease related to lower pre-tax income and a $14 million decrease related to higher amortization of excess deferred income taxes as a result of the TCJA.

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 24% of PPL's Net Income for the nine months ended September 30, ~~2017~~2018 and ~~25%~~26% of PPL's assets at September 30, ~~2017.~~2018.

Net Income and Earnings from Ongoing Operations for the periods ended September 30 include the following results.


	Three Months							Nine Months							Three Months								Nine Months
	2017		2016		$ Change			2017		2016		$ Change			2018			2017		$ Change			2018			2017		$ Change
Operating revenues	$	547	$	539	$	8		$	1,620	$	1,619	$	1		$	548		$	547	$	1		$	1,704		$	1,620	$	84
Energy purchases	121		129		(8		)	374		414		(40		)	127			121		6			403			374		29
Other operation and maintenance	132		143		(11		)	435		431		4			127			133		(6		)	419			435		(16		)
Depreciation	77		64		13			228		185		43			89			77		12			262			228		34
Taxes, other than income	27		26		1			79		79		—			27			27		—			81			79		2
Total operating expenses	357		362		(5		)	1,116		1,109		7			370			358		12			1,165			1,116		49
Other Income (Expense) - net	5		4		1			11		12		(1		)	9			6		3			23			11		12
Interest Expense	36		32		4			105		97		8			40			36		4			116			105		11
Income Taxes	64		58		6			159		162		(3		)	35			64		(29		)	111			159		(48		)
Net Income	95		91		4			251		263		(12		)	112			95		17			335			251		84
Less: Special Items (a)	—		—		—			—		—		—
Less: Special Item															(5		)	—		(5		)	(5		)	—		(5		)
Earnings from Ongoing Operations	$	95	$	91	$	4		$	251	$	263	$	(12	)	$	117		$	95	$	22		$	340		$	251	$	89

The following after-tax gain (loss), which management considers a special item, impacted the Pennsylvania Regulated segment's results and is excluded from Earnings from Ongoing Operations during the periods ended September 30.



	Income Statement Line Item	Three Months					Nine Months
	Income Statement Line Item	2018			2017		2018			2017
IT transformation, net of tax of $2, $0, $2, $0 (a)	Other operation and maintenance	$	(5	)	$	—	$	(5	)	$	—
Total Special Item		$	(5	)	$	—	$	(5	)	$	—

(a)

~~There are no items that management considers special~~In June 2018, PPL EU Services’ IT department announced an internal reorganization which was substantially completed in the third quarter of 2018. As a result, $5 million of after-tax costs, which includes separation benefits as well as outside services for strategic consulting to establish the ~~periods presented.~~new IT organization, were incurred. See Note 10 to the Financial Statements for additional information on separation benefits.

Table of Contents

The changes in the components of the Pennsylvania Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as Pennsylvania Adjusted Gross Margins and the item that management considers special on a separate line and not in their respective Statement of Income line items.

Three Months Nine Months
Pennsylvania Gross Margins $ 6
$ 14
Other operation and maintenance 16
8
Depreciation (8 ) (29 )
Taxes, other than income (1 ) 1
Other Income (Expense) - net 1
(1 )
Interest Expense (4 ) (8 )
Income Taxes (6 ) 3
Net Income $ 4
$ (12 )

~~Table of Contents~~



	Three Months			Nine Months
Pennsylvania Adjusted Gross Margins	$	(4	)	$	39
Other operation and maintenance	7			27
Depreciation	(8		)	(23		)
Taxes, other than income	—			(1		)
Other Income (Expense) - net	4			12
Interest Expense	(4		)	(11		)
Income Taxes	27			46
Earnings from Ongoing Operations	22			89
Special Item, after tax	(5		)	(5		)
Net Income	$	17		$	84

See ~~"Margins~~"Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Pennsylvania Adjusted Gross Margins.

Lower other operation and maintenance expense for the three month period primarily due to $5$14 million of lower ~~payroll related expenses, $4~~corporate service costs allocated to PPL Electric, partially offset by $3 million of ~~lower~~higher nonrecoverable storm expenses and $2 million of higher bad debt ~~expense and $4 million of lower vegetation management expenses.~~expense.

Lower other operation and maintenance expense for the nine month period primarily due to ~~$10~~$31 million of lower ~~bad debt~~corporate service costs allocated to PPL Electric, $11 million of lower payroll related expenses $7and $11 million of lower vegetation management expenses, ~~and $7 million of lower payroll related expenses,~~ partially offset by ~~$17~~$12 million of higher ~~corporate service costs allocated to PPL Electric.~~nonrecoverable storm expenses and $9 million of higher bad debt expense.

Higher depreciation expense for the three and nine month periods primarily due to ~~transmission and distribution additions~~additional assets placed into service, related to the ongoing efforts to ~~improve~~ensure the reliability of the delivery system and ~~replace~~the replacement of aging infrastructure, net of retirements.

Higher interest expense for the nine month period primarily due to the May 2017 issuance of $475 million of 3.950% First Mortgage Bonds ~~in May 2017.~~and the June 2018 issuance of $400 million of 4.15% First Mortgage Bonds.

Lower income taxes for the three month period primarily due to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018 of $18 million and lower pre-tax income resulting in $7 million of lower income taxes.

Lower income taxes for the nine month period primarily due to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018 of $56 million and $13 million of lower income taxes due to amortization of excess deferred income taxes, partially offset by higher pre-tax income resulting in $14 million of higher income taxes.

Reconciliation of Earnings from Ongoing Operations

The following tables contain after-tax gains (losses), in total, which management considers special items, that are excluded from Earnings from Ongoing Operations and a reconciliation to PPL's "Net Income" for the periods ended September 30.

2017 Three Months

U.K.
Regulated

KY
Regulated

PA
Regulated

Corporate
and Other
Total
Net Income $ 126
$ 125
$ 95
$ 9
$ 355
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $20 (37 ) —
—
—
(37 )
Spinoff of the Supply segment, net of tax of ($2) (a) —
—
—
4
4
Total Special Items (37 ) —
—
4
(33 )
Earnings from Ongoing Operations $ 163
$ 125
$ 95
$ 5
$ 388

2016 Three Months

U.K.
Regulated

KY
Regulated

PA
Regulated

Corporate
and Other
Total
Net Income $ 281
$ 126
$ 91
$ (25 ) $ 473
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $103 (193 ) —
—
—
(193 )
Other:

Settlement of foreign currency contracts, net of tax of ($108) 202
—
—
—
202
Change in U.K. tax rate 37
—
—
—
37
Total Special Items 46
—
—
—
46
Earnings from Ongoing Operations $ 235
$ 126
$ 91
$ (25 ) $ 427

2017 Nine Months

U.K.
Regulated

KY
Regulated

PA
Regulated

Corporate
and Other
Total
Net Income $ 560
$ 299
$ 251
$ (60 ) $ 1,050
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $66 (122 ) —
—
—
(122 )
Spinoff of the Supply segment, net of tax of ($2) (a) —
—
—
4
4
Adjustment to investment, net of tax of $0 —
(1 ) —
—
(1 )
Total Special Items (122 ) (1 ) —
4
(119 )
Earnings from Ongoing Operations $ 682
$ 300
$ 251
$ (64 ) $ 1,169

Table of Contents

2016 Nine Months

U.K.
Regulated

KY
Regulated

PA
Regulated

Corporate
and Other
Total
Net Income $ 915
$ 314
$ 263
$ (55 ) $ 1,437
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $34 (65 ) —
—
—
(65 )
Spinoff of the Supply segment, net of tax of $2 —
—
—
(2 ) (2 )
Other:

Settlement of foreign currency contracts, net of tax of ($108) 202
—
—
—
202
Change in U.K. tax rate 37
—
—
—
37
Total Special Items 174
—
—
(2 ) 172
Earnings from Ongoing Operations $ 741
$ 314
$ 263
$ (53 ) $ 1,265



	2018 Three Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total
Net Income	$	245		$	122		$	112		$	(34	)	$	445
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($7)	28			—			—			—			28
U.S. tax reform	3			2			—			(5		)	—
IT transformation, net of tax of $2	—			—			(5		)	—			(5		)
Total Special Items	31			2			(5		)	(5		)	23
Earnings from Ongoing Operations	$	214		$	120		$	117		$	(29	)	$	422

	2017 Three Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total
Net Income	$	126		$	125		$	95		$	9		$	355
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $20	(37		)	—			—			—			(37		)
Spinoff of the Supply segment, net of tax of ($2) (a)	—			—			—			4			4
Total Special Items	$	(37	)	$	—		$	—		$	4		$	(33	)
Earnings from Ongoing Operations	$	163		$	125		$	95		$	5		$	388

	2018 Nine Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total
Net Income	$	836		$	332		$	335		$	(91	)	$	1,412
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($27)	103			—			—			—			103
U.S. tax reform	3			2			—			(5		)	—
Kentucky state tax reform	—			(9		)	—			—			(9		)
IT transformation, net of tax of $2	—			—			(5		)	—			(5		)
Total Special Items	106			(7		)	(5		)	(5		)	89
Earnings from Ongoing Operations	$	730		$	339		$	340		$	(86	)	$	1,323

	2017 Nine Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total
Net Income	$	560		$	299		$	251		$	(60	)	$	1,050
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $66	(122		)	—			—			—			(122		)
Spinoff of the Supply segment, net of tax of ($2) (a)	—			—			—			4			4
Adjustment to investment, net of tax of $0	—			(1		)	—			—			(1		)
Total Special Items	(122		)	(1		)	—			4			(119		)
Earnings from Ongoing Operations	$	682		$	300		$	251		$	(64	)	$	1,169

(a) Represents a tax settlement associated with the former Supply segment. Included in "Taxes, and other than income" on the Statement of Income.


~~(a)~~	~~Represents a tax settlement associated with the former Supply segment. Included in "Taxes, other than income" on the Statements of Income.~~

Adjusted Gross Margins

Management also utilizes the following non-GAAP financial measures as indicators of performance for its businesses:

Table of Contents

"U.K. Adjusted Gross Margins" is a single financial performance measure of the electricity distribution operations of the U.K. Regulated segment. In calculating this measure, direct costs such as connection charges from National Grid, which owns and manages the electricity transmission network in England and Wales, and Ofgem license fees (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues, as they are costs passed through to customers. As a result, this measure represents the net revenues from the delivery of electricity across WPD's distribution network in the U.K. and directly related activities.

"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. 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 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 segment and by component, as applicable, for the periods ended September 30 as well as the change between periods. The factors that gave rise to the changes are described following the table.



	Three Months							Nine Months
	2018		2017		$ Change			2018		2017		$ Change
U.K. Regulated
U.K. Adjusted Gross Margins	$	467	$	441	$	26		$	1,578	$	1,446	$	132
Impact of changes in foreign currency exchange rates					5							108
U.K. Adjusted Gross Margins excluding impact of foreign currency exchange rates					$	21						$	24

Kentucky Regulated
Kentucky Adjusted Gross Margins
LG&E	$	240	$	245	$	(5	)	$	697	$	678	$	19
KU	288		302		(14		)	847		842		5
Total Kentucky Adjusted Gross Margins	$	528	$	547	$	(19	)	$	1,544	$	1,520	$	24

Pennsylvania Regulated
Pennsylvania Adjusted Gross Margins
Distribution	$	225	$	233	$	(8	)	$	695	$	710	$	(15	)
Transmission	138		134		4			411		357		54
Total Pennsylvania Adjusted Gross Margins	$	363	$	367	$	(4	)	$	1,106	$	1,067	$	39

Table of Contents

Three Months Nine Months
2017 2016 $ Change 2017 2016 $ Change
U.K. Regulated

U.K. Gross Margins $ 441
$ 476
$ (35 ) $ 1,446
$ 1,566
$ (120 )
Impact of changes in foreign currency exchange rates (18 ) (172 )
U.K. Gross Margins excluding impact of foreign currency exchange rates $ (17 ) $ 52

Kentucky Regulated
Kentucky Gross Margins
LG&E $ 245
$ 237
$ 8
$ 678
$ 676
$ 2
KU 302
300
2
842
857
(15 )
Total Kentucky Gross Margins $ 547
$ 537
$ 10
$ 1,520
$ 1,533
$ (13 )

Pennsylvania Regulated
Pennsylvania Gross Margins
Distribution $ 233
$ 246
$ (13 ) $ 710
$ 721
$ (11 )
Transmission 134
115
19
357
332
25
Total Pennsylvania Gross Margins $ 367
$ 361
$ 6
$ 1,067
$ 1,053
$ 14

U.K. Adjusted Gross Margins

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, ~~decreased~~increased for the three months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to ~~$12 million of lower volumes and $3~~$19 million from the April 1, ~~2017~~2018 price ~~decrease, which includes lower true-up mechanisms partially offset by higher base demand revenue.~~increase.

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased for the nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to ~~$83~~$29 million from the April 1, ~~2016~~2018 price increase, partially offset by ~~$24 million of lower volumes and $9~~$10 million from the April 1, 2017 price decrease, ~~which includes~~driven by lower true-up mechanisms partially offset by higher base demand revenue.

Kentucky Adjusted Gross Margins

Kentucky Adjusted Gross Margins ~~increased~~decreased for the three months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to $30 million of estimated income tax savings owed to customers ($14 million at LG&E and $16 million at KU) related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018, partially offset by $8 million of increased sales volumes related to favorable weather in 2018 ($5 million at LG&E and $3 million at KU) and returns on additional environmental capital investments of $4 million ($2 million at LG&E and $2 million at KU).

Kentucky Adjusted Gross Margins increased for the nine months ended September 30, 2018 compared with 2017, primarily due to $59 million of increased sales volumes related to favorable weather in 2018 ($21 million at LG&E and $38 million at KU), higher base rates of ~~$31~~$58 million ($1832 million at LG&E and ~~$13~~$26 million at KU) as new base rates were approved by the KPSC effective July 1, 2017 ~~partially offset by $20~~and returns on additional environmental capital investments of $14 million ~~of lower sales volumes due to milder weather in 2017~~ ($8 million at LG&E and ~~$12~~$6 million at KU)., partially offset by $109 million of estimated income tax savings owed to customers ($51 million at LG&E and $58 million at KU) related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

~~Kentucky~~Pennsylvania Adjusted Gross Margins

Distribution

Distribution Adjusted Gross Margins decreased for the three months ended September 30, 2018 compared with 2017, primarily due to a $17 million negative surcharge, which was effective as of July 1, 2018, related to the estimated income tax savings as a result of the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA. This decrease was partially offset by $11 million of higher electricity sales volumes primarily due to weather.

Distribution Adjusted Gross Margins decreased for the nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to ~~$51~~a $37 million net of ~~lower sales volumes due~~gross receipts tax impact of the estimated income tax savings owed to ~~milder weather in 2017 ($17~~customers for the period January 1, 2018 through June 30, 2018 and $17 million ~~at LG&E and $34 million at KU)~~from the negative surcharge beginning on July 1, 2018, as a result of the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA. These decreases were partially offset by $36 million of higher ~~base rates of $31 million ($18 million at LG&E and $13 million at KU) as new base rates were approved by the KPSC effective July 1, 2017.~~

~~Pennsylvania Gross Margins~~

~~Distribution~~

~~Distribution margins decreased for the three and nine month periods ended September 30, 2017 compared with 2016,~~electricity sales volumes primarily due to ~~$11 million~~weather and ~~$16~~$6 million of ~~lower electricity sales volumes due to milder weather in 2017.~~returns on additional Smart Meter capital investments.

Transmission

Transmission ~~margins~~Adjusted Gross Margins increased for the three months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to an increase of ~~$20~~$23 million ~~from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability.~~

~~Table of Contents~~

~~Transmission margins increased for the nine months ended September 30, 2017 compared with 2016, primarily due to an increase of $42 million primarily~~ from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability, partially offset by $16 million from the impact of the reduced federal income taxes as a ~~$17~~result of the TCJA.

Transmission Adjusted Gross Margins increased for the nine months ended September 30, 2018 compared with 2017, primarily due to increases of $49 million ~~decrease~~from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability and $25 million as a result of a ~~lower~~higher PPL zonal peak load billing factor ~~which affected transmission revenue~~ in the first five months of ~~2017.~~2018, partially offset by $22 million from the impact of the reduced federal income taxes as a result of the TCJA.

Table of Contents

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 periods ended September 30.

2017 Three Months
U.K.
Gross
Margins Kentucky
Gross
Margins PA Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 467
(c) $ 818
$ 547
$ 13
$ 1,845
Operating Expenses
Fuel —
202
—
—
202
Energy purchases —
22
121
—
143
Other operation and maintenance 26
30
29
312
397
Depreciation —
16
5
236
257
Taxes, other than income —
1
25
43
69
Total Operating Expenses 26
271
180
591
1,068
Total $ 441
$ 547
$ 367
$ (578 ) $ 777

2016 Three Months
U.K.
Gross
Margins Kentucky
Gross
Margins PA Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 504
(c) $ 835
$ 539
$ 11
$ 1,889
Operating Expenses
Fuel —
227
—
—
227
Energy purchases —
24
129
(2 ) 151
Other operation and maintenance 28
33
24
332
417
Depreciation —
14
—
218
232
Taxes, other than income —
—
25
51
76
Total Operating Expenses 28
298
178
599
1,103
Total $ 476
$ 537
$ 361
$ (588 ) $ 786


	2017 Nine Months												2018 Three Months
	U.K. Gross Margins			Kentucky Gross Margins		PA Gross Margins		Other (a)			Operating Income (b)		U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,517	(c)	$	2,350	$	1,620	$	34		$	5,521	$	508	(c)	$	802	$	548	$	14		$	1,872
Operating Expenses
Fuel	—			576		—		—			576		—			206		—		—			206
Energy purchases	—			120		374		—			494		—			22		127		—			149
Other operation and maintenance	71			82		89		975			1,217		41			26		23		389			479
Depreciation	—			48		14		683			745		—			18		10		247			275
Taxes, other than income	—			4		76		134			214		—			2		25		50			77
Total Operating Expenses	71			830		553		1,792			3,246		41			274		185		686			1,186
Total	$	1,446		$	1,520	$	1,067	$	(1,758	)	$	2,275	$	467		$	528	$	363	$	(672	)	$	686

													2017 Three Months
													U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues													$	467	(c)	$	818	$	547	$	13		$	1,845
Operating Expenses
Fuel													—			202		—		—			202
Energy purchases													—			22		121		—			143
Other operation and maintenance													26			30		29		353			438
Depreciation													—			16		5		236			257
Taxes, other than income													—			1		25		43			69
Total Operating Expenses													26			271		180		632			1,109
Total													$	441		$	547	$	367	$	(619	)	$	736

													2018 Nine Months
													U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues													$	1,687	(c)	$	2,417	$	1,704	$	38		$	5,846
Operating Expenses
Fuel													—			609		—		—			609
Energy purchases													—			135		403		—			538
Other operation and maintenance													109			74		92		1,178			1,453
Depreciation													—			52		26		739			817
Taxes, other than income													—			3		77		154			234
Total Operating Expenses													109			873		598		2,071			3,651
Total													$	1,578		$	1,544	$	1,106	$	(2,033	)	$	2,195

Table of Contents


	2016 Nine Months												2017 Nine Months
	U.K. Gross Margins			Kentucky Gross Margins		PA Gross Margins		Other (a)			Operating Income (b)		U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,641	(c)	$	2,382	$	1,619	$	43		$	5,685	$	1,517	(c)	$	2,350	$	1,620	$	34		$	5,521
Operating Expenses
Fuel	—			607		—		—			607		—			576		—		—			576
Energy purchases	—			118		414		(1		)	531		—			120		374		—			494
Other operation and maintenance	75			81		77		1,059			1,292		71			82		89		1,098			1,340
Depreciation	—			40		—		652			692		—			48		14		683			745
Taxes, other than income	—			3		75		151			229		—			4		76		134			214
Total Operating Expenses	75			849		566		1,861			3,351		71			830		553		1,915			3,369
Total	$	1,566		$	1,533	$	1,053	$	(1,818	)	$	2,334	$	1,446		$	1,520	$	1,067	$	(1,881	)	$	2,152


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.


(c)	Excludes ancillary revenues of $8 million and $29 million for the three and nine months ended September 30, 2018 and $11 million and $30 million for the three and nine months ended September 30, ~~2017 and $11 million and $32 million for the three and nine months ended September 30, 2016.~~2017.

~~2017~~ 2018Outlook

(PPL)

The following projections and factors underlying these projections (on an after-tax basis) are provided for PPL's segments and the Corporate and Other category and the related Registrants.

(PPL's U.K. Regulated Segment)

~~Lower~~Higher net income is projected in ~~2017~~2018 compared with ~~2016,~~2017. The increase in net income reflects the 2017 unfavorable impact of U.S. tax reform and unrealized losses on foreign currency economic hedges. Excluding these 2017 special items, the increase is expected to be driven primarily ~~driven~~ by ~~a lower~~higher assumed GBP exchange ~~rate in 2017, lower true-up mechanisms, lower incentive revenues, higher interest expense~~rates and higher ~~depreciation expense,~~pension income, partially offset by ~~lower operation and maintenance expense, including pension expense, and~~ higher ~~base revenue from the April 1, 2017 price reset.~~taxes.

(PPL's Kentucky Regulated Segment and LKE, LG&E and KU)

~~Lower~~Higher net income is projected in ~~2017~~2018 compared with ~~2016, primarily~~2017, which reflects the 2017 unfavorable impact of U.S. tax reform. Excluding this 2017 special item, earnings in 2018 compared with 2017 are projected to be slightly higher, driven by ~~lower~~favorable weather and higher base electricity ~~sales volumes due to unfavorable weather in~~and gas rates effective July 1, 2017, partially offset by higher operation and maintenance expense, higher depreciation expense, ~~partially offset by electricity~~higher interest expense and ~~gas base rate increases.~~a lower tax shield on holding company interest and expenses.

(PPL's Pennsylvania Regulated Segment and PPL Electric)

~~Relatively flat~~Higher net income is projected in ~~2017~~2018 compared with ~~2016,~~2017, primarily driven by higher transmission earnings, ~~and lower operation and maintenance expense,~~partially offset by higher depreciation expense and higher interest expense.

(PPL's Corporate and Other Category)

~~Relatively flat~~Lower costs are projected in ~~2017~~2018 compared with ~~2016.~~2017, which reflects the 2017 unfavorable impact of U.S. tax reform. Excluding this 2017 special item, costs are projected to be higher in 2018 compared to 2017, due to a lower tax shield on holding company interest expense.

(All Registrants)

Earnings in future periods are subject to various risks and uncertainties. See "Forward-Looking Information," the rest of this Item 2, Notes 67 and 910 to the Financial Statements and "Item 1A. Risk Factors" in this Form 10-Q (as applicable) and "Item 1. Business" and "Item 1A. Risk Factors" in the Registrants' ~~2016~~2017 Form 10-K for a discussion of the risks, uncertainties and factors that may impact future earnings.

Table of Contents

PPL Electric: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the periods ended September 30 includes the following results.


	Three Months							Nine Months							Three Months							Nine Months
	2017		2016		$ Change			2017		2016		$ Change			2018		2017		$ Change			2018		2017		$ Change
Operating Revenues	$	547	$	539	$	8		$	1,620	$	1,619	$	1		$	548	$	547	$	1		$	1,704	$	1,620	$	84
Operating Expenses
Operation
Energy purchases	121		129		(8		)	374		414		(40		)	127		121		6			403		374		29
Other operation and maintenance	133		144		(11		)	435		431		4			127		133		(6		)	419		435		(16		)
Depreciation	77		64		13			228		185		43			89		77		12			262		228		34
Taxes, other than income	27		26		1			79		79		—			27		27		—			81		79		2
Total Operating Expenses	358		363		(5		)	1,116		1,109		7			370		358		12			1,165		1,116		49
Other Income (Expense) - net	4		4		—			8		12		(4		)	5		4		1			18		8		10
Interest Income from Affiliate	2		—		2			3		—		3			4		2		2			5		3		2
Interest Expense	36		32		4			105		97		8			41		36		5			117		105		12
Income Taxes	64		58		6			159		162		(3		)	35		64		(29		)	111		159		(48		)
Net Income	$	95	$	90	$	5		$	251	$	263	$	(12	)	$	111	$	95	$	16		$	334	$	251	$	83

Operating Revenues

The increase (decrease) in operating revenues for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Distribution Price (a)	$	16		$	46
Distribution price (a)							$	(6	)	$	5
Distribution volume	(20		)	(30		)	17			49
PLR (b)	(1		)	(32		)	5			31
Transmission Formula Rate(c)	20			25			3			53
TCJA refund (d)							(20		)	(57		)
Other	(7		)	(8		)	2			3
Total	$	8		$	1		$	1		$	84


(a)	Distribution ~~rider prices resulted in increases of $16 million and $40 million for~~price variance is primarily due to reconcilable cost recovery mechanisms approved by the ~~three and nine months ended September 30, 2017.~~PUC.


(b)	The ~~decrease for the nine month period was~~increases were primarily due to higher energy volumes, partially offset by lower energy prices as described below.


(c)	Transmission Formula Rate revenues include the impacts of the TCJA which reduced the new revenue requirement that went into effect June 1, 2018.


(d)	Represents the estimated income tax savings owed to or already returned to distribution customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 7 to the Financial Statements for additional information.

Energy Purchases

Energy purchases ~~decreased $8~~increased $6 million for the three months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to ~~lower~~higher PLR volumes of ~~$12~~$17 million, partially offset by ~~higher~~lower PLR prices of $6$7 million.

Energy purchases ~~decreased $40~~increased $29 million for the nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to higher PLR volumes of $42 million, partially offset by lower PLR prices of ~~$24 million and lower PLR volumes~~$9 million.

Table of ~~$11 million.~~Contents

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:

~~Table of Contents~~


	Three Months			Nine Months			Three Months			Nine Months
Corporate service costs	$	—		$	17		$	(6	)	$	(23	)
Vegetation management	(4		)	(7		)	(1		)	(11		)
Storm costs							(1		)	15
Payroll-related costs	(5		)	(6		)	3			(11		)
Act 129	3			11			(1		)	(3		)
Bad debts	(4		)	(10		)	2			9
Act 129 Smart Meter							—			4
Other	(1		)	(1		)	(2		)	4
Total	$	(11	)	$	4		$	(6	)	$	(16	)

Depreciation

Depreciation increased ~~$13~~$12 million and ~~$43~~$34 million for the three and nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, 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.

Other Income (Expense) - net

Other income (expense) - net increased $10 million for the nine months ended September 30, 2018 compared with 2017, primarily due to a $4 million increase related to higher AFUDC equity rates and a $4 million increase in non-service cost credits from defined benefit plans.

Interest Expense

Interest expense increased ~~$4 million and $8~~$12 million for the ~~three and~~ nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to the May 2017 issuance of $475 million of ~~3.950%~~3.95% First Mortgage Bonds due ~~2047.~~2047 and the June 2018 issuance of $400 million of 4.15% First Mortgage Bonds due 2048.

Income Taxes

The increase (decrease) in income taxes for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months		Nine Months			Three Months			Nine Months
Change in pre-tax income at current period tax rates	$	3	$	(7	)
Change in pre-tax income						$	(5	)	$	15
Reduction in U.S. federal income tax rate (a)						(18		)	(56		)
Amortization of excess deferred income taxes (a)						(5		)	(13		)
Stock-based compensation	—		2			—			5
Other	3		2			(1		)	1
Total	$	6	$	(3	)	$	(29	)	$	(48	)


(a)	The decreases are related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

Earnings


	Three Months Ended				Nine Months Ended				Three Months Ended					Nine Months Ended
	September 30,				September 30,				September 30,					September 30,
	2017		2016		2017		2016		2018			2017		2018			2017
Net Income	$	95	$	90	$	251	$	263	$	111		$	95	$	334		$	251
Special items, gains (losses), after-tax (a)	—		—		—		—
Special Item, gain (loss), after-tax (a)									(5		)	—		(5		)	—

Table of Contents

(a)

~~There are no items that management considers special~~In June 2018, PPL EU Services’ Information Technology (IT) department announced an internal reorganization which was substantially completed in the third quarter of 2018. As a result, $5 million of after-tax costs, which includes separation benefits as well as outside services for strategic consulting to establish the ~~periods presented.~~new IT organization, were incurred. See Note 10 to the Financial Statements for additional information on separation benefits.

~~Earnings~~Excluding a special item, earnings increased for the three month period in ~~2017~~2018 compared with ~~2016 as higher transmission margins from~~2017, driven primarily by returns on additional capital investments in transmission, higher sales volumes primarily due to weather, and lower ~~other~~ operation and maintenance expense, ~~were~~partially offset by ~~lower sales volumes due to unfavorable weather and~~ higher depreciation expense.

~~Earnings decreased~~Excluding a special item, earnings increased for the nine month period in ~~2017~~2018 compared with ~~2016,~~2017, driven primarily by returns on additional capital investments in transmission, higher sales volumes primarily due to weather, and lower operation and maintenance expense, partially offset by higher depreciation expense ~~primarily due to transmission~~ and ~~distribution additions placed into service related to the ongoing efforts to improve reliability and replace aging infrastructure, net of retirements,~~ higher interest expense and lower distribution margins primarily due to lower sales volumes due to unfavorable weather in 2017. Higher transmission margins from additional capital investments were partially offset by a lower PPL zonal peak load billing factor..

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Pennsylvania Adjusted Gross Margins and the item that management considers special on a separate ~~line~~lines and not in their respective Statement of Income line items.

~~Table of Contents~~



	Three Months			Nine Months
Pennsylvania Adjusted Gross Margins	$	(4	)	$	39
Other operation and maintenance	8			27
Depreciation	(8		)	(23		)
Taxes, other than income	—			(1		)
Other Income (Expense) - net	3			12
Interest Expense	(5		)	(12		)
Income Taxes	27			46
Special Item, gain (loss), after tax (a)	(5		)	(5		)
Net Income	$	16		$	83


(a)	See PPL's "Results of Operations - Segment Earnings - Pennsylvania Regulated Segment" for details of the special item.

Three Months Nine Months
Pennsylvania Gross Margins $ 6
$ 14
Other operation and maintenance 16
8
Depreciation (8 ) (29 )
Taxes, other than income (1 ) 1
Other Income (Expense) - net 2
(1 )
Interest Expense (4 ) (8 )
Income Taxes (6 ) 3
Net Income $ 5
$ (12 )

Adjusted Gross Margins

"~~Pennsylvania~~Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for information on why management believes this measure is useful and for explanations of the underlying drivers of the changes between periods. Within PPL's discussion, PPL Electric's Adjusted Gross Margins are referred to as "Pennsylvania Adjusted Gross Margins."

The following tables contain the components from the Statements of Income that are included in this non-GAAP financial measure and a reconciliation to "Operating Income" for the periods ended September 30.


	2017 Three Months							2016 Three Months							2018 Three Months							2017 Three Months
	PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	547	$	—		$	547	$	539	$	—		$	539	$	548	$	—		$	548	$	547	$	—		$	547
Operating Expenses
Energy purchases	121		—			121		129		—			129		127		—			127		121		—			121
Other operation and maintenance	29		104			133		24		120			144		23		104			127		29		104			133
Depreciation	5		72			77		—		64			64		10		79			89		5		72			77
Taxes, other than income	25		2			27		25		1			26		25		2			27		25		2			27
Total Operating Expenses	180		178			358		178		185			363		185		185			370		180		178			358
Total	$	367	$	(178	)	$	189	$	361	$	(185	)	$	176	$	363	$	(185	)	$	178	$	367	$	(178	)	$	189

	2017 Nine Months							2016 Nine Months
	PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,620	$	—		$	1,620	$	1,619	$	—		$	1,619
Operating Expenses
Energy purchases	374		—			374		414		—			414
Other operation and maintenance	89		346			435		77		354			431
Depreciation	14		214			228		—		185			185
Taxes, other than income	76		3			79		75		4			79
Total Operating Expenses	553		563			1,116		566		543			1,109
Total	$	1,067	$	(563	)	$	504	$	1,053	$	(543	)	$	510

Table of Contents



	2018 Nine Months							2017 Nine Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,704	$	—		$	1,704	$	1,620	$	—		$	1,620
Operating Expenses
Energy purchases	403		—			403		374		—			374
Other operation and maintenance	92		327			419		89		346			435
Depreciation	26		236			262		14		214			228
Taxes, other than income	77		4			81		76		3			79
Total Operating Expenses	598		567			1,165		553		563			1,116
Total	$	1,106	$	(567	)	$	539	$	1,067	$	(563	)	$	504


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.

~~Table of Contents~~

LKE: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the periods ended September 30 includes the following results.


	Three Months								Nine Months									Three Months								Nine Months
	2017		2016			$ Change			2017			2016			$ Change			2018		2017			$ Change			2018			2017			$ Change
Operating Revenues	$	818	$	835		$	(17	)	$	2,350		$	2,382		$	(32	)	$	802	$	818		$	(16	)	$	2,417		$	2,350		$	67
Operating Expenses
Operation
Fuel	202		227			(25		)	576			607			(31		)	206		202			4			609			576			33
Energy purchases	22		24			(2		)	120			118			2			22		22			—			135			120			15
Other operation and maintenance	199		197			2			598			603			(5		)	216		197			19			632			594			38
Depreciation	114		102			12			324			301			23			119		114			5			354			324			30
Taxes, other than income	17		16			1			49			46			3			18		17			1			53			49			4
Total Operating Expenses	554		566			(12		)	1,667			1,675			(8		)	581		552			29			1,783			1,663			120
Other Income (Expense) - net	1		(3		)	4			(5		)	(9		)	4			—		(1		)	1			(2		)	(9		)	7
Interest Expense	49		50			(1		)	148			147			1			52		49			3			154			148			6
Interest Expense with Affiliate	5		4			1			13			12			1			7		5			2			18			13			5
Income Taxes	79		79			—			195			202			(7		)	32		79			(47		)	102			195			(93		)
Net Income	$	132	$	133		$	(1	)	$	322		$	337		$	(15	)	$	130	$	132		$	(2	)	$	358		$	322		$	36

Operating Revenues

The increase (decrease) in operating revenues for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Volumes (a)							$	19		$	122
Base rates	$	31		$	31		—			58
Volumes	(41		)	(86		)
ECR							5			18
TCJA refund (b)							(30		)	(109		)
DSM							(2		)	(13		)
Fuel and other energy prices	(8		)	10			(8		)	(15		)
Other	1			13			—			6
Total	$	(17	)	$	(32	)	$	(16	)	$	67

Table of Contents


(a)	Increases were primarily due to favorable weather in 2018.


(b)	Represents estimated income tax savings owed to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 7 to the Financial Statements for additional information.

Fuel

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance for ~~coal.~~the periods ended September 30, 2018 compared with 2017 was due to:



	Three Months		Nine Months
Storm costs	$	8	$	10
Timing and scope of generation maintenance outages	—		7
Vegetation management	2		5
Gas distribution maintenance and compliance	1		4
Other	8		12
Total	$	19	$	38

Depreciation

Depreciation increased $1230 million for the ~~three~~nine months endedSeptember 30, ~~2017~~2018 compared with ~~2016~~2017, primarily due to a $7$15 million increase related to higher depreciation rates effective July 1, 2017 and a $5$12 million increase related to ~~additions to PP&E,~~additional assets placed into service, net of retirements.

~~Depreciation increased~~ ~~$23 million~~Income Taxes

The increase (decrease) in income taxes for the ~~nine months~~periods endedSeptember 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:



	Three Months			Nine Months
Reduction in U.S. federal income tax rate (a)	$	(23	)	$	(64	)
Change in pre-tax income	(19		)	(22		)
Amortization of excess deferred income taxes (a)	(3		)	(14		)
Kentucky state tax reform (b)	—			9
Other	(2		)	(2		)
Total	$	(47	)	$	(93	)


(a)	The decreases are related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.


(b)	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

Earnings



	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2018		2017		2018			2017
Net Income	$	130	$	132	$	358		$	322
Special items, gains (losses), after-tax	2		—		(7		)	(1		)

Excluding special items, earnings increased for the nine month period in 2018 compared with 2017, primarily due to ~~a $16 million increase related to additions to PP&E, net of retirements,~~higher sales volumes driven by favorable weather, higher base electricity and ~~a $7 million increase related to higher depreciation~~gas rates effective July 1, ~~2017.~~

2017 and returns on additional environmental capital investments, partially offset by higher other operation and maintenance expense, higher depreciation expense and higher interest expense.

Table of Contents

~~Earnings~~

Three Months Ended Nine Months Ended
September 30, September 30,
2017 2016 2017 2016
Net Income $ 132
$ 133
$ 322
$ 337
Special items, gains (losses), after-tax —
—
(1 ) —

Earnings decreased for the three and nine month periods in 2017 compared with 2016, primarily due to lower sales volumes driven by milder weather and higher depreciation expense, partially offset by higher base rates effective July 1, 2017.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Adjusted Gross Margins and ~~an item~~items that management considers special on separate lines and not in their respective Statement of Income line items.


	Three Months			Nine Months			Three Months			Nine Months
Margins	$	10		$	(13	)
Adjusted Gross Margins							$	(19	)	$	24
Other operation and maintenance	(5		)	6			(23		)	(46		)
Depreciation	(10		)	(15		)	(3		)	(26		)
Taxes, other than income	—			(2		)	—			(5		)
Other Income (Expense) - net	4			5			1			6
Interest Expense	—			(2		)	(5		)	(11		)
Income Taxes	—			7			45			100
Special items, gains (losses), after-tax (a)	—			(1		)	2			(6		)
Net Income	$	(1	)	$	(15	)	$	(2	)	$	36


(a)	See PPL's "Results of Operations - Segment Earnings - Kentucky Regulated Segment" for details of the special ~~item.~~items.

Adjusted Gross Margins

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, LKE's Adjusted Gross Margins are referred to as "Kentucky Adjusted Gross Margins."

2017 Three Months 2016 Three Months
Margins Other (a) Operating
Income (b) Margins Other (a) Operating
Income (b)
Operating Revenues $ 818
$ —
$ 818
$ 835
$ —
$ 835
Operating Expenses
Fuel 202
—
202
227
—
227
Energy purchases 22
—
22
24
—
24
Other operation and maintenance 30
169
199
33
164
197
Depreciation 16
98
114
14
88
102
Taxes, other than income 1
16
17
—
16
16
Total Operating Expenses 271
283
554
298
268
566
Total $ 547
$ (283 ) $ 264
$ 537
$ (268 ) $ 269

~~Table of Contents~~


	2017 Nine Months							2016 Nine Months							2018 Three Months							2017 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	2,350	$	—		$	2,350	$	2,382	$	—		$	2,382	$	802	$	—		$	802	$	818	$	—		$	818
Operating Expenses
Fuel	576		—			576		607		—			607		206		—			206		202		—			202
Energy purchases	120		—			120		118		—			118		22		—			22		22		—			22
Other operation and maintenance	82		516			598		81		522			603		26		190			216		30		167			197
Depreciation	48		276			324		40		261			301		18		101			119		16		98			114
Taxes, other than income	4		45			49		3		43			46		2		16			18		1		16			17
Total Operating Expenses	830		837			1,667		849		826			1,675		274		307			581		271		281			552
Total	$	1,520	$	(837	)	$	683	$	1,533	$	(826	)	$	707	$	528	$	(307	)	$	221	$	547	$	(281	)	$	266

															2018 Nine Months							2017 Nine Months
															Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues															$	2,417	$	—		$	2,417	$	2,350	$	—		$	2,350
Operating Expenses
Fuel															609		—			609		576		—			576
Energy purchases															135		—			135		120		—			120
Other operation and maintenance															74		558			632		82		512			594
Depreciation															52		302			354		48		276			324
Taxes, other than income															3		50			53		4		45			49
Total Operating Expenses															873		910			1,783		830		833			1,663
Total															$	1,544	$	(910	)	$	634	$	1,520	$	(833	)	$	687


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.

Table of Contents

LG&E: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the periods ended September 30 includes the following results.


	Three Months									Nine Months									Three Months									Nine Months
	2017			2016			$ Change			2017			2016			$ Change			2018			2017			$ Change			2018			2017			$ Change
Operating Revenues
Retail and wholesale	$	361		$	366		$	(5	)	$	1,055		$	1,058		$	(3	)	$	357		$	361		$	(4	)	$	1,095		$	1,055		$	40
Electric revenue from affiliate	2			2			—			23			19			4			5			2			3			21			23			(2		)
Total Operating Revenues	363			368			(5		)	1,078			1,077			1			362			363			(1		)	1,116			1,078			38
Operating Expenses
Operation
Fuel	76			86			(10		)	225			233			(8		)	83			76			7			234			225			9
Energy purchases	18			19			(1		)	107			104			3			17			18			(1		)	121			107			14
Energy purchases from affiliate	3			5			(2		)	8			10			(2		)	2			3			(1		)	10			8			2
Other operation and maintenance	89			85			4			262			264			(2		)	95			87			8			277			258			19
Depreciation	47			43			4			136			126			10			49			47			2			146			136			10
Taxes, other than income	8			9			(1		)	25			24			1			9			8			1			27			25			2
Total Operating Expenses	241			247			(6		)	763			761			2			255			239			16			815			759			56
Other Income (Expense) - net	(1		)	(1		)	—			(2		)	(6		)	4			(3		)	(3		)	—			(5		)	(6		)	1
Interest Expense	17			18			(1		)	53			53			—			20			17			3			57			53			4
Income Taxes	39			39			—			99			98			1			18			39			(21		)	51			99			(48		)
Net Income	$	65		$	63		$	2		$	161		$	159		$	2		$	66		$	65		$	1		$	188		$	161		$	27

~~Table of Contents~~

Operating Revenues

The increase (decrease) in operating revenues for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Volumes (a)							$	14		$	58
Base rates	$	18		$	18		—			32
Volumes	(16		)	(26		)
ECR							1			8
TCJA refund (b)							(14		)	(51		)
Fuel and other energy prices	(4		)	4			(3		)	(13		)
DSM							(1		)	(6		)
Other	(3		)	5			2			10
Total	$	(5	)	$	1		$	(1	)	$	38


(a)	Increases were primarily due to favorable weather in 2018.


(b)	Represents estimated income tax savings owed to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 7 to the Financial Statements for additional information.

Fuel

Fuel ~~decreased~~ ~~$10~~increased $7 million for the three months ended September 30, ~~2017~~2018 compared with ~~2016~~2017, primarily due to an $8 million increase in volumes driven by weather in 2018.

Table of Contents

Energy Purchases

Energy purchases increased $14 million for the nine months ended September 30, 2018 compared with 2017, primarily due to an $18 million increase in natural gas volumes driven by weather in 2018, partially offset by a $6 million decrease in market prices for ~~coal and a $5 million decrease in volumes driven by milder weather in the third quarter of 2017.~~natural gas.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months		Nine Months			Three Months		Nine Months
Plant operations and maintenance	$	1	$	(1	)
Pension expense	1		1
Storm costs						$	4	$	6
Gas distribution maintenance and compliance						1		4
Timing and scope of generation maintenance outages	—		(1		)	—		2
Storm costs	—		(1		)
Other	2		—			3		7
Total	$	4	$	(2	)	$	8	$	19

Depreciation

Depreciation increased $4$10 million for the ~~three~~nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017, due to a $2$6 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.

Income Taxes

The increase (decrease) in income taxes for the periods ended September 30, 2018 compared with 2017 ~~and a $2 million increase related to additions to PP&E, net of retirements.~~was due to:



	Three Months			Nine Months
Reduction in U.S. federal income tax rate (a)	$	(12	)	$	(33	)
Change in pre-tax income	(8		)	(8		)
Amortization of excess deferred income taxes (a)	(1		)	(6		)
Other	—			(1		)
Total	$	(21	)	$	(48	)


(a)	The decreases are related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

Earnings


	Three Months Ended				Nine Months Ended				Three Months Ended				Nine Months Ended
	September 30,				September 30,				September 30,				September 30,
	2017		2016		2017		2016		2018		2017		2018		2017
Net Income	$	65	$	63	$	161	$	159	$	66	$	65	$	188	$	161
Special items, gains (losses), after-tax (a)	—		—		—		—		—		—		—		—


(a)	There are no items management considers special for the periods presented.

~~Earnings increased for the three month period in 2017 compared with 2016, primarily due to higher base rates effective July 1, 2017, partially offset by lower sales volumes driven by milder weather.~~

Earnings increased for the nine month period in ~~2017~~2018 compared with ~~2016,~~2017, primarily due to higher sales volumes driven by favorable weather, higher base electricity and gas rates effective July 1, 2017 and ~~lower~~returns on additional environmental capital investments, partially offset by higher other operation and maintenance expense ~~partially offset by lower sales volumes driven by milder weather.~~and higher depreciation expense.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Adjusted Gross Margins on a separate line and not in their respective Statement of Income line items.

Table of Contents


	Three Months			Nine Months			Three Months			Nine Months
Margins	$	8		$	2
Adjusted Gross Margins							$	(5	)	$	19
Other operation and maintenance	(4		)	3			(11		)	(23		)
Depreciation	(5		)	(6		)	(1		)	(11		)
Taxes, other than income	2			—			—			(3		)
Other Income (Expense) - net	—			4			—			1
Interest Expense	1			—			(3		)	(4		)
Income Taxes	—			(1		)	21			48
Net Income	$	2		$	2		$	1		$	27

Adjusted Gross Margins

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, LG&E's Adjusted Gross Margins are included in "Kentucky Adjusted Gross Margins."


	2017 Three Months							2016 Three Months							2018 Three Months							2017 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	363	$	—		$	363	$	368	$	—		$	368	$	362	$	—		$	362	$	363	$	—		$	363
Operating Expenses
Fuel	76		—			76		86		—			86		83		—			83		76		—			76
Energy purchases, including affiliate	21		—			21		24		—			24		19		—			19		21		—			21
Other operation and maintenance	13		76			89		13		72			85		10		85			95		13		74			87
Depreciation	7		40			47		8		35			43		8		41			49		7		40			47
Taxes, other than income	1		7			8		—		9			9		2		7			9		1		7			8
Total Operating Expenses	118		123			241		131		116			247		122		133			255		118		121			239
Total	$	245	$	(123	)	$	122	$	237	$	(116	)	$	121	$	240	$	(133	)	$	107	$	245	$	(121	)	$	124

	2017 Nine Months							2016 Nine Months							2018 Nine Months							2017 Nine Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,078	$	—		$	1,078	$	1,077	$	—		$	1,077	$	1,116	$	—		$	1,116	$	1,078	$	—		$	1,078
Operating Expenses
Fuel	225		—			225		233		—			233		234		—			234		225		—			225
Energy purchases, including affiliate	115		—			115		114		—			114		131		—			131		115		—			115
Other operation and maintenance	33		229			262		32		232			264		29		248			277		33		225			258
Depreciation	24		112			136		20		106			126		23		123			146		24		112			136
Taxes, other than income	3		22			25		2		22			24		2		25			27		3		22			25
Total Operating Expenses	400		363			763		401		360			761		419		396			815		400		359			759
Total	$	678	$	(363	)	$	315	$	676	$	(360	)	$	316	$	697	$	(396	)	$	301	$	678	$	(359	)	$	319


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.

Table of Contents

KU: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the periods ended September 30 includes the following results.


	Three Months								Nine Months									Three Months							Nine Months
	2017		2016			$ Change			2017			2016			$ Change			2018		2017		$ Change			2018		2017			$ Change
Operating Revenues
Retail and wholesale	$	457	$	469		$	(12	)	$	1,295		$	1,324		$	(29	)	$	445	$	457	$	(12	)	$	1,322	$	1,295		$	27
Electric revenue from affiliate	3		5			(2		)	8			10			(2		)	2		3		(1		)	10		8			2
Total Operating Revenues	460		474			(14		)	1,303			1,334			(31		)	447		460		(13		)	1,332		1,303			29
Operating Expenses
Operation
Fuel	126		141			(15		)	351			374			(23		)	123		126		(3		)	375		351			24
Energy purchases	4		5			(1		)	13			14			(1		)	5		4		1			14		13			1
Energy purchases from affiliate	2		2			—			23			19			4			5		2		3			21		23			(2		)
Other operation and maintenance	104		107			(3		)	313			320			(7		)	114		104		10			331		312			19
Depreciation	67		59			8			188			175			13			70		67		3			208		188			20
Taxes, other than income	9		7			2			24			22			2			9		9		—			26		24			2
Total Operating Expenses	312		321			(9		)	912			924			(12		)	326		312		14			975		911			64
Other Income (Expense) - net	—		(3		)	3			(3		)	(4		)	1			1		—		1			1		(4		)	5
Interest Expense	24		24			—			72			71			1			24		24		—			74		72			2
Income Taxes	47		48			(1		)	120			128			(8		)	21		47		(26		)	59		120			(61		)
Net Income	$	77	$	78		$	(1	)	$	196		$	207		$	(11	)	$	77	$	77	$	—		$	225	$	196		$	29

Operating ~~Revenue~~Revenues

The increase (decrease) in operating ~~revenue~~revenues for the periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due to:


	Three Months			Nine Months			Three Months			Nine Months
Volumes (a)							$	8		$	64
Base rates	$	13		$	13		—			26
Volumes	(27		)	(57		)
ECR							4			10
TCJA refund (b)							(16		)	(58		)
DSM							(1		)	(7		)
Fuel and other energy prices	(3		)	5			(4		)	(2		)
Other	3			8			(4		)	(4		)
Total	$	(14	)	$	(31	)	$	(13	)	$	29


(a)	Increases were primarily due to favorable weather in 2018.


(b)	Represents estimated income tax savings owed to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 7 to the Financial Statements for additional information.

Fuel

Fuel decreased $15 million for the three months ended September 30, 2017 compared with 2016, primarily due to an $11 million decrease in volumes driven by milder weather in the third quarter of 2017 and a $3 million decrease in market prices for coal.

~~Fuel decreased $23~~increased $24 million for the nine months ended September 30, ~~2017~~2018 compared with ~~2016,~~2017, primarily due to a ~~$29~~$30 million ~~decrease~~increase in volumes driven by ~~milder~~ weather in ~~2017.~~2018, partially offset by a $6 million decrease in commodity costs.

Table of Contents

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance for the periods ended September 30, 2018 compared with 2017 was due to:



	Three Months		Nine Months
Timing and scope of generation maintenance outages	$	—	$	6
Vegetation management	1		5
Storm costs	5		4
Other	4		4
Total	$	10	$	19

Depreciation

Depreciation increased $8$20 million for the ~~three~~nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017, primarily due to ~~a $5~~an $11 million increase related to higher depreciation rates effective July 1, 2017 and a $3$6 million increase related to ~~additions to PP&E,~~additional assets placed into service, net of retirements.

~~Depreciation increased $13 million~~Income Taxes

The increase (decrease) in income taxes for the ~~nine months~~periods ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was due ~~to an $8 million increase related to additions to PP&E, net of retirements, and a $5 million increase related to higher depreciation rates effective July 1, 2017.~~to:



	Three Months			Nine Months
Reduction in U.S. federal income tax rate (a)	$	(14	)	$	(40	)
Change in pre-tax income	(10		)	(12		)
Amortization of excess deferred income taxes (a)	(2		)	(8		)
Other	—			(1		)
Total	$	(26	)	$	(61	)


(a)	The decreases are related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

Earnings


	Three Months Ended				Nine Months Ended					Three Months Ended				Nine Months Ended
	September 30,				September 30,					September 30,				September 30,
	2017		2016		2017			2016		2018		2017		2018		2017
Net Income	$	77	$	78	$	196		$	207	$	77	$	77	$	225	$	196
Special items, gains (losses), after-tax	—		—		(1		)	—		—		—		—		(1		)

Earnings decreased for the three month period in 2017 compared with 2016, primarily due to lower electricity sales volumes driven by milder weather and higher depreciation expense, partially offset by higher base rates effective July 1, 2017.

~~Earnings decreased~~increased for the nine month period in ~~2017~~2018 compared with ~~2016,~~2017, primarily due to ~~lower electricity~~higher sales volumes driven by ~~milder~~favorable weather, ~~and higher depreciation expense, partially offset by~~ higher base electricity rates effective July 1, 2017 and ~~lower~~returns on environmental capital investments, partially offset by higher other operation and maintenance expense and higher depreciation expense.


	Three Months			Nine Months			Three Months			Nine Months
Margins	$	2		$	(15	)
Adjusted Gross Margins							$	(14	)	$	5
Other operation and maintenance	—			7			(11		)	(23		)
Depreciation	(5		)	(9		)	(2		)	(15		)
Taxes, other than income	(2		)	(2		)	—			(2		)
Other Income (Expense) - net	3			2			1			4
Interest Expense	—			(1		)	—			(2		)
Income Taxes	1			8			26			61
Special items, gains (losses), after-tax (a)	—			(1		)	—			1
Net Income	$	(1	)	$	(11	)	$	—		$	29

Table of Contents


(a)	See PPL's "Results of Operations - Segment Earnings - Kentucky Regulated Segment" for details of the special item.

Adjusted Gross Margins

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, KU's Adjusted Gross Margins are included in "Kentucky Adjusted Gross Margins."

~~Table of Contents~~


	2017 Three Months							2016 Three Months							2018 Three Months							2017 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	460	$	—		$	460	$	474	$	—		$	474	$	447	$	—		$	447	$	460	$	—		$	460
Operating Expenses
Fuel	126		—			126		141		—			141		123		—			123		126		—			126
Energy purchases, including affiliate	6		—			6		7		—			7		10		—			10		6		—			6
Other operation and maintenance	17		87			104		20		87			107		16		98			114		17		87			104
Depreciation	9		58			67		6		53			59		10		60			70		9		58			67
Taxes, other than income	—		9			9		—		7			7		—		9			9		—		9			9
Total Operating Expenses	158		154			312		174		147			321		159		167			326		158		154			312
Total	$	302	$	(154	)	$	148	$	300	$	(147	)	$	153	$	288	$	(167	)	$	121	$	302	$	(154	)	$	148

	2017 Nine Months							2016 Nine Months							2018 Nine Months							2017 Nine Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,303	$	—		$	1,303	$	1,334	$	—		$	1,334	$	1,332	$	—		$	1,332	$	1,303	$	—		$	1,303
Operating Expenses
Fuel	351		—			351		374		—			374		375		—			375		351		—			351
Energy purchases, including affiliate	36		—			36		33		—			33		35		—			35		36		—			36
Other operation and maintenance	49		264			313		49		271			320		45		286			331		49		263			312
Depreciation	24		164			188		20		155			175		29		179			208		24		164			188
Taxes, other than income	1		23			24		1		21			22		1		25			26		1		23			24
Total Operating Expenses	461		451			912		477		447			924		485		490			975		461		450			911
Total	$	842	$	(451	)	$	391	$	857	$	(447	)	$	410	$	847	$	(490	)	$	357	$	842	$	(450	)	$	392


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.

Table of Contents

Financial Condition

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

Liquidity and Capital Resources

(All Registrants)

The Registrants had the following at:

PPL (a) PPL Electric LKE LG&E KU
September 30, 2017
Cash and cash equivalents $ 676
$ 243
$ 40
$ 9
$ 31
Notes receivable from affiliate 2
—
—
10
Short-term debt 1,211
—
190
190
—
Notes payable with affiliate —
159
10
—

December 31, 2016
Cash and cash equivalents $ 341
$ 13
$ 13
$ 5
$ 7
Short-term debt 923
295
185
169
16
Notes payable with affiliate —
163
—
—



	PPL (a)		PPL Electric		LKE		LG&E		KU
September 30, 2018
Cash and cash equivalents	$	842	$	414	$	29	$	11	$	18
Short-term debt	1,549		—		304		176		128
Long-term debt due within one year	330		—		330		234		96
Notes payable with affiliates			—		80		—		—

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		—		—

(a)

At September 30, ~~2017, $86~~2018, $57 million of cash and cash equivalents were denominated in GBP. If these amounts would be remitted as dividends, PPL would not anticipate ~~a material~~an incremental U.S. tax cost. ~~Historically, dividends paid by foreign subsidiaries have been limited to distributions of the current year's earnings.~~ See Note 5 to the Financial Statements in PPL's ~~2016~~2017 Form 10-K for additional information on undistributed earnings of WPD.

~~Table of Contents~~

Net cash provided by (used in) operating, investing and financing activities for the nine month periods ended September 30, and the changes between periods, were as follows.


	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
2017
2018
Operating activities	$	1,754		$	575		$	920		$	418		$	501		$	2,210		$	650		$	787		$	410		$	485
Investing activities	(2,164		)	(858		)	(575		)	(293		)	(289		)	(2,466		)	(837		)	(825		)	(420		)	(404		)
Financing activities	738			513			(318		)	(121		)	(188		)	618			552			37			6			(78		)
2016
2017
Operating activities	$	2,230		$	595		$	816		$	383		$	469		$	1,754		$	575		$	920		$	418		$	501
Investing activities	(2,066		)	(740		)	(599		)	(343		)	(254		)	(2,168		)	(858		)	(575		)	(293		)	(289		)
Financing activities	(558		)	134			(236		)	(55		)	(219		)	738			513			(318		)	(121		)	(188		)
Change - Cash Provided (Used)
Operating activities	$	(476	)	$	(20	)	$	104		$	35		$	32		$	456		$	75		$	(133	)	$	(8	)	$	(16	)
Investing activities	(98		)	(118		)	24			50			(35		)	(298		)	21			(250		)	(127		)	(115		)
Financing activities	1,296			379			(82		)	(66		)	31			(120		)	39			355			127			110

Operating Activities

The components of the change in cash provided by (used in) operating activities for the nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017 were as follows.

Table of Contents

PPL PPL Electric LKE LG&E KU
Change - Cash Provided (Used)
Net income $ (387 ) $ (12 ) $ (15 ) $ 2
$ (11 )
Non-cash components (23 ) 34
(18 ) (11 ) 4
Working capital 91
(3 ) 78
(9 ) 31
Defined benefit plan funding (213 ) (24 ) 50
42
(3 )
Other operating activities 56
(15 ) 9
11
11
Total $ (476 ) $ (20 ) $ 104
$ 35
$ 32



	PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Net income	$	362		$	83		$	36		$	27		$	29
Non-cash components	(386		)	(39		)	(88		)	(44		)	(69		)
Working capital	134			13			49			78			76
Defined benefit plan funding	274			(4		)	(94		)	(56		)	(31		)
Other operating activities	72			22			(36		)	(13		)	(21		)
Total	$	456		$	75		$	(133	)	$	(8	)	$	(16	)

(PPL)

PPL's cash provided by operating activities in ~~2017 decreased $476~~2018 increased $456 million compared with ~~2016.~~2017.

~~The $27~~Net income increased $362 million between periods and included a decrease in non-cash ~~components~~charges of $386 million. The decrease in non-cash charges was primarily due to ~~a decrease~~an increase in ~~deferred income tax expense (primarily due to lower income taxes from tax benefits related to accelerated pension contributions to the U.K. pension plans)~~unrealized gains on hedging activities and an increase in the U.K. net periodic defined benefit credits (primarily due to ~~a decrease~~an increase in ~~the U.K. pension plan discount rates used to calculate the interest cost component of the net periodic defined benefit costs),~~expected returns on higher asset balances) partially offset by ~~an increase in unrealized losses on hedging activities and~~ an increase in depreciation expense (primarily due to additional assets placed into service, net of retirements, related to the ongoing efforts to ensure the reliability of the delivery system, the replacement of aging infrastructure, the roll-out of the Act 129 Smart Meter program and higher depreciation rates effective July 1, ~~2017, partially offset by the impact of foreign currency exchange rates at WPD)~~2017).

The ~~$91~~$134 million increase in cash from changes in working capital was primarily due to a decrease in unbilled revenue (primarily due to colder weather in the fourth quarter of 2017), a decrease in net regulatory assets and liabilities (primarily due to an increase in regulatory liabilities due to the impact of the TCJA and timing of rate recovery mechanisms) and an increase in accounts payable (primarily due to timing of payments).

Defined benefit plan funding was $274 million lower in 2018. The decrease was primarily due to the acceleration of WPD's contributions to its U.K. pension plans in 2017.

(PPL Electric)

PPL Electric's cash provided by operating activities in 2018 increased $75 million compared with 2017.

Net income increased $83 million between the periods and included a decrease in non-cash charges of $39 million. The decrease in non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and net operating losses) partially offset by an increase in depreciation expense (primarily due to additional assets placed into service, net of retirements, related to the ongoing efforts to ensure the reliability of the delivery system, the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program).

The $13 million increase in cash from changes in working capital was primarily due to a decrease in accounts receivable (which was primarily due to tax proceeds from the filing of the 2017 federal income tax return), a decrease in unbilled revenues (primarily due to colder weather in the fourth quarter of 2017) and ~~unbilled revenue~~a decrease in materials and supplies within Other (primarily due to inventory optimization efforts) partially offset by an increase in net regulatory assets and liabilities (primarily due to a decrease in ~~volumes due to milder weather~~the transmission service charge regulatory liability as a result of the June 1, 2018 Transmission Formula Rate filing, an increase in 2017 compared to 2016), a decrease in net regulatory assets and liabilities (due to timing of rate recovery mechanisms), a decrease in fuel, material and supplies (primarily due to a decrease in fuel purchases due to milder weather in 2017 compared to 2016),recoverable storm costs and an increase in accrued interest, partially offset by a decrease in accounts payable (primarily due to an increase in accrued expenditures for property, plant and equipment and timing of payments) and a decrease in taxes payable (primarily due to an increase in current income tax benefit in 2017).

~~Defined benefit plan funding was $213 million higher in 2017. The increase was primarily due~~recoverable costs related to the ~~acceleration of WPD's contributions to its U.K. pension plans. See Note 8 to the Financial Statements for additional information.~~

~~(PPL Electric)~~

~~PPL Electric's cash provided by operating activities in 2017 decreased $20 million compared with 2016.~~

~~Table of Contents~~

Act 129 Smart Meter program).

The ~~$34~~$22 million increase in ~~non-cash components~~cash provided by other operating activities was primarily due to an increase in ~~depreciation expense~~non-current regulatory liabilities (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),~~TCJA regulatory liability) partially offset by ~~a decrease~~an increase in ~~deferred income taxes~~non-current regulatory assets (primarily due to ~~book versus tax plant timing differences)~~recoverable storm costs).

The $3 million decrease in cash from changes in working capital was primarily due to an increase in prepayments (primarily due to an increase in the 2017 gross receipts tax prepayment compared to 2016) and a decrease in accounts payable (primarily due to timing of payments), partially offset by a decrease in net regulatory assets and liabilities (due to timing of rate recovery mechanisms), a decrease in unbilled revenue (primarily due to lower volumes due to milder weather in 2017 compared to 2016), an increase in taxes payable (primarily due to a decrease in the current income tax benefit) and a decrease in accounts receivable (primarily due to a decrease in volumes due to milder weather in 2017 and income tax refunds received).

~~Defined benefit plan funding was $24 million higher in 2017.~~

(LKE)

LKE's cash provided by operating activities in ~~2017 increased $104~~2018 decreased $133 million compared with ~~2016.~~2017.

Net income increased $36 million between the periods and included a decrease in non-cash charges of $88 million. The ~~increase~~decrease in ~~cash from changes in working capital~~non-cash charges was primarily driven by ~~decreases in accounts receivable from customers and unbilled revenues due to milder weather in 2017 compared to 2016,~~ a decrease in ~~fuel purchases~~deferred income tax expense (primarily due to ~~lower generation driven by weather in 2017 compared to 2016,~~book versus tax plant timing differences and ~~an increase in taxes payable due to timing~~the impacts of ~~payments,~~federal and state tax reform), partially offset by ~~a decrease in accounts payable due to the timing of fuel purchases and payments.~~an increase

~~Defined benefit plan funding was~~ ~~$50 million~~ ~~lower in 2017.~~Table of Contents

~~(LG&E)~~

~~LG&E's cash provided by operating activities~~ in ~~2017 increased $35 million compared with 2016.~~

~~The decrease in cash from changes in working capital was primarily driven by decreases in accounts payable~~depreciation expense (primarily due to ~~fuel purchases from lower generation~~higher depreciation rates effective July 1, 2017 and ~~timing~~additional assets placed into service, net of payments and taxes payable due to timing of payments, partially offset by decreases in accounts receivable from customers and unbilled revenues due to milder weather in 2017 compared to 2016 and accounts receivable from affiliates due to timing of intercompany settlements associated with inventory and energy sales to KU.retirements).

~~Defined benefit plan funding was~~ ~~$42 million~~ ~~lower in 2017.~~

~~(KU)~~

~~KU's cash provided by operating activities in 2017 increased $32 million compared with 2016.~~

The increase in cash from changes in working capital was primarily driven by a decrease in ~~accounts receivable from customers and unbilled revenues~~other current liabilities (primarily due to ~~milder weather in 2017 compared to 2016,~~timing of payments), a decrease in ~~fuel purchases~~net regulatory assets and liabilities (primarily due to ~~lower generation driven by weather in 2017 compared to 2016,~~the impact of the TCJA and timing of rate recovery mechanisms), an increase in accounts payable (primarily due to ~~the~~ timing of ~~fuel purchases~~payments) and ~~payments,~~a decrease in unbilled revenues (primarily due to colder weather in the fourth quarter of 2017), partially offset by a decrease in taxes payable (primarily due to timing of ~~payments~~payments), and ~~accounts payable to affiliates~~an increase in fuel inventory (primarily due to timing of ~~intercompany settlements associated with inventory~~fuel purchases and ~~energy purchases from LG&E.~~payments).

Defined benefit plan funding was $94 million higher in 2018.

The decrease in cash from LKE's other operating activities was primarily driven by an increase in ARO expenditures.

(LG&E)

LG&E's cash provided by operating activities in 2018 decreased $8 million compared with 2017.

Net income increased $27 million between the periods and included a decrease in non-cash charges of $44 million. The decrease in non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and the impacts of federal and state tax reform), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements).

The increase in cash from changes in working capital was primarily driven by an increase in accounts payable (primarily due to timing of payments), a decrease in net regulatory assets and liabilities (primarily due to the impact of the TCJA and the timing of rate recovery mechanisms), an increase in taxes payable (primarily due to timing of payments) and a decrease in unbilled revenues (primarily due to colder weather in the fourth quarter of 2017), partially offset by a decrease in other current liabilities (primarily due to timing of payments).

Defined benefit plan funding was $56 million higher in 2018.

(KU)

KU's cash provided by operating activities in 2018 decreased $16 million compared with 2017.

Net income increased $29 million between the periods and included a decrease in non-cash charges of $69 million. The decrease in non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and the impacts of federal and state tax reform), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements).

The increase in cash from changes in working capital was primarily driven by a decrease in net regulatory assets and liabilities (primarily due to the impact of the TCJA and the timing of rate recovery mechanisms), an increase in taxes payable (primarily due to timing of payments), a decrease in unbilled revenues (primarily due to colder weather in the fourth quarter of 2017), partially offset by an increase in fuel inventory (primarily due to timing of fuel purchases and payments).

Defined benefit plan funding was $31 million higher in 2018.

The decrease in cash from KU's other operating activities was primarily driven by an increase in ARO expenditures.

Investing Activities

(All Registrants)

Expenditures for Property, Plant and Equipment

Investment in PP&E is the primary investing activity of the Registrants. The change in cash used in expenditures for PP&E for the nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017 was as follows.

PPL PPL Electric LKE LG&E KU
Decrease (Increase) $ (79 ) $ (112 ) $ 21
$ 50
$ (28 )

Table of Contents



	PPL			PPL Electric		LKE			LG&E			KU
Decrease (Increase)	$	(192	)	$	16	$	(247	)	$	(127	)	$	(122	)

For PPL, the increase in expenditures was due to higher project expenditures at ~~PPL Electric~~LKE, LG&E and KU partially offset by lower project expenditures at WPD and ~~LG&E.~~PPL Electric. The increase in expenditures for 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 decrease in expenditures for WPD was primarily due to a decrease in foreign currency exchange rates partially offset by an increase in expenditures to enhance system reliability. The decrease in expenditures forLKE, LG&E was primarily due to reduced spending for environmental air projects at LG&E's Mill Creek plant, partially offset by increased spending for environmental water projects at LG&E’s Mill Creek plant. The increase in expenditures forand KU was primarily due to increased spending for environmental water projects at ~~KU’s~~LG&E's Mill Creek and Trimble County plants and increased spending for environmental water projects at KU's Ghent plant. The decrease in expenditures at WPD was primarily due to a decrease in expenditures to enhance system reliability partially offset by an increase in foreign currency exchange rates. The decrease in expenditures for PPL Electric was primarily due to timing differences on capital spending projects related to the ongoing efforts to improve reliability and replace aging infrastructure.

Financing Activities

(All Registrants)

The components of the change in cash provided by (used in) financing activities for the nine months ended September 30, ~~2017~~2018 compared with ~~2016~~2017 were as follows.


	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	692		$	470		$	—		$	—		$	—		$	(703	)	$	(72	)	$	91		$	100		$	(9	)
Settlement of cross-currency swaps	(46		)	—			—			—			—
Debt issuance/retirement with affiliate, net																			—			250			—			—
Stock issuances/redemptions, net	142			—			—			—			—			403			—			—			—			—
Dividends	(28		)	(38		)	—			(63		)	26			(46		)	(40		)	—			37			(25		)
Capital contributions/distributions, net	—			375			(129		)	(47		)	(20		)				(146		)	99			43			45
Change in short-term debt, net	537			(425		)	135			35			25			212			295			55			(44		)	99
Notes payable with affiliate	—			—			(88		)	10			—						—			(141		)	(10		)	—
Other financing activities	(1		)	(3		)	—			(1		)	—			14			2			1			1			—
Total	$	1,296		$	379		$	(82	)	$	(66	)	$	31		$	(120	)	$	39		$	355		$	127		$	110

See Note 78 to the Financial Statements in this Form 10-Q for information on ~~2017~~2018 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 7 to the Financial Statements in the Registrants' ~~2016~~2017 Form 10-K for information on ~~2016~~2017 activity.

Credit Facilities

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. Amounts borrowed under these credit facilities are reflected in "Short-term debt" on the Balance Sheets except for borrowings under LG&E's term loan agreement which are reflected in "Long-term debt" on the Balance Sheets. At September 30, ~~2017,~~2018, the total committed borrowing capacity under credit facilities and the ~~use of that capacity~~borrowings under these ~~credit~~ facilities ~~was as follows:~~

~~External~~

Committed
Capacity
Borrowed
Letters of
Credit
and
Commercial
Paper Issued

Unused
Capacity
PPL Capital Funding Credit Facilities $ 1,400
$ —
$ 303
$ 1,097
PPL Electric Credit Facility 650
—
1
649

LKE Credit Facility 75
—
—
75
LG&E Credit Facility 500
—
190
310
KU Credit Facilities 598
—
198
400
Total LKE 1,173
—
388
785
Total U.S. Credit Facilities (a) $ 3,223
$ —
$ 692
$ 2,531
Total U.K. Credit Facilities (b) £ 1,285
£ 501
£ —
£ 783
were:

Table of Contents

External



	Committed Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity
PPL Capital Funding Credit Facilities	$	1,350	$	—	$	711	$	639
PPL Electric Credit Facility	650		—		1		649

LKE Credit Facility	75		—		—		75
LG&E Credit Facility	700		200		176		324
KU Credit Facilities	598		—		326		272
Total LKE	1,373		200		502		671
Total U.S. Credit Facilities (a)	$	3,373	$	200	$	1,214	$	1,959
Total U.K. Credit Facilities (b)	£	1,185	£	427	£	—	£	756


(a)	The commitments under the U.S. 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%, PPL Electric - 7%, LKE - ~~21%~~18%, LG&E - 7%33% and KU - 37%.

(b)

The amounts borrowed at September 30, ~~2017~~2018 were a USD-denominated borrowing of $200 million and GBP-denominated borrowings which equated to ~~$446~~$354 million. The unused capacity reflects the USD-denominated borrowing amount borrowed in GBP of £156 million as of the date borrowed. At September 30, ~~2017,~~2018, the USD equivalent of unused capacity under the U.K. committed credit facilities was $1.0 billion.

The commitments under the U.K. credit facilities are provided by a diverse bank group, with no one bank providing more than ~~20%~~17% of the total committed capacity.

See Note 78 to the Financial Statements for further discussion of the Registrants' credit facilities.

Intercompany (LKE, LG&E and KU)


	Committed Capacity		Borrowed		Other Used Capacity		Unused Capacity		Committed Capacity		Borrowed		Non-affiliate Used Capacity		Unused Capacity
LKE Credit Facility	$	225	$	159	$	—	$	66	$	300	$	80	$	—	$	220
LG&E Money Pool (a)	500		10		190		300		500		—		176		324
KU Money Pool (a)	500		—		—		500		500		—		128		372


(a)	LG&E and KU participate in an intercompany money pool agreement whereby LKE, LG&E and/or KU make available funds up to $500 million at an interest rate based on a market index of commercial paper issues. However, the FERC has issued a maximum aggregate short-term debt limit for each utility at $500 million from all covered sources.

See Note 1011 to the Financial Statements for further discussion of intercompany credit facilities.

Commercial Paper (All Registrants)


	Capacity		Commercial Paper Issuances		Unused Capacity		Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding	$	1,000	$	285	$	715	$	1,000	$	691	$	309
PPL Electric	650		—		650		650		—		650

LG&E	350		190		160		350		176		174
KU	350		—		350		350		128		222
Total LKE	700		190		510		700		304		396
Total PPL	$	2,350	$	475	$	1,875	$	2,350	$	995	$	1,355

Table of Contents

Long-term Debt (All Registrants)

See Note 78 to the Financial Statements for information regarding the Registrants’ long-term debt activities.

(PPL)

Equity Securities Activities

Equity Forward Contracts

In May 2018, PPL completed a registered underwritten public offering of 55 million shares of its common stock. In connection with that offering, the underwriters exercised an option to purchase 8.25 million additional shares of PPL common stock solely to cover over-allotments.

In September 2018, PPL settled a portion of the initial forward sale agreements by issuing 20 million shares of PPL common stock, resulting in net cash proceeds of $520 million.

See Note 8 to the Financial Statements for additional information.

ATM Program

For the ~~periods~~nine months ended September 30, ~~2017,~~2018, PPL issued ~~the following:~~

Three Months Nine Months
Number of shares (in thousands) 2,049
5,526
Average share price $ 39.04
$ 38.49
Net Proceeds $ 79
$ 211

~~Table~~4.2 million shares of ~~Contents~~

common stock and received proceeds of $119 million. See Note 78 to the Financial Statements for further discussion of the ATM program.

Common Stock Dividends (PPL)

Rating Agency Actions

(All Registrants)

Moody's and S&P have periodically reviewed 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 rating agencies have taken the following actions related to the Registrants and their subsidiaries during ~~2017:~~2018:

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(PPL)

In March ~~2017,~~2018, Moody's and S&P assigned ratings of Baa1 and A- to WPD (South Wales)~~’s £50~~'s £30 million 0.01% Index-linked Senior Notes due ~~2029.~~2036.

In ~~September 2017,~~May 2018, Moody's and S&P assigned ratings of ~~Baa2~~Baa1 and A- to WPD (West Midlands)'s £30 million 0.01% Index-linked Senior Notes due 2028.

In October 2018, Moody's and S&P assigned ratings of Baa3 and BBB+ to ~~PPL Capital Funding’s $500~~WPD plc's £350 million ~~4.00%~~3.5% Senior Notes due ~~2047.~~2026.

(PPL and PPL Electric)

In ~~January 2017, Moody's and S&P affirmed their commercial paper ratings for PPL Electric's $650 million commercial paper program.~~

~~In May 2017,~~June 2018, Moody's and S&P assigned ratings of A1 and A to PPL Electric's ~~$475~~$400 million ~~3.95%~~4.15% First Mortgage Bonds due ~~2047.~~2048.

(PPL, LKE and LG&E)

In ~~August 2017,~~February 2018, Moody’s assigned a rating of A1 and S&P confirmed its rating of A to the County of Trimble, Kentucky's $28 million 2.30% Pollution Control Revenue Bonds, 2001 Series A (Louisville Gas and Electric Company Project) due 2026, previously issued on behalf of LG&E.

In April 2018, Moody's assigned a rating of A1 and S&P confirmed its rating of A ~~for LCIDA's $116~~to the County of Trimble, Kentucky's $35 million ~~1.80%~~2.55% Pollution Control Revenue ~~Refunding~~ Bonds, ~~(PPL~~2001 Series B (Louisville Gas and Electric ~~Utilities Corporation~~Company 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.~~

~~(PPL, LKE and~~ LG~~&E)~~&E.

In ~~March 2017, Moody’s~~April 2018, Moody's assigned a rating of A1 and S&P confirmed its rating of A ~~for~~to the ~~Louisville/~~County of Jefferson, ~~Metro Government of~~ Kentucky's ~~$128~~$35 million ~~1.5%~~2.55% Pollution Control Revenue Bonds, ~~2003 Series A (Louisville Gas and Electric Company Project) due 2033, previously issued on behalf of LG&E.~~

In May 2017, Moody’s and S&P assigned ratings of A1 and A to the County of Trimble, Kentucky's $60 million 3.75% Environmental Facilities Revenue Bonds, 2017 Series A (Louisville Gas and Electric Company Project) due 2033, issued on behalf of LG&E.

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In May 2017, Moody’s assigned a rating of A1 and in June 2017, S&P confirmed its rating of A for the Louisville/Jefferson Metro Government of Kentucky's $31 million 1.25% Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033, previously issued on behalf of LG&E.

In May 2017, Moody’s assigned a rating 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, 20072001 Series B (Louisville Gas and Electric Company Project) due ~~2033,~~2027, previously issued on behalf of LG&E.

~~(PPL, LKE and KU)~~

In July 2017, Moody’s affirmed its rating of Aa2 and in August 2017, S&P confirmed its rating of AA for the County of Mercer, Kentucky's $13 million Solid Waste Disposal Facility Revenue Bonds, 2000 Series A (Kentucky Utilities Company Project) due 2023, the County of Carroll, Kentucky's $50 million Environmental Facilities Revenue Bonds, 2004 Series A (Kentucky Utilities Company Project) due 2034, the County of Carroll, Kentucky's $78 million Environmental Facilities Revenue Bonds, 2008 Series A (Kentucky Utilities Company Project) due 2032 and the County of Carroll, Kentucky's $54 million Environmental Facilities Revenue Refunding Bonds, 2006 Series B (Kentucky Utilities Company Project) due 2034, each previously issued on behalf of KU.

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, 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 1314 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 September 30, ~~2017.~~2018.

(All Registrants)

For additional information on the Registrants' liquidity and capital resources, see "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Registrants' ~~2016~~2017 Form 10-K.

Risk Management

Market Risk

(All Registrants)

See Notes 1213 and 1314 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

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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

The Registrants and their subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. The Registrants and their subsidiaries utilize various financial derivative instruments to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of their debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under the risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolios due to changes in the absolute level of 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.

~~Table of Contents~~

The following interest rate hedges were outstanding at September 30, ~~2017.~~2018.


	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)			Maturities Ranging Through
PPL
Cash flow hedges
Interest rate swaps (c)	$	242	$	(2	)	$	(3	)	2027	$	97	$	—		$	(1	)	2026
Cross-currency swaps (c)	802		162			(90		)	2028	702		125			(78		)	2028
Economic hedges
Interest rate swaps (d)	147		(29		)	(1		)	2033	147		(19		)	(2		)	2033
LKE
Economic hedges
Interest rate swaps (d)	147		(29		)	(1		)	2033	147		(19		)	(2		)	2033
LG&E
Economic hedges
Interest rate swaps (d)	147		(29		)	(1		)	2033	147		(19		)	(2		)	2033


(a)	Includes accrued interest, if applicable.


(b)	Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability. Sensitivities represent a 10% adverse movement in interest rates, except for cross-currency swaps which also includes a 10% adverse movement in foreign currency exchange rates.


(c)	Changes in the fair value of these instruments are recorded in equity and reclassified into earnings in the same period during which the item being hedged affects earnings.


(d)	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 September 30, ~~2017~~2018 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 September 30, ~~2017~~2018 is shown below.


	10% Adverse Movement in Rates		10% Adverse Movement in Rates
PPL	$	600	$	647
PPL Electric	165		190
LKE	172		176
LG&E	63		63
KU	95		92

Foreign Currency Risk (PPL)

PPL is exposed to foreign currency risk primarily through investments in and earnings of U.K. affiliates. Under its risk management program, PPL may enter into financial instruments to hedge certain foreign currency exposures, including

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translation risk of expected earnings, firm commitments, recognized assets or liabilities, anticipated transactions and net investments.

The following foreign currency hedges were outstanding at September 30, ~~2017.~~2018.

Exposure
Hedged

Fair Value,
Net - Asset
(Liability)

Effect of a
10%
Adverse
Movement
in Foreign
Currency
Exchange
Rates (a)

Maturities
Ranging
Through
Net investment hedges (b) £ 92
$ 1
$ (12 ) 2017
Economic hedges (c) 2,728
(4 ) (340 ) 2020



	Exposure Hedged		Fair Value, Net - Asset (Liability)		Effect of a 10% Adverse Movement in Foreign Currency Exchange Rates (a)			Maturities Ranging Through
Economic hedges (b)	£	1,783	$	144	$	(216	)	2020


(a)	Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability.

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(b)	~~To protect the value of a portion of its net investment in WPD, PPL executes forward contracts to sell GBP.~~


~~(c)~~	To economically hedge the translation risk of expected earnings denominated in GBP.

(All Registrants)

Commodity Price Risk

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

Volumetric Risk

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.

Credit Risk (All Registrants)

See Notes 1213 and 1314 to the Financial Statements in this Form 10-Q and "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Risk Management - Credit Risk" in the Registrants' ~~2016~~2017 Form 10-K for additional information.

Foreign Currency Translation (PPL)

The value of the British pound sterling fluctuates in relation to the U.S. dollar. Changes in this exchange rate resulted in a foreign currency translation loss of $330 million for the nine months ended September 30, 2018, which primarily reflected a $549 million decrease to PP&E and a $110 million decrease to goodwill, partially offset by a $319 million decrease to long-term debt and a $10 decrease to other net liabilities. Changes in this exchange rate resulted in a foreign currency translation gain of $194 million for the nine months ended September 30, 2017, which primarily reflected a $345 million increase to PP&E and a $75 million increase to goodwill partially offset by a $203 million increase to long-term debt and a $23 million increase to other net liabilities. Changes in this exchange rate resulted in a foreign currency translation loss of $840 million for the nine months ended September 30, 2016, which primarily reflected a $1.6 billion decrease to PP&E and $375 million decrease to goodwill partially offset by a $995 million decrease to long-term debt and a $160 million decrease to other net liabilities. The impact of foreign currency translation is recorded in AOCI.

Related Party Transactions (All Registrants)

The Registrants are not aware of any material ownership interests or operating responsibility by senior management in outside partnerships, including leasing transactions with variable interest entities, or other entities doing business with the Registrants.

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See Note 1011 to the Financial Statements for additional information on related party transactions for PPL Electric, LKE, LG&E and KU.

Acquisitions, Development and Divestitures (All Registrants)

The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures and development projects. Development projects are reexamined based on market conditions and other factors to determine whether to proceed with, modify or terminate the projects. Any resulting transactions may impact future financial results. See Note 8 to the Financial Statements in the Registrants' ~~2016~~2017 Form 10-K for information on the more significant activities.

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Environmental Matters

(All Registrants)

Extensive federal, state and local environmental laws and regulations are applicable to PPL's, PPL Electric's, LKE's, LG&E's and KU's air emissions, water discharges and the management of hazardous and solid waste, as well as other aspects of the Registrants' businesses. The cost 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. In addition, the regulatory reviews specified in the President's March 2017 Executive Order promoting energy independence and economic growth could result in future regulatory changes and additional uncertainty. 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 cost for their products or their demand for the Registrants' services. Increased capital and operating costs are subject to rate recovery. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.

See below for further discussion of the EPA's CCR Rule and Note 910 to the Financial Statements for a discussion of ~~the more~~other significant environmental matters ~~including:~~

including Legal Matters,

NAAQS, Climate Change,

~~CCRs,~~

~~ELGs,~~ and

~~NAAQS.~~

ELGs. Additionally, see "Item 1. Business - Environmental Matters" in the Registrants' ~~2016~~2017 Form 10-K for additional information.

EPA’s CCR Rule (PPL, LKE, LG&E and KU)

Over the next several years, LG&E and KU anticipate undertaking extensive measures, including significant capital expenditures, in complying with the provisions of the EPA’s CCR Rule. Although LG&E and KU have identified compliance strategies and are finalizing closure plans and schedules as required by the CCR Rule, remaining regulatory uncertainties could substantially impact current plans. As a result of a judicial settlement, legislative amendments, and the EPA’s review of the current program, the EPA is in the process of undertaking significant revisions to the CCR Rule. On July 30, 2018, the EPA published certain amendments to the CCR Rule which include extending the deadline for commencement of closure of certain impoundments from April 2019 to October 31, 2020. The EPA has announced that additional amendments to the rule will be proposed in late 2018. On August 21, 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule, including the provisions allowing unlined impoundments to continue operating and provisions exempting certain inactive impoundments from regulation. The exact impact of the judicial decision will be highly dependent on the EPA’s rulemaking actions on remand and any subsequent legal challenges. LG&E and KU are evaluating the specific plan impacts of developments to date and will continue to monitor the EPA’s ongoing regulatory proceedings.

In connection with the CCR Rule, LG&E and KU have recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 16 and Note 19 to the Financial Statements in the Registrants’ 2017 Form 10-K for additional information on ~~environmental matters.~~AROs. LG&E and KU continue to perform technical evaluations related to their plans to close impoundments at all of their generating plants. Although LG&E and KU believe their recorded liabilities appropriately reflect their obligations under current rules, changes to current compliance strategies as a result of ongoing regulatory proceedings or other developments could result in additional closure costs. It is not currently possible to determine the magnitude of any potential cost increases related to changes in compliance strategies or plans, and the timing of future cash outflows are indeterminable at this time. As rules are revised, technical evaluations are completed, and the timing and details of impoundment closures develop further on a plant-by-plant basis, LG&E and KU will update their cost estimates and record any changes as necessary to their ARO liability, which could be material. These costs are subject to rate recovery.

New Accounting Guidance (All Registrants)

See Note 2 and 17 to the Financial Statements for a discussion of new accounting guidance adopted and pending adoption.

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Application of Critical Accounting Policies (All Registrants)

Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. The following table summarizes the accounting policies by Registrant that are particularly important to an understanding of the reported financial condition or results of operations, and require management to make estimates or other judgments of matters that are inherently uncertain. See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' ~~2016~~2017 Form 10-K for a discussion of each critical accounting policy.

PPL

Electric

LKE

LG&E

Defined Benefits

Income Taxes

Regulatory Assets and Liabilities

Price Risk Management

Goodwill Impairment

AROs

~~Price Risk Management~~

~~Regulatory Assets and Liabilities~~

Revenue Recognition - Unbilled Revenue

Income Taxes (All Registrants)

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PPL Corporation

PPL Electric Utilities Corporation

LG&E and KU Energy LLC

Louisville Gas and Electric Company

Kentucky Utilities Company

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

Item 4. Controls and Procedures

(a) Evaluation of disclosure controls and procedures.

The Registrants' principal executive officers and principal financial officers, based on their evaluation of the Registrants' disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) of the Securities Exchange Act of 1934) have concluded that, as of September 30, ~~2017,~~2018, the Registrants' disclosure controls and procedures are effective to ensure that material information relating to the Registrants and their consolidated subsidiaries is recorded, processed, summarized and reported within the time periods specified by the SEC's rules and forms, particularly during the period for which this quarterly report has been prepared. The 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 and principal financial officers, to allow for timely decisions regarding required disclosure.

(b) Change in internal controls over financial reporting.

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

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For information regarding ~~pending administrative and judicial proceedings involving~~legal, tax, regulatory, environmental ~~and~~or other ~~matters,~~administrative proceedings that became reportable events or were pending in the third quarter of 2018, which information is incorporated by reference into this Part II, see:

"Item 3. Legal Proceedings" in each Registrant's ~~2016~~2017 Form 10-K; and

Notes 67 and 910 to the Financial Statements.

Item 1A. Risk Factors

There have been no material changes in the Registrants' risk factors from those disclosed in "Item 1A. Risk Factors" of the Registrants' ~~2016~~2017 Form 10-K.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

Effective October 25, 2018, the Compensation, Governance and Nominating Committee approved amendments of the 2012 Amended and Restated Stock Incentive Plan and the Incentive Compensation Plan for Key Employees. The amendments add a one-year minimum vesting requirement for equity awards with the exception of change-in-control events; death, retirement and disability; and additional awards issued in the aggregate up to 5% of the authorized shares that can be issued under the respective equity plan.

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Item 6. Exhibits

The following Exhibits indicated by an asterisk preceding the Exhibit number are filed herewith. The balance of the Exhibits has heretofore been filed with the Commission and pursuant to Rule 12(b)-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.

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*4(a)	-	Supplemental Indenture No. ~~16,~~6, dated as of ~~September 8, 2017, among PPL Capital Funding, Inc., PPL Corporation~~August 1, 2018, to Indenture, dated as of October 1, 2010, between Kentucky Utilities Company and The Bank of New York Mellon, ~~(as successor to JPMorgan Chase Bank, N.A. (formerly known as The Chase Manhattan Bank)),~~ as Trustee ~~(Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated September 6, 2017)~~
*4(b)	-	~~£3,000,000,000 Euro Medium Term Note Programme entered into~~2018 Series A Carroll County Loan Agreement, dated as of August 1, 2018, by and between Kentucky Utilities Company and County of Carroll, Kentucky
*4(c)	-	Amended and Restated Trust Deed, dated August 14, 2018, by and among Western Power Distribution (East Midlands) plc, Western Power Distribution (South Wales) plc, Western Power Distribution (South West) plc and Western Power Distribution (West Midlands) plc ~~dated~~ as ~~of September 15, 2017~~Issuers, and HSBC Corporate Trustee Company (UK) Limited as Note Trustee
*~~4(c)~~4(d)	-	~~Amendment No. 1 to PPL Employee Stock Ownership Plan,~~Trust Deed, dated October ~~2, 2017~~
*10(a)-1	-	~~£20,000,000 Uncommitted Facility Letter entered into~~16, 2018, between Western Power Distribution ~~(South West)~~ plc ~~Western Power Distribution (South Wales) plc, Western Power Distribution (West Midlands) plc, Western Power Distribution (East Midlands) plc~~as Issuer, and ~~BNP Paribas, dated~~HSBC Corporate Trustee Company (UK) Limited as ~~of January 23, 2014~~Trustee
*[_]10(a)-2	-	~~Amendment to said Uncommitted Facility Letter, dated as of July 28, 2017~~Amended and Restated Incentive Compensation Plan for Key Employees, effective October 25, 2018
*[_]10(b)	-	~~$200,000,000 Term Loan Credit Agreement, dated as of~~PPL Corporation Amended and Restated 2012 Stock Incentive Plan, effective October ~~26, 2017, among Louisville Gas and Electric Company, as the Borrower, the Lenders from time to time party hereto and U.S. Bank National Association, as Administrative Agent~~25, 2018
*12(a)	-	PPL Corporation and Subsidiaries Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends
*12(b)	-	PPL Electric Utilities Corporation and Subsidiaries Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends
*12(c)	-	LG&E and KU Energy LLC and Subsidiaries Computation of Ratio of Earnings to Fixed Charges
*12(d)	-	Louisville Gas and Electric Company Computation of Ratio of Earnings to Fixed Charges
*12(e)	-	Kentucky Utilities Company Computation of Ratio of Earnings to Fixed Charges

Certifications pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended September 30, ~~2017,~~2018, filed by the following officers for the following companies:

*31(a)	-	PPL Corporation's principal executive officer
*31(b)	-	PPL Corporation's principal financial officer
*31(c)	-	PPL Electric Utilities Corporation's principal executive officer
*31(d)	-	PPL Electric Utilities Corporation's principal financial officer
*31(e)	-	LG&E and KU Energy LLC's principal executive officer
*31(f)	-	LG&E and KU Energy LLC's principal financial officer
*31(g)	-	Louisville Gas and Electric Company's principal executive officer
*31(h)	-	Louisville Gas and Electric Company's principal financial officer
*31(i)	-	Kentucky Utilities Company's principal executive officer
*31(j)	-	Kentucky Utilities Company's principal financial officer

Certifications pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended September 30, ~~2017,~~2018, furnished by the following officers for the following companies:

*32(a)	-	PPL Corporation's principal executive officer and principal financial officer
*32(b)	-	PPL Electric Utilities Corporation's principal executive officer and principal financial officer
*32(c)	-	LG&E and KU Energy LLC's principal executive officer and principal financial officer
*32(d)	-	Louisville Gas and Electric Company's principal executive officer and principal financial officer
*32(e)	-	Kentucky Utilities Company's principal executive officer and principal financial officer

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101.INS	-	XBRL Instance Document
101.SCH	-	XBRL Taxonomy Extension Schema
101.CAL	-	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	-	XBRL Taxonomy Extension Definition Linkbase
101.LAB	-	XBRL Taxonomy Extension Label Linkbase
101.PRE	-	XBRL Taxonomy Extension Presentation Linkbase

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SIGNATURES

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



		PPL Corporation
		(Registrant)



Date:	November 1, ~~2017~~2018	/s/ Stephen K. Breininger
		Stephen K. Breininger Vice President and Controller
		(Principal Accounting Officer)



		PPL Electric Utilities Corporation
		(Registrant)



Date:	November 1, ~~2017~~2018	/s/ Marlene C. Beers
		Marlene C. Beers Vice President-Finance and Regulatory Affairs and Controller
		(Principal Financial Officer and Principal Accounting Officer)



		LG&E and KU Energy LLC
		(Registrant)

		Louisville Gas and Electric Company
		(Registrant)

		Kentucky Utilities Company
		(Registrant)



Date:	November 1, ~~2017~~2018	/s/ Kent W. Blake
		Kent W. Blake Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

~~110~~130



	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	16			15			5			10
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(70		)	(63		)	(12		)	(51		)
Obligations settled	(30		)	(30		)	(20		)	(10		)
Balance at September 30, 2017	$	406		$	355		$	118		$	237



	Three Months			Nine Months
Kentucky Gross Margins	$	10		$	(13	)
Other operation and maintenance	(5		)	6
Depreciation	(10		)	(15		)
Taxes, other than income	—			(2		)
Other Income (Expense) - net	4			5
Interest Expense	—			(2		)
Income Taxes	—			7
Earnings from Ongoing Operations	(1		)	(14		)
Special items, after-tax	—			(1		)
Net Income	$	(1	)	$	(15	)



	Three Months			Nine Months
Pennsylvania Gross Margins	$	6		$	14
Other operation and maintenance	16			8
Depreciation	(8		)	(29		)
Taxes, other than income	(1		)	1
Other Income (Expense) - net	1			(1		)
Interest Expense	(4		)	(8		)
Income Taxes	(6		)	3
Net Income	$	4		$	(12	)



	Three Months		Nine Months
Number of shares (in thousands)	2,049		5,526
Average share price	$	39.04	$	38.49
Net Proceeds	$	79	$	211