10-Q

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 June 30, 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

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, 699,570,660 shares outstanding at July 31, 2018.
PPL Electric Utilities Corporation	Common stock, no par value, 66,368,056 shares outstanding and all held by PPL Corporation at July 31, 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 July 31, 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 July 31, 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.

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 JUNE 30, 2018

Table of Contents

This combined Form 10-Q is separately filed by the following Registrants in their individual capacity: PPL Corporation, PPL Electric Utilities Corporation, 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' financial statements in accordance with GAAP. This presentation has been applied where identification of particular subsidiaries is not material to the matter being disclosed, and to conform narrative disclosures to the presentation of financial information on a consolidated basis.

				Page
GLOSSARY OF TERMS AND ABBREVIATIONS				i
FORWARD-LOOKING INFORMATION				1
PART I.  FINANCIAL INFORMATION
	Item 1.  Financial Statements
		PPL Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	3
			Condensed Consolidated Statements of Comprehensive Income	4
			Condensed Consolidated Statements of Cash Flows	5
			Condensed Consolidated Balance Sheets	6
			Condensed Consolidated Statements of Equity	8
		PPL Electric Utilities Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	10
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Balance Sheets	12
			Condensed Consolidated Statements of Equity	14
		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

	Combined Notes to Condensed Financial Statements (Unaudited)
		1.   Interim Financial Statements		33
		2.   Summary of Significant Accounting Policies		33
		3.   Segment and Related Information		35
		4.   Revenue from Contracts with Customers		35
		5.   Earnings Per Share		39
		6.   Income Taxes		40
		7.   Utility Rate Regulation		42
		8.   Financing Activities		47
		9.   Defined Benefits		51
		10. Commitments and Contingencies		53
		11. Related Party Transactions		61
		12. Other Income (Expense) - net		62
		13. Fair Value Measurements		62
		14. Derivative Instruments and Hedging Activities		65
		15. Asset Retirement Obligations		72
		16. Accumulated Other Comprehensive Income (Loss)		72
		17. New Accounting Guidance Pending Adoption		74
	Item 2.  Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		77
			Introduction	77
			Business Strategy	79
			Financial and Operational Developments	80
		Results of Operations		85
			PPL Corporation and Subsidiaries - Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins	86
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis, Earnings and Adjusted Gross Margins	99
			LG&E and KU Energy LLC and Subsidiaries - Statement of Income Analysis, Earnings and Adjusted Gross Margins	102
			Louisville Gas and Electric Company - Statement of Income Analysis, Earnings and Adjusted Gross Margins	105
			Kentucky Utilities Company - Statement of Income Analysis, Earnings and Adjusted Gross Margins	108
		Financial Condition		111
			Liquidity and Capital Resources	111
			Risk Management	117
			Foreign Currency Translation	119
			Related Party Transactions	119
			Acquisitions, Development and Divestitures	119
			Environmental Matters	119
		New Accounting Guidance		120
		Application of Critical Accounting Policies		120
	Item 3.  Quantitative and Qualitative Disclosures About Market Risk			121
	Item 4.  Controls and Procedures			121
PART II.  OTHER INFORMATION
	Item 1. Legal Proceedings			121
	Item 1A. Risk Factors			121
	Item 4. Mine Safety Disclosures			121
	Item 6. Exhibits			121
SIGNATURES				124
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. Following a reorganization in October 2015 and October 2017, PPL WPD Limited is 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, 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.

i

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

Other terms and abbreviations

£ - British pound sterling.

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

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

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

Act 129 Smart Meter program - PPL Electric's system wide meter replacement program that installs wireless digital meters that provide secure communication between PPL Electric and the meter as well as all related infrastructure.

Adjusted Gross Margins - a non-GAAP financial measure of performance used in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).

Advanced Metering System - meters and 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 - at-the-market stock offering program.

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

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

Clean Water Act - federal legislation enacted to address certain environmental issues relating to water quality including effluent discharges, cooling water intake, and dredge and fill activities.

CPCN - Certificate of Public Convenience and Necessity. Authority granted by the KPSC pursuant to Kentucky Revised Statute 278.020 to provide utility service to or for the public or the construction of certain plant, equipment, property or facility for furnishing of utility service to the public.

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.

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

ii

DNO - Distribution Network Operator in the U.K.

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

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

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

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

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

EPS - earnings per share.

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

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

GBP -British pound sterling.

GHG(s) -greenhouse gas(es).

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

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

kWh - kilowatt hour, basic unit of electrical energy.

LIBOR - London Interbank Offered Rate.

Mcf - one thousand cubic feet, a unit of measure for natural gas.

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

iii

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.

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 capacities of 2,120 MW.

Performance unit - stock-based compensation award that represents a variable number of shares of PPL common stock that a recipient may receive based on PPL's attainment of (i) total shareowner return (TSR) over a three-year performance period as compared to companies in the Philadelphia Stock Exchange Utility 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.

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

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 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.

iv

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.

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

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.

SCRs - selective catalytic reduction, a pollution control process for the removal of 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.

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 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 proceedings;

• changes in U.S. state or federal, or U.K. tax laws or 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;

• developments related to 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 of the Registrants and their subsidiaries;

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

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

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

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

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

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

• 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.

1

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.

2

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 June 30,					Six Months Ended June 30,
	2018		2017			2018		2017
Operating Revenues	$	1,848	$	1,725		$	3,974	$	3,676
Operating Expenses
Operation
Fuel	189		183			403		374
Energy purchases	148		136			389		351
Other operation and maintenance	506		432			974		902
Depreciation	273		246			542		488
Taxes, other than income	74		70			157		145
Total Operating Expenses	1,190		1,067			2,465		2,260
Operating Income	658		658			1,509		1,416
Other Income (Expense) - net	234		(68		)	191		(77		)
Interest Expense	235		222			474		439
Income Before Income Taxes	657		368			1,226		900
Income Taxes	142		76			259		205
Net Income	$	515	$	292		$	967	$	695
Earnings Per Share of Common Stock:
Net Income Available to PPL Common Shareowners:
Basic	$	0.74	$	0.43		$	1.39	$	1.02
Diluted	$	0.73	$	0.43		$	1.38	$	1.01
Dividends Declared Per Share of Common Stock	$	0.41	$	0.395		$	0.82	$	0.79
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	699,006		683,841			696,772		682,370
Diluted	700,976		686,351			698,161		684,725

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

3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
Net income	$	515		$	292		$	967		$	695
Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax of ($2), $0, ($2), ($1)	(250		)	231			(134		)	207
Qualifying derivatives, net of tax of ($4), $5, $0, $7	19			(24		)	(1		)	(30		)
Defined benefit plans:
Prior service costs, net of tax of $0, $0, $0, $0	(1		)	—			(1		)	—
Net actuarial gain (loss), net of tax of $0, $7, $0, $7	—			(11		)	(1		)	(11		)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax of $3, ($7), $1, ($7)	(19		)	25			(7		)	24
Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0, $0	—			1			—			1
Defined benefit plans:
Prior service costs, net of tax of $0, $0, $0, $0	1			1			1			1
Net actuarial (gain) loss, net of tax of ($9), ($9), ($18), ($18)	34			31			70			63
Total other comprehensive income (loss)	(216		)	254			(73		)	255
Comprehensive income	$	299		$	546		$	894		$	950

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

4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities
Net income	$	967		$	695
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	542			488
Amortization	34			45
Defined benefit plans - (income)	(101		)	(45		)
Deferred income taxes and investment tax credits	171			201
Unrealized (gains) losses on derivatives, and other hedging activities	(91		)	135
Stock-based compensation expense	16			22
Other	(9		)	(5		)
Change in current assets and current liabilities
Accounts receivable	46			26
Accounts payable	(90		)	(92		)
Unbilled revenues	91			70
Fuel, materials and supplies	32			42
Prepayments	(60		)	(66		)
Taxes payable	28			(27		)
Regulatory assets and liabilities, net	42			(19		)
Accrued interest	(79		)	(77		)
Other current liabilities	(47		)	(52		)
Other	(16		)	13
Other operating activities
Defined benefit plans - funding	(206		)	(552		)
Proceeds from transfer of excess benefit plan funds	65			—
Other assets	(67		)	(1		)
Other liabilities	57			(11		)
Net cash provided by operating activities	1,325			790
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(1,527		)	(1,373		)
Purchase of available-for-sale securities	(65		)	—
Other investing activities	(57		)	(12		)
Net cash used in investing activities	(1,649		)	(1,385		)
Cash Flows from Financing Activities
Issuance of long-term debt	584			594
Retirement of long-term debt	(250		)	(60		)
Issuance of common stock	147			177
Payment of common stock dividends	(558		)	(529		)
Net increase in short-term debt	788			554
Other financing activities	(16		)	(25		)
Net cash provided by financing activities	695			711
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash	(7		)	7
Net Increase in Cash, Cash Equivalents and Restricted Cash	364			123
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	511			367
Cash, Cash Equivalents and Restricted Cash at End of Period	$	875		$	490
Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	329		$	284
Accrued expenditures for intangible assets at June 30,	$	59		$	56

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

5

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Assets
Current Assets
Cash and cash equivalents	$	852	$	485
Accounts receivable (less reserve: 2018, $55; 2017, $51)
Customer	675		681
Other	66		100
Unbilled revenues	453		543
Fuel, materials and supplies	288		320
Prepayments	126		66
Price risk management assets	78		49
Other current assets	62		50
Total Current Assets	2,600		2,294
Property, Plant and Equipment
Regulated utility plant	38,999		38,228
Less:  accumulated depreciation - regulated utility plant	7,083		6,785
Regulated utility plant, net	31,916		31,443
Non-regulated property, plant and equipment	370		384
Less:  accumulated depreciation - non-regulated property, plant and equipment	108		110
Non-regulated property, plant and equipment, net	262		274
Construction work in progress	1,645		1,375
Property, Plant and Equipment, net	33,823		33,092
Other Noncurrent Assets
Regulatory assets	1,530		1,504
Goodwill	3,308		3,258
Other intangibles	694		697
Pension benefit asset	498		284
Price risk management assets	185		215
Other noncurrent assets	192		135
Total Other Noncurrent Assets	6,407		6,093
Total Assets	$	42,830	$	41,479

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

6

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018			December 31, 2017
Liabilities and Equity
Current Liabilities
Short-term debt	$	1,864		$	1,080
Long-term debt due within one year	203			348
Accounts payable	804			924
Taxes	132			105
Interest	203			282
Dividends	287			273
Customer deposits	271			292
Regulatory liabilities	137			95
Other current liabilities	547			624
Total Current Liabilities	4,448			4,023
Long-term Debt	20,217			19,847
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	2,632			2,462
Investment tax credits	128			129
Accrued pension obligations	665			800
Asset retirement obligations	297			312
Regulatory liabilities	2,747			2,704
Other deferred credits and noncurrent liabilities	456			441
Total Deferred Credits and Other Noncurrent Liabilities	6,925			6,848
Commitments and Contingent Liabilities (Notes 7 and 10)
Equity
Common stock - $0.01 par value (a)	7			7
Additional paid-in capital	10,462			10,305
Earnings reinvested	4,266			3,871
Accumulated other comprehensive loss	(3,495		)	(3,422		)
Total Equity	11,240			10,761
Total Liabilities and Equity	$	42,830		$	41,479

(a) 1,560,000 shares authorized; 699,128 and 693,398 shares issued and outstanding at June 30, 2018 and December 31, 2017.

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

7

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	5,730			163									163
Stock-based compensation				(6		)							(6		)
Net income							967						967
Dividends and dividend equivalents							(572		)				(572		)
Other comprehensive income (loss)										(73		)	(73		)
June 30, 2018	699,128	$	7	$	10,462		$	4,266		$	(3,495	)	$	11,240
December 31, 2016	679,731	$	7	$	9,841		$	3,829		$	(3,778	)	$	9,899
Common stock issued	5,742			202									202
Stock-based compensation				(20		)							(20		)
Net income							695						695
Dividends and dividend equivalents							(541		)				(541		)
Other comprehensive income (loss)										255			255
June 30, 2017	685,473	$	7	$	10,023		$	3,983		$	(3,523	)	$	10,490

(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.

8

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9

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
Operating Revenues	$	517	$	500	$	1,156	$	1,073
Operating Expenses
Operation
Energy purchases	115		107		276		253
Other operation and maintenance	159		139		292		302
Depreciation	88		76		173		151
Taxes, other than income	22		23		54		52
Total Operating Expenses	384		345		795		758
Operating Income	133		155		361		315
Other Income (Expense) - net	7		4		13		4
Interest Income from Affiliate	1		1		1		1
Interest Expense	39		36		76		69
Income Before Income Taxes	102		124		299		251
Income Taxes	27		47		76		95
Net Income (a)	$	75	$	77	$	223	$	156

(a) Net income equals comprehensive income.

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

10

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities
Net income	$	223		$	156
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	173			151
Amortization	11			15
Defined benefit plans - expense	—			7
Deferred income taxes and investment tax credits	53			84
Other	(9		)	(4		)
Change in current assets and current liabilities
Accounts receivable	37			13
Accounts payable	(60		)	(59		)
Unbilled revenues	30			17
Prepayments	(47		)	(52		)
Regulatory assets and liabilities, net	(27		)	(12		)
Taxes payable	(1		)	(4		)
Other	1			(6		)
Other operating activities
Defined benefit plans - funding	(28		)	(24		)
Other assets	(41		)	(4		)
Other liabilities	49			1
Net cash provided by operating activities	364			279
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(518		)	(550		)
Net decrease in notes receivable from affiliate	—			(270		)
Other investing activities	(3		)	(4		)
Net cash used in investing activities	(521		)	(824		)
Cash Flows from Financing Activities
Issuance of long-term debt	398			470
Contributions from parent	425			575
Payment of common stock dividends to parent	(222		)	(154		)
Net decrease in short-term debt	—			(295		)
Other financing activities	(4		)	(5		)
Net cash provided by financing activities	597			591
Net Increase in Cash, Cash Equivalents and Restricted Cash	440			46
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	51			15
Cash, Cash Equivalents and Restricted Cash at End of Period	$	491		$	61
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	180		$	157

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

11

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Assets
Current Assets
Cash and cash equivalents	$	489	$	49
Accounts receivable (less reserve: 2018, $27; 2017, $24)
Customer	289		279
Other	23		71
Accounts receivable from affiliates	11		—
Unbilled revenues	97		127
Materials and supplies	28		34
Prepayments	53		6
Regulatory assets	16		16
Other current assets	13		6
Total Current Assets	1,019		588
Property, Plant and Equipment
Regulated utility plant	11,140		10,785
Less: accumulated depreciation - regulated utility plant	2,815		2,778
Regulated utility plant, net	8,325		8,007
Construction work in progress	586		508
Property, Plant and Equipment, net	8,911		8,515
Other Noncurrent Assets
Regulatory assets	737		709
Intangibles	260		259
Other noncurrent assets	56		11
Total Other Noncurrent Assets	1,053		979
Total Assets	$	10,983	$	10,082

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

12

CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Liabilities and Equity
Current Liabilities
Accounts payable	$	374	$	386
Accounts payable to affiliates	29		31
Taxes	7		8
Interest	37		36
Regulatory liabilities	66		86
Other current liabilities	99		98
Total Current Liabilities	612		645
Long-term Debt	3,693		3,298
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,225		1,154
Accrued pension obligations	212		246
Regulatory liabilities	692		668
Other deferred credits and noncurrent liabilities	131		79
Total Deferred Credits and Other Noncurrent Liabilities	2,260		2,147
Commitments and Contingent Liabilities (Notes 7 and 10)
Equity
Common stock - no par value (a)	364		364
Additional paid-in capital	3,154		2,729
Earnings reinvested	900		899
Total Equity	4,418		3,992
Total Liabilities and Equity	$	10,983	$	10,082

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

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

13

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
December 31, 2017	66,368	$	364	$	2,729	$	899		$	3,992
Net income						223			223
Capital contributions from PPL				425					425
Dividends declared on common stock						(222		)	(222		)
June 30, 2018	66,368	$	364	$	3,154	$	900		$	4,418
December 31, 2016	66,368	$	364	$	2,154	$	873		$	3,391
Net income						156			156
Capital contributions from PPL				575					575
Dividends declared on common stock						(154		)	(154		)
June 30, 2017	66,368	$	364	$	2,729	$	875		$	3,968

(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.

14

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,					Six Months Ended June 30,
	2018		2017			2018			2017
Operating Revenues	$	743	$	723		$	1,615		$	1,532
Operating Expenses
Operation
Fuel	189		183			403			374
Energy purchases	33		29			113			98
Other operation and maintenance	211		192			416			397
Depreciation	118		105			235			210
Taxes, other than income	18		16			35			32
Total Operating Expenses	569		525			1,202			1,111
Operating Income	174		198			413			421
Other Income (Expense) - net	1		(4		)	(2		)	(8		)
Interest Expense	52		50			102			99
Interest Expense with Affiliate	6		4			11			8
Income Before Income Taxes	117		140			298			306
Income Taxes	31		53			70			116
Net Income	$	86	$	87		$	228		$	190

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

15

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018		2017
Net income	$	86		$	87		$	228	$	190
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, $7, $0, $7	1			(11		)	—		(11		)
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
Defined benefit plans:
Prior service costs, net of tax of $0, $0, $0, $0	1			1			1		1
Net actuarial (gain) loss, net of tax of $0, ($1), ($1), ($2)	(1		)	1			1		2
Total other comprehensive income (loss)	1			(9		)	2		(7		)
Comprehensive income	$	87		$	78		$	230	$	183

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

16

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities
Net income	$	228		$	190
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	235			210
Amortization	9			14
Defined benefit plans - expense	8			12
Deferred income taxes and investment tax credits	30			91
Other	(1		)	—
Change in current assets and current liabilities
Accounts receivable	16			13
Accounts payable	(10		)	(28		)
Accounts payable to affiliates	1			—
Unbilled revenues	40			23
Fuel, materials and supplies	26			41
Regulatory assets and liabilities, net	69			(7		)
Taxes payable	(25		)	3
Other	(40		)	(14		)
Other operating activities
Defined benefit plans - funding	(122		)	(29		)
Expenditures for asset retirement obligations	(26		)	(12		)
Other assets	(1		)	(2		)
Other liabilities	3			6
Net cash provided by operating activities	440			511
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(564		)	(355		)
Net cash used in investing activities	(564		)	(355		)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate	(126		)	(4		)
Issuance of long-term debt with affiliate	250			—
Issuance of long-term debt	100			60
Retirement of long-term debt	—			(60		)
Distributions to member	(161		)	(218		)
Net increase in short-term debt	72			73
Other financing activities	(2		)	(1		)
Net cash provided by (used in) financing activities	133			(150		)
Net Increase in Cash and Cash Equivalents	9			6
Cash and Cash Equivalents at Beginning of Period	30			13
Cash and Cash Equivalents at End of Period	$	39		$	19
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	112		$	83

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

17

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)

	June 30, 2018		December 31, 2017
Assets
Current Assets
Cash and cash equivalents	$	39	$	30
Accounts receivable (less reserve: 2018, $26; 2017, $25)
Customer	229		246
Other	45		44
Unbilled revenues	163		203
Fuel, materials and supplies	229		254
Prepayments	31		25
Regulatory assets	11		18
Other current assets	6		8
Total Current Assets	753		828
Property, Plant and Equipment
Regulated utility plant	13,346		13,187
Less: accumulated depreciation - regulated utility plant	1,955		1,785
Regulated utility plant, net	11,391		11,402
Construction work in progress	880		627
Property, Plant and Equipment, net	12,271		12,029
Other Noncurrent Assets
Regulatory assets	793		795
Goodwill	996		996
Other intangibles	82		86
Other noncurrent assets	75		68
Total Other Noncurrent Assets	1,946		1,945
Total Assets	$	14,970	$	14,802

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

18

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)

	June 30, 2018		December 31, 2017
Liabilities and Equity
Current Liabilities
Short-term debt	$	316	$	244
Long-term debt due within one year	203		98
Notes payable with affiliates	99		225
Accounts payable	266		338
Accounts payable to affiliates	8		7
Customer deposits	59		58
Taxes	41		66
Price risk management liabilities	4		4
Regulatory liabilities	71		9
Interest	32		32
Asset retirement obligations	84		85
Other current liabilities	124		161
Total Current Liabilities	1,307		1,327
Long-term Debt
Long-term debt	4,657		4,661
Long-term debt to affiliate	650		400
Total Long-term Debt	5,307		5,061
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	878		866
Investment tax credits	127		129
Price risk management liabilities	17		22
Accrued pension obligations	259		365
Asset retirement obligations	248		271
Regulatory liabilities	2,055		2,036
Other deferred credits and noncurrent liabilities	140		162
Total Deferred Credits and Other Noncurrent Liabilities	3,724		3,851
Commitments and Contingent Liabilities (Notes 7 and 10)
Member's Equity	4,632		4,563
Total Liabilities and Equity	$	14,970	$	14,802

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

19

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	228
Distributions to member	(161		)
Other comprehensive income	2
June 30, 2018	$	4,632
December 31, 2016	$	4,667
Net income	190
Distributions to member	(218		)
Other comprehensive income	(7		)
June 30, 2017	$	4,632

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

20

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21

CONDENSED STATEMENTS OF INCOME

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,					Six Months Ended June 30,
	2018			2017		2018			2017
Operating Revenues
Retail and wholesale	$	331		$	320	$	738		$	694
Electric revenue from affiliate	4			4		16			21
Total Operating Revenues	335			324		754			715
Operating Expenses
Operation
Fuel	72			69		151			149
Energy purchases	28			25		104			89
Energy purchases from affiliate	2			3		8			5
Other operation and maintenance	93			86		182			171
Depreciation	49			45		97			89
Taxes, other than income	9			9		18			17
Total Operating Expenses	253			237		560			520
Operating Income	82			87		194			195
Other Income (Expense) - net	(1		)	1		(2		)	(3		)
Interest Expense	19			19		37			36
Income Before Income Taxes	62			69		155			156
Income Taxes	12			27		33			60
Net Income (a)	$	50		$	42	$	122		$	96

(a) Net income equals comprehensive income.

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

22

CONDENSED STATEMENTS OF CASH FLOWS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities
Net income	$	122		$	96
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	97			89
Amortization	7			7
Defined benefit plans - expense	2			3
Deferred income taxes and investment tax credits	18			57
Change in current assets and current liabilities
Accounts receivable	11			9
Accounts receivable from affiliates	6			11
Accounts payable	(12		)	(17		)
Accounts payable to affiliates	(3		)	(3		)
Unbilled revenues	24			14
Fuel, materials and supplies	31			33
Regulatory assets and liabilities, net	32			(3		)
Taxes payable	(2		)	(23		)
Other	(7		)	—
Other operating activities
Defined benefit plans - funding	(57		)	(3		)
Expenditures for asset retirement obligations	(10		)	(7		)
Other liabilities	(4		)	1
Net cash provided by operating activities	255			264
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(296		)	(177		)
Net cash used in investing activities	(296		)	(177		)
Cash Flows from Financing Activities
Issuance of long-term debt	100			60
Retirement of long-term debt	—			(60		)
Net increase (decrease) in short-term debt	(16		)	38
Payment of common stock dividends to parent	(81		)	(122		)
Contributions from parent	43			—
Other financing activities	(1		)	(1		)
Net cash provided by (used in) financing activities	45			(85		)
Net Increase in Cash and Cash Equivalents	4			2
Cash and Cash Equivalents at Beginning of Period	15			5
Cash and Cash Equivalents at End of Period	$	19		$	7
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	57		$	40

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

23

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Assets
Current Assets
Cash and cash equivalents	$	19	$	15
Accounts receivable (less reserve: 2018, $1; 2017, $1)
Customer	104		116
Other	14		13
Unbilled revenues	67		91
Accounts receivable from affiliates	18		24
Fuel, materials and supplies	100		131
Prepayments	16		11
Regulatory assets	11		12
Other current assets	2		3
Total Current Assets	351		416
Property, Plant and Equipment
Regulated utility plant	5,653		5,587
Less: accumulated depreciation - regulated utility plant	678		614
Regulated utility plant, net	4,975		4,973
Construction work in progress	455		305
Property, Plant and Equipment, net	5,430		5,278
Other Noncurrent Assets
Regulatory assets	406		411
Goodwill	389		389
Other intangibles	50		53
Other noncurrent assets	23		12
Total Other Noncurrent Assets	868		865
Total Assets	$	6,649	$	6,559

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

24

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Liabilities and Equity
Current Liabilities
Short-term debt	$	183	$	199
Long-term debt due within one year	194		98
Accounts payable	132		179
Accounts payable to affiliates	21		23
Customer deposits	28		27
Taxes	23		25
Price risk management liabilities	4		4
Regulatory liabilities	34		3
Interest	11		11
Asset retirement obligations	17		24
Other current liabilities	47		52
Total Current Liabilities	694		645
Long-term Debt	1,614		1,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	581		572
Investment tax credits	34		35
Price risk management liabilities	17		22
Accrued pension obligations	—		45
Asset retirement obligations	95		97
Regulatory liabilities	922		919
Other deferred credits and noncurrent liabilities	81		86
Total Deferred Credits and Other Noncurrent Liabilities	1,730		1,776
Commitments and Contingent Liabilities (Notes 7 and 10)
Stockholder's Equity
Common stock - no par value (a)	424		424
Additional paid-in capital	1,755		1,712
Earnings reinvested	432		391
Total Equity	2,611		2,527
Total Liabilities and Equity	$	6,649	$	6,559

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

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

25

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						122			122
Capital contributions from LKE				43					43
Cash dividends declared on common stock						(81		)	(81		)
June 30, 2018	21,294	$	424	$	1,755	$	432		$	2,611
December 31, 2016	21,294	$	424	$	1,682	$	370		$	2,476
Net income						96			96
Cash dividends declared on common stock						(122		)	(122		)
June 30, 2017	21,294	$	424	$	1,682	$	344		$	2,450

(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.

26

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27

CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,					Six Months Ended June 30,
	2018		2017			2018		2017
Operating Revenues
Retail and wholesale	$	412	$	403		$	877	$	838
Electric revenue from affiliate	2		3			8		5
Total Operating Revenues	414		406			885		843
Operating Expenses
Operation
Fuel	117		114			252		225
Energy purchases	5		4			9		9
Energy purchases from affiliate	4		4			16		21
Other operation and maintenance	112		100			217		208
Depreciation	70		61			138		121
Taxes, other than income	9		7			17		15
Total Operating Expenses	317		290			649		599
Operating Income	97		116			236		244
Other Income (Expense) - net	3		(2		)	—		(4		)
Interest Expense	25		24			50		48
Income Before Income Taxes	75		90			186		192
Income Taxes	14		34			38		73
Net Income (a)	$	61	$	56		$	148	$	119

(a) Net income approximates comprehensive income.

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

28

CONDENSED STATEMENTS OF CASH FLOWS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Six Months Ended June 30,
	2018			2017
Cash Flows from Operating Activities
Net income	$	148		$	119
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	138			121
Amortization	2			6
Defined benefit plans - expense	—			2
Deferred income taxes and investment tax credits	9			70
Other	(1		)	—
Change in current assets and current liabilities
Accounts receivable	4			5
Accounts payable	11			(1		)
Accounts payable to affiliates	(12		)	(15		)
Unbilled revenues	16			9
Fuel, materials and supplies	(5		)	8
Regulatory assets and liabilities, net	37			(4		)
Taxes payable	4			(29		)
Other	(11		)	(9		)
Other operating activities
Defined benefit plans - funding	(52		)	(21		)
Expenditures for asset retirement obligations	(16		)	(5		)
Other assets	(1		)	(3		)
Other liabilities	3			4
Net cash provided by operating activities	274			257
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(266		)	(177		)
Net cash used in investing activities	(266		)	(177		)
Cash Flows from Financing Activities
Net increase in short-term debt	88			35
Payment of common stock dividends to parent	(136		)	(110		)
Contributions from parent	45			—
Net cash used in financing activities	(3		)	(75		)
Net Increase in Cash and Cash Equivalents	5			5
Cash and Cash Equivalents at Beginning of Period	15			7
Cash and Cash Equivalents at End of Period	$	20		$	12
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	55		$	43

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

29

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Assets
Current Assets
Cash and cash equivalents	$	20	$	15
Accounts receivable (less reserve: 2018, $1; 2017, $1)
Customer	125		130
Other	31		30
Unbilled revenues	96		112
Fuel, materials and supplies	129		123
Prepayments	15		14
Regulatory assets	—		6
Other current assets	4		5
Total Current Assets	420		435
Property, Plant and Equipment
Regulated utility plant	7,683		7,592
Less: accumulated depreciation - regulated utility plant	1,275		1,170
Regulated utility plant, net	6,408		6,422
Construction work in progress	424		321
Property, Plant and Equipment, net	6,832		6,743
Other Noncurrent Assets
Regulatory assets	387		384
Goodwill	607		607
Other intangibles	32		33
Other noncurrent assets	75		52
Total Other Noncurrent Assets	1,101		1,076
Total Assets	$	8,353	$	8,254

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

30

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	June 30, 2018		December 31, 2017
Liabilities and Equity
Current Liabilities
Short-term debt	$	133	$	45
Long-term debt due within one year	9		—
Accounts payable	121		137
Accounts payable to affiliates	42		53
Customer deposits	31		31
Taxes	23		19
Regulatory liabilities	37		6
Interest	16		16
Asset retirement obligations	67		61
Other current liabilities	35		46
Total Current Liabilities	514		414
Long-term Debt	2,320		2,328
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	690		691
Investment tax credits	93		94
Accrued pension obligations	—		36
Asset retirement obligations	153		174
Regulatory liabilities	1,133		1,117
Other deferred credits and noncurrent liabilities	36		43
Total Deferred Credits and Other Noncurrent Liabilities	2,105		2,155
Commitments and Contingent Liabilities (Notes 7 and 10)
Stockholder's Equity
Common stock - no par value (a)	308		308
Additional paid-in capital	2,661		2,616
Earnings reinvested	445		433
Total Equity	3,414		3,357
Total Liabilities and Equity	$	8,353	$	8,254

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

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

31

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 loss			Total
December 31, 2017	37,818	$	308	$	2,616	$	433		$	—		$	3,357
Capital contributions from LKE				45								45
Net income						148						148
Cash dividends declared on common stock						(136		)				(136		)
June 30, 2018	37,818	$	308	$	2,661	$	445		$	—		$	3,414
December 31, 2016	37,818	$	308	$	2,616	$	400		$	(1	)	$	3,323
Net income						119						119
Cash dividends declared on common stock						(110		)				(110		)
Other comprehensive income (loss)									1			1
June 30, 2017	37,818	$	308	$	2,616	$	409		$	—		$	3,333

(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.

32

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, 2017 is derived from that Registrant's 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 2017 Form 10-K. The results of operations for the three and six months ended June 30, 2018 are not necessarily indicative of the results to be expected for the full year ending December 31, 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

(All Registrants)

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

New Accounting Guidance Adopted (All Registrants)

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 as a result of 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.

33

For PPL, the non-service cost components of net periodic benefit costs were in a net credit position for the three and six months ended June 30, 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 $6 million ($5 million after-tax or $0.01 per share) and $11 million ($9 million after-tax or $0.01 per share) for the three and six months ended June 30, 2018. For PPL Electric, LG&E and 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					Six Months
	2018			2017		2018			2017
PPL	$	66		$	44	$	134		$	82
PPL Electric	1			1		3			—
LKE	—			—		2			(2		)
LG&E	(2		)	—		(1		)	(2		)
KU	1			—		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.

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
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Cash and cash equivalents	$	852	$	485	$	489	$	49
Restricted cash - current (a)	3		3		2		2
Restricted cash - noncurrent (a)	20		23		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	875	$	511	$	491	$	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."

34

3. Segment and Related Information

(PPL)

See Note 2 in PPL's 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 June 30 are as follows:

	Three Months						Six Months
	2018			2017			2018			2017
Operating Revenues from external customers
U.K. Regulated	$	584		$	502		$	1,199		$	1,070
Kentucky Regulated	743			723			1,615			1,532
Pennsylvania Regulated	517			500			1,156			1,073
Corporate and Other	4			—			4			1
Total	$	1,848		$	1,725		$	3,974		$	3,676
Net Income
U.K. Regulated (a)	$	394		$	148		$	591		$	434
Kentucky Regulated	77			79			210			174
Pennsylvania Regulated	75			77			223			156
Corporate and Other	(31		)	(12		)	(57		)	(69		)
Total	$	515		$	292		$	967		$	695

(a) Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 14 for additional information.

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

	June 30, 2018		December 31, 2017
Assets
U.K. Regulated (a)	$	16,839	$	16,813
Kentucky Regulated	14,636		14,468
Pennsylvania Regulated	10,995		10,082
Corporate and Other (b)	360		116
Total	$	42,830	$	41,479

(a) Includes $12.6 billion and $12.5 billion of net PP&E as of June 30, 2018 and December 31, 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.

(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.

U.K. Regulated Segment Revenue(PPL)

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

35

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.

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 primarily 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

36

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 June 30, 2018.

	Three Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,848		$	517		$	743		$	335		$	414
Revenues derived from:
Alternative revenue programs (b)	9			—			9			6			3
Other (c)	(13		)	(2		)	(4		)	(2		)	(2		)
Revenues from Contracts with Customers	$	1,844		$	515		$	748		$	339		$	415

	Six Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	3,974		$	1,156		$	1,615		$	754		$	885
Revenues derived from:
Alternative revenue programs (b)	41			2			39			20			19
Other (c)	(28		)	(6		)	(9		)	(3		)	(6		)
Revenues from Contracts with Customers	$	3,987		$	1,152		$	1,645		$	771		$	898

(a) PPL includes $584 million and $1,199 million for the three and six months ended June 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 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 $414 million and $101 million for the three months ended June 30, 2018 and $946 million and $206 million for the six months ended June 30, 2018.

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

37

	Three Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	547	$	—	$	—	$	—	$	—
Residential	588		300		288		146		142
Commercial	296		89		207		107		100
Industrial	155		12		143		45		98
Other (b)	114		13		67		30		37
Wholesale - municipal	31		—		31		—		31
Wholesale - other (c)	12		—		12		11		7
Transmission	101		101		—		—		—
Revenues from Contracts with Customers	$	1,844	$	515	$	748	$	339	$	415

	Six Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,131	$	—	$	—	$	—	$	—
Residential	1,392		708		684		343		341
Commercial	621		187		434		231		203
Industrial	310		25		285		89		196
Other (b)	220		26		135		61		74
Wholesale - municipal	61		—		61		—		61
Wholesale - other (c)	46		—		46		47		23
Transmission	206		206		—		—		—
Revenues from Contracts with Customers	$	3,987	$	1,152	$	1,645	$	771	$	898

(a) Represents customers of WPD.

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

(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.

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

	Three Months		Six Months
PPL	$	3	$	13
PPL Electric	3		10
LKE	1		3
LG&E	—		1
KU	1		2

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 June 30, 2018	38		14		8		4		3

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

38

	Six Months
PPL	$	18
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 June 30, 2018, PPL had $70 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $50 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. 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 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 June 30 used in the EPS calculation are:

	Three Months				Six Months
	2018		2017		2018		2017
Income (Numerator)
Net income	$	515	$	292	$	967	$	695
Less amounts allocated to participating securities	—		—		1		1
Net income available to PPL common shareowners - Basic and Diluted	$	515	$	292	$	966	$	694
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	699,006		683,841		696,772		682,370
Add incremental non-participating securities:
Share-based payment awards	173		2,510		491		2,355
Forward sale agreements	1,797		—		898		—
Weighted-average shares - Diluted EPS	700,976		686,351		698,161		684,725
Basic EPS
Net Income available to PPL common shareowners	$	0.74	$	0.43	$	1.39	$	1.02
Diluted EPS
Net Income available to PPL common shareowners	$	0.73	$	0.43	$	1.38	$	1.01

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

39

	Three Months		Six Months
	2018	2017	2018	2017
Stock-based compensation plans (a)	12	564	488	1,451
DRIP	526	369	1,011	814

(a) Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors.

See Note 8 for additional information on common stock issued under the ATM Program.

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

	Three Months		Six Months
	2018	2017	2018	2017
Stock options	441	696	336	696
Restricted stock units	23	—	21	—

6. Income Taxes

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

(PPL)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	138		$	129		$	257		$	315
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			10			25			23
Valuation allowance adjustments	5			—			12			5
Impact of lower U.K. income tax rates relative to U.S. income tax rates (a)	(6		)	(40		)	(13		)	(88		)
U.S. income tax on foreign earnings - net of foreign tax credit (a) (b)	—			(7		)	1			(16		)
Federal and state tax reserve adjustments	3			—			3			—
Impact of the U.K. Finance Acts	(2		)	(6		)	(3		)	(9		)
Depreciation and other items not normalized	(2		)	(2		)	(4		)	(5		)
Amortization of excess deferred income taxes (a)	(9		)	—			(19		)	—
Deferred tax impact of state tax reform (c)	9			—			9			—
Interest benefit on U.K. financing entities	(4		)	(4		)	(9		)	(8		)
Stock-based compensation	—			(4		)	1			(7		)
Other	—			—			(1		)	(5		)
Total increase (decrease)	4			(53		)	2			(110		)
Total income taxes	$	142		$	76		$	259		$	205

(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 was recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

(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.

40

(PPL Electric)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	22		$	44		$	63		$	88
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	8			9			24			17
Depreciation and other items not normalized	(1		)	(2		)	(3		)	(4		)
Amortization of excess deferred income taxes (a)	(3		)	—			(8		)	—
Stock-based compensation	—			(3		)	—			(5		)
Other	1			(1		)	—			(1		)
Total increase (decrease)	5			3			13			7
Total income taxes	$	27		$	47		$	76		$	95

(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						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	25		$	49		$	63		$	107
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	3			5			11			11
Deferred tax impact of state tax reform (c)	9			—			9			—
Amortization of excess deferred income taxes (a)	(6		)	—			(11		)	—
Other	—			(1		)	(2		)	(2		)
Total increase (decrease)	6			4			7			9
Total income taxes	$	31		$	53		$	70		$	116

(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					Six Months
	2018			2017		2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	13		$	24	$	33		$	55
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3		6			6
Amortization of excess deferred income taxes (a)	(3		)	—		(5		)	—
Other	—			—		(1		)	(1		)
Total increase (decrease)	(1		)	3		—			5
Total income taxes	$	12		$	27	$	33		$	60

(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.

41

(KU)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	16		$	32		$	39		$	67
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3			7			7
Amortization of excess deferred income taxes (a)	(3		)	—			(6		)	—
Other	(1		)	(1		)	(2		)	(1		)
Total increase (decrease)	(2		)	2			(1		)	6
Total income taxes	$	14		$	34		$	38		$	73

(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.

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 reduced tax rate, related to the remeasurement of deferred income taxes, as an increase in regulatory liabilities of $16 million and $19 million. LG&E and KU continue to evaluate other impacts of Kentucky state tax reform along with the associated regulatory considerations. PPL is evaluating the impact, if any, of unitary or elective consolidated income tax reporting on all its Registrants.

U.S. Tax Reform(All Registrants)

On August 1, 2018, the Department of Treasury and the IRS issued proposed regulations under Internal Revenue Code Section 965 to provide guidance relating to the transition tax upon the mandatory deemed repatriation of certain deferred foreign earnings. On August 3, 2018, the Department of Treasury and the IRS also issued proposed regulations on the new 100 percent depreciation deduction effective for assets placed in service after September 27, 2017. The Registrants are currently reviewing the proposed regulations to determine what impact the newly issued guidance may have on their financial statements.

7. Utility Rate Regulation

(All Registrants)

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

42

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—
Smart meter rider	15		15		15		15
Plant outage costs	6		3		—		—
Gas supply clause	5		4		—		—
Other	1		1		1		1
Total current regulatory assets (a)	$	27	$	34	$	16	$	16
Noncurrent Regulatory Assets:
Defined benefit plans	$	857	$	880	$	491	$	504
Taxes recoverable through future rates	3		3		3		3
Storm costs (b)	47		33		21		—
Unamortized loss on debt	49		54		25		29
Interest rate swaps	21		26		—		—
Terminated interest rate swaps	89		92		—		—
Accumulated cost of removal of utility plant	182		173		182		173
AROs	260		234		—		—
Act 129 compliance rider	15		—		15		—
Other	7		9		—		—
Total noncurrent regulatory assets	$	1,530	$	1,504	$	737	$	709

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Generation supply charge	$	30	$	34	$	30	$	34
Transmission service charge	4		9		4		9
Environmental cost recovery	25		1		—		—
Universal service rider	20		26		20		26
Transmission formula rate	11		9		11		9
Fuel adjustment clause	5		3		—		—
TCJA customer refund (c)	33		—		—		—
Storm damage expense rider	1		8		1		8
Other	8		5		—		—
Total current regulatory liabilities	$	137	$	95	$	66	$	86
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	—	$	—
Power purchase agreement - OVEC (d)	64		68		—		—
Net deferred taxes (e)	1,858		1,853		652		668
Defined benefit plans	31		27		—		—
Terminated interest rate swaps	72		74		—		—
TCJA customer refund (f)	37		—		37		—
Other	7		5		3		—
Total noncurrent regulatory liabilities	$	2,747	$	2,704	$	692	$	668

43

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—		—		6
Plant outage costs	6		3		6		3		—		—
Gas supply clause	5		4		5		4		—		—
Total current regulatory assets	$	11	$	18	$	11	$	12	$	—	$	6
Noncurrent Regulatory Assets:
Defined benefit plans	$	366	$	376	$	231	$	234	$	135	$	142
Storm costs	26		33		14		18		12		15
Unamortized loss on debt	24		25		15		16		9		9
Interest rate swaps	21		26		21		26		—		—
Terminated interest rate swaps	89		92		52		54		37		38
AROs	260		234		71		61		189		173
Other	7		9		2		2		5		7
Total noncurrent regulatory assets	$	793	$	795	$	406	$	411	$	387	$	384

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Environmental cost recovery	$	25	$	1	$	14	$	—	$	11	$	1
Fuel adjustment clause	5		3		1		—		4		3
Gas line tracker	2		3		2		3		—		—
TCJA customer refund (c)	33		—		15		—		18		—
Other	6		2		2		—		4		2
Total current regulatory liabilities	$	71	$	9	$	34	$	3	$	37	$	6
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	280	$	282	$	398	395
Power purchase agreement - OVEC (d)	64		68		44		47		20		21
Net deferred taxes (e)	1,206		1,185		561		552		645		633
Defined benefit plans	31		27		—		—		31		27
Terminated interest rate swaps	72		74		36		37		36		37
Other	4		5		1		1		3		4
Total noncurrent regulatory liabilities	$	2,055	$	2,036	$	922	$	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 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.

44

Regulatory Matters

Kentucky Activities

(PPL, LKE, LG&E and KU)

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 full deployment is expected to be completed in 2021 with estimated capital costs of $155 million and $104 million for KU and LG&E electric service and $62 million for LG&E gas service. The full Advanced Metering Systems deployment is expected to result in incremental operation and maintenance costs during the deployment phase of $17 million and $11 million for KU and LG&E electric service and $3 million for LG&E gas service. A hearing on this matter was held July 24, 2018. LG&E and KU cannot predict the outcome of this proceeding.

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. 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. Ongoing tax savings are also expected to be addressed in LG&E's and KU's next Kentucky base rate case. LG&E and KU have indicated their intent to file an application for base rate changes during 2018 to be effective during spring 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. On March 30, 2018, following receipt of the Attorney General's response, the KPSC issued an Order amending its March 28, 2018 Order to allow the parties to raise any relevant issues related to the TCJA. A hearing on this matter was held May 24, 2018. Post-hearing briefs have been filed and the case is now submitted to the KPSC for a decision.

45

LG&E and KU cannot predict the outcome of these proceedings.

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 requesting the KPSC to review and rule upon the recoverability of the franchise fee.

On March 14, 2018, the KPSC issued an order authorizing the franchise fee to be recovered only from LG&E's Louisville/Jefferson County customers in the franchise area. As a result, the franchise fee will continue to be zero in accordance with the 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 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 $37 million relates to the period January 1, 2018 through June 30, 2018 and has been recorded as a noncurrent regulatory liability to be distributed to customers pursuant to a future rate adjustment. The remaining $35 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and will be passed back to customers through the negative surcharge beginning July 1, 2018.

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 Federal Energy Regulatory Commission, to accelerate incorporation of the changes to the federal corporate

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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 joint transmission owners filing, submitted comments in response to the FERC's March 15, 2018 Notice of Inquiry. The filing submitted by the PJM joint transmission owners 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 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 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 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.

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 six months ended June 30, 2018, PPL Electric purchased $297 million and $673 million of accounts receivable from alternate suppliers. During the three and six months ended June 30, 2017, PPL Electric purchased $288 million and $644 million of accounts receivable from alternate suppliers.

8. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and 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:

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	June 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
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2023	£	210	£	150	£	—	£	60	£	148	£	—
Term Loan Facility (b)	Dec. 2018	130		130		—		—		—		—
WPD (South West)
Syndicated Credit Facility	July 2021	245		—		—		245		—		—
WPD (East Midlands)
Syndicated Credit Facility (c)	July 2021	300		99		—		201		180		—
WPD (West Midlands)
Syndicated Credit Facility (d)	July 2021	300		34		—		266		120		—
Uncommitted Credit Facilities		130		—		4		126		—		4
Total U.K. Credit Facilities (e)		£	1,315	£	413	£	4	£	898	£	448	£	4
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2023	$	950	$	—	$	950	$	—	$	—	$	230
Syndicated Credit Facility	Nov. 2018	300		—		49		251		—		—
Bilateral Credit Facility	Mar. 2019	100		—		20		80		—		18
Total PPL Capital Funding Credit Facilities		$	1,350	$	—	$	1,019	$	331	$	—	$	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	$	—	$	183	$	317	$	—	$	199
Term Loan Credit Facility	Oct. 2019	200		200		—		—		100		—
Total LG&E Credit Facilities		$	700	$	200	$	183	$	317	$	100	$	199
KU
Syndicated Credit Facility	Jan. 2023	$	400	$	—	$	133	$	267	$	—	$	45
Letter of Credit Facility	Oct. 2020	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	331	$	267	$	—	$	243

(a) The amounts borrowed at June 30, 2018 and December 31, 2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at 2.81% and 2.17%. The unused capacity reflects the amount borrowed in GBP of £150 million as of the date borrowed.

(b) The amount borrowed at June 30, 2018 was a GBP-denominated borrowing which equated to $173 million and bore interest at 1.75%.

(c) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $132 millionand $244 million and bore interest at 0.90% and 0.89%.

(d) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $45 million and $162 million and bore interest at 0.90% and 0.89%.

(e) At June 30, 2018, the unused capacity under the U.K. credit facilities was $1.2 billion.

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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:

	June 30, 2018							December 31, 2017
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	2.42%	$	1,000	$	999	$	1	1.64%	$	230
PPL Electric		650		—		650			—
LG&E	2.33%	350		183		167		1.83%	199
KU	2.34%	350		133		217		1.97%	45
Total		$	2,350	$	1,315	$	1,035		$	474

(PPL Electric, LKE, and LG&E)

See Note 11 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

In March 2018, WPD (South Wales) issued £30 million of 0.01% Index-linked Senior Notes due 2036. WPD (South Wales) received proceeds of £31 million, which equated to $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 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.

(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 and for general corporate purposes.

(PPL, LKE and LG&E)

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

In May 2018, the County of Trimble, 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.

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.

(PPL, LKE and KU)

In July 2018, KU redeemed, at par, its $9 million County of Trimble, Kentucky, Environmental Facilities Revenue Bonds, 2007 Series A (Kentucky Utilities Company Project) due 2037.

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(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 with 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. Settlement of these forward sale agreements will occur no later than November 2019. Upon any physical settlement 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. PPL will not receive any proceeds or issue any shares of common stock until settlement of the forward sale agreements. PPL intends to use any net proceeds that it receives upon settlement for general corporate purposes.

The forward sale agreements are classified as equity transactions. As a result, no amounts will be recorded in the consolidated financial statements until the settlement of the forward sale agreements. Prior to any settlements, 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.

ATM Program

In February 2018, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $1.0 billion of its common stock through an at-the-market offering program; including a forward sales component. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. PPL issued 1.2 million and 4.2 million shares of common stock and received gross proceeds of $34 million and $119 million for the three and six months ended June 30, 2018.

Distributions

In May 2018, PPL declared a quarterly common stock dividend, payable July 2, 2018, of 41.0 cents per share (equivalent to $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.

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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 its subsidiaries, and LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	15		$	21		$	18		$	31		$	32		$	42		$	37
Interest cost	39			42			47			44			78			84			94			87
Expected return on plan assets	(62		)	(58		)	(150		)	(127		)	(124		)	(115		)	(300		)	(252		)
Amortization of:
Prior service cost	3			3			—			—			5			5			—			—
Actuarial loss	19			14			38			36			41			34			77			71
Net periodic defined benefit costs (credits) before special termination benefits	14			16			(44		)	(29		)	31			40			(87		)	(57		)
Special termination benefits (a)	—			(1		)	—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	14		$	15		$	(44	)	$	(29	)	$	31		$	41		$	(87	)	$	(57	)

(a) 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LKE
Service cost	$	5		$	5		$	12		$	12
Interest cost	16			18			32			34
Expected return on plan assets	(25		)	(24		)	(51		)	(46		)
Amortization of:
Prior service cost	2			2			4			4
Actuarial loss (a)	8			4			18			15
Net periodic defined benefit costs (b)	$	6		$	5		$	15		$	19

(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 $6 million for the three and six months ended June 30, 2018 and $5 million for the six months ended June 30, 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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.

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	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			3			6			6
Expected return on plan assets	(6		)	(6		)	(11		)	(11		)
Amortization of:
Prior service cost	2			1			3			2
Actuarial loss (a)	1			1			3			4
Net periodic defined benefit costs (b)	$	1		$	—		$	2		$	2

(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 six months ended June 30, 2018 and 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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						Six Months
	2018			2017			2018			2017
PPL
Service cost	$	3		$	2		$	4		$	4
Interest cost	7			6			10			12
Expected return on plan assets	(9		)	(5		)	(13		)	(11		)
Amortization of prior service cost	1			(1		)	—			(1		)
Net periodic defined benefit costs	$	2		$	2		$	1		$	4
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			2			4			4
Expected return on plan assets	(2		)	(2		)	(4		)	(3		)
Amortization of:
Prior service cost	1			—			1			—
Actuarial gain	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	1		$	1		$	2		$	3

(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 11 for 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 June 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				Six Months
	2018		2017		2018		2017
PPL Electric	$	3	$	5	$	7	$	13
LG&E	2		2		4		5
KU	1		1		2		5

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(All Registrants)

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

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.

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 alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant, which had three coal-fired units retired in 2015. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In July 2014, the court dismissed the 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 District Court issued an order dismissing PPL as a defendant and dismissing the final federal claim against LG&E. On April 13, 2017, the federal District Court issued an order declining to exercise supplemental jurisdiction on the state law claims and dismissed the case in its entirety. On June 16, 2017, the plaintiffs filed a class action complaint in Jefferson Circuit Court, Kentucky, against LG&E 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 and 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 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 sought injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act 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 sought assessment of civil penalties and an award of litigation costs and attorney fees. On December 28, 2017 the U.S. District Court for the Eastern District of Kentucky 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. KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan, and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. PPL, LKE and KU cannot predict the outcome of these matters and an estimate or range of possible losses cannot be determined.

Regulatory Issues(All Registrants)

See Note 7 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 an estimate or range of possible losses 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 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. 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 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 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. 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 the need for further nitrogen oxide reductions from fossil-fueled plants to address interstate impacts. Although PPL, LKE, LG&E and KU are unable to predict the outcome of ongoing and future evaluations by the EPA and the states, such evaluations could potentially result in requirements for nitrogen oxide reductions beyond those currently required under the 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 nonattainment. In July 2013, the EPA finalized nonattainment designations for parts of the country, including part of Jefferson County in Kentucky. 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.

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 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, the March 2017 Executive Order directed the EPA to review its 2015 greenhouse gas rules 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 Clean Power Plan

There continues to be uncertainty about the EPA's regulation of existing coal-fired power plants. In 2015, the EPA had finalized rules imposing GHG emission standards for both new and existing power plants and had proposed a federal implementation plan that would apply to any states that failed to submit an acceptable state implementation plan to reduce GHG emissions on a state-by-state basis (the 2015 EPA Rules).

Following legal challenges to the 2015 EPA Rules, a stay of those rules by the U.S. Supreme Court and the March 2017 Executive Order requiring the EPA to review the 2015 EPA Rules, in October 2017, the EPA proposed to rescind the 2015 EPA Rules and, in December 2017, released an advanced notice of proposed rulemaking for a replacement (Replacement Rules) which contemplates GHG reductions based on "inside the fence" measures implemented at individual plants. The contemplated approach in the Replacement Rules is a more limited approach than that taken in the 2015 EPA Rules which had included assumed increased levels of fuel switching and renewable energy in determining the level of emission reduction required by each state. At present, the 2015 EPA Rules remain stayed and the Replacement Rules have not yet been published.

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 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 are consistent with the EPA's notice of proposed rulemaking on the Replacement Rules.

LG&E and KU are monitoring developments at the state and federal level. Until there is more clarity about the potential requirements that may be imposed under the Replacement Rules and Kentucky's implementation plan, 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 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.

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.

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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. On March 1, 2018, the EPA proposed amendments to the CCR rule primarily relating to impoundment closure and remediation requirements. On July 18, 2018, the EPA released a pre-publication copy of a signed 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. 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. Revisions to the current rule could potentially result in additional costs.

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 Franklin County, Kentucky Circuit Court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. 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 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 future.

LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. On January 26, 2018, KU filed an application requesting a CPCN and approval of amendments to the second phase of its compliance plan for 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 beginning in 2015 and continue to record adjustments as required. See Note 16 below and Note 19 in the Registrants' 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 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.

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

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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. 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. 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 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 a review of part two later in 2018.

Superfund and Other Remediation

PPL Electric, LG&E and KU are potentially responsible for investigating, responding to agency inquiries, implementing various preventative measures, and/or remediating contamination under programs other than those described in the 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 about such additional sites to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

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.

As of June 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 the paragraph above. 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.

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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 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.

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 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

(LKE and KU)

KU has 68 employees that are represented by the IBEW labor union. Contract negotiations with the IBEW commenced in July 2018. The current three-year agreement, scheduled to expire on August 1, 2018, was extended to August 9, 2018. Although union members voted to reject a recent agreement reached by KU and the IBEW, negotiations are continuing. KU cannot predict the outcome of these negotiations but does not expect the ultimate outcome of this matter, including terms of any potential new agreement, or lack thereof, to have a material impact on KU.

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.

(All Registrants)

The table below details guarantees provided as of June 30, 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." The total recorded liability at June 30, 2018 was $6 million for PPL and not significant for LKE. The total recorded liability at December 31, 2017 was $17 million for PPL and $11 million for LKE. 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.

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	Exposure at June 30, 2018			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2020
WPD guarantee of pension and other obligations of unconsolidated entities	82		(c)
PPL Electric
Guarantee of inventory value	20		(d)	2020
LKE
Indemnification of lease termination and other divestitures	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.

(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 June 30, 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. 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.

(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 $115 million at June 30, 2018, consisting of LG&E's share of $80 million and KU's share of $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 2017 Form 10-K for additional information on the OVEC power purchase contract.

In March 2018, a sponsor with a pro-rata share of certain OVEC obligations of 4.85% filed for bankruptcy under Chapter 11 and is seeking to reject the OVEC power purchase contract, which action OVEC and certain sponsors are contesting. 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.

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PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225 million. This insurance may be applicable to obligations under certain of these contractual arrangements.

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 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 June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of June 30, 2018 was $650 million. No balance was outstanding at June 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread.

(LKE)

LKE maintains a $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. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2018 and December 31, 2017, $99 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at June 30, 2018 and December 31, 2017 were 3.50% and 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 June 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 millionten-year note with a PPL affiliate with an interest rate of 3.5%. At June 30, 2018 and December 31, 2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $3 million and $7 million for the three and six months ending June 30, 2018 and 2017.

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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 May and November. At June 30, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $2 million for the three and six months ending June 30, 2018.

Other(PPL Electric, LG&E and KU)

See Note 9 for discussions regarding intercompany allocations associated with defined benefits.

12. Other Income (Expense) - net

(PPL)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months					Six Months
	2018		2017			2018		2017
Other Income
Economic foreign currency exchange contracts (Note 14)	$	164	$	(113	)	$	52	$	(156	)
Defined benefit plans - non-service credits (Note 9)	66		44			134		82
Interest income	2		—			2		1
AFUDC - equity component	5		4			10		6
Miscellaneous	—		—			1		9
Total Other Income	237		(65		)	199		(58		)
Other Expense
Charitable contributions	1		1			5		5
Miscellaneous	2		2			3		14
Total Other Expense	3		3			8		19
Other Income (Expense) - net	$	234	$	(68	)	$	191	$	(77	)

(PPL Electric)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months				Six Months
	2018		2017		2018		2017
Other Income
AFUDC - equity component	$	5	$	4	$	10	$	6
Defined benefit plans - non-service credits (Note 9)	1		1		3		—
Miscellaneous	1		—		1		—
Total Other Income	7		5		14		6
Other Expense
Charitable contributions	—		—		1		1
Miscellaneous	—		1		—		1
Total Other Expense	—		1		1		2
Other Income (Expense) - net	$	7	$	4	$	13	$	4

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

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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 six months ended June 30, 2018 and 2017, there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's 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:

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	852	$	852	$	—	$	—	$	485	$	485	$	—	$	—
Restricted cash and cash equivalents (a)	23		23		—		—		26		26		—		—
Special use funds (a)	65		65		—		—		—		—		—		—
Price risk management assets (b):
Foreign currency contracts	163		—		163		—		163		—		163		—
Cross-currency swaps	100		—		100		—		101		—		101		—
Total price risk management assets	263		—		263		—		264		—		264		—
Total assets	$	1,203	$	940	$	263	$	—	$	775	$	511	$	264	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Foreign currency contracts	53		—		53		—		148		—		148		—
Total price risk management liabilities	$	74	$	—	$	74	$	—	$	174	$	—	$	174	$	—
PPL Electric
Assets
Cash and cash equivalents	$	489	$	489	$	—	$	—	$	49	$	49	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	491	$	491	$	—	$	—	$	51	$	51	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Total assets	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
LG&E
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—

63

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
KU
Assets
Cash and cash equivalents	$	20	$	20	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	20	$	20	$	—	$	—	$	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.

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 for 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. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.

	June 30, 2018				December 31, 2017
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	20,420	$	23,448	$	20,195	$	23,783
PPL Electric	3,693		3,950		3,298		3,769
LKE	5,510		5,801		5,159		5,670
LG&E	1,808		1,884		1,709		1,865
KU	2,329		2,480		2,328		2,605

(a) Amounts are net of debt issuance costs.

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

14. Derivative Instruments and Hedging Activities

Risk Management Objectives

(All Registrants)

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

Market Risk

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

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

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

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

65

Volumetric Risk

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

• 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 regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 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.

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 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 $28 million obligation to return cash collateral under master netting arrangements at June 30, 2018 and a $20 million obligation to return cash collateral under master netting arrangements at December 31, 2017.

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

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

LKE, LG&E and KU had no cash collateral posted under master netting arrangements at June 30, 2018 and December 31, 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.

66

Interest Rate Risk

(All Registrants)

PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.

Cash Flow Hedges(PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL held no such contracts at June 30, 2018.

For the three and six months ended June 30, 2018 and 2017, PPL had no hedge ineffectiveness associated with interest rate derivatives.

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

For the three and six months ended June 30, 2018 and 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 six months ended June 30, 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At June 30, 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 June 30, 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.

67

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. There were no contracts outstanding at June 30, 2018.

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

Economic Activity

PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings. At June 30, 2018, the total exposure hedged by PPL was approximately £2.0 billion (approximately $2.8 billion based on contracted rates). These contracts have termination dates ranging from July 2018 through 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 7 for amounts recorded in regulatory assets and regulatory liabilities at June 30, 2018 and December 31, 2017.

See Note 1 in each Registrant's 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.

	June 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
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	$	—	$	—	$	—	$	4	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	5		—		—		—		4		—		—		—
Foreign currency contracts	—		—		73		31		—		—		45		67
Total current	5		—		73		35		4		—		45		71
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		17		—		—		—		22
Cross-currency swaps (b)	95		—		—		—		97		—		—		—
Foreign currency contracts	—		—		90		22		—		—		118		81
Total noncurrent	95		—		90		39		97		—		118		103
Total derivatives	$	100	$	—	$	163	$	74	$	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.

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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 June 30, 2018.

							Three Months					Six 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)
	Three Months		Six Months
Cash Flow Hedges:
Interest rate swaps	$	—	$	—		Interest expense	$	(2	)	$	—	$	(4	)	$	—
Cross-currency swaps	23		(1		)	Other income (expense) - net	24			—		12			—
Total	$	23	$	(1	)		$	22		$	—	$	8		$	—
Net Investment Hedges:
Foreign currency contracts	$	12	$	11

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	164		$	52
Interest rate swaps	Interest expense	(2		)	(3		)
	Total	$	162		$	49
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017.

								Three Months					Six 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)
	Three Months			Six Months
Cash Flow Hedges:
Interest rate swaps	$	(2	)	$	(2	)	Interest expense	$	(2	)	$	—	$	(4	)	$	(1	)
Cross-currency swaps	(27		)	(35		)	Interest expense	(1		)	—		—			—
							Other income (expense) - net	(29		)	—		(26		)	—
Total	$	(29	)	$	(37	)		$	(32	)	$	—	$	(30	)	$	(1	)
Net Investment Hedges:
Foreign currency contracts	$	—		$	—

69

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	(113	)	$	(156	)
Interest rate swaps	Interest expense	(1		)	(3		)
	Total	$	(114	)	$	(159	)
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

(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.

	June 30, 2018				December 31, 2017
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	4	$	—	$	4
Total current	—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		17		—		22
Total noncurrent	—		17		—		22
Total derivatives	$	—	$	21	$	—	$	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 June 30, 2018.

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(1	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

(PPL, LKE, LG&E and KU)

Offsetting Derivative Instruments

PPL, LKE, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination

70

of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.

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

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
June 30, 2018
Treasury Derivatives
PPL	$	263	$	43	$	28	$	192	$	74	$	43	$	—	$	31
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

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 June 30, 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:

71

	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	17	$	7	$	7
Aggregate fair value of collateral posted on these derivative instruments	—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	17		7		7

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

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

16. Accumulated Other Comprehensive Income (Loss)

(PPL and LKE)

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

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives					Defined benefit plans
							Equity investees' AOCI		Prior service costs			Actuarial gain (loss)			Total
PPL
March 31, 2018	$	(973	)	$	(21	)	$	—	$	(7	)	$	(2,278	)	$	(3,279	)
Amounts arising during the period	(250		)	19			—		(1		)	—			(232		)
Reclassifications from AOCI	—			(19		)	—		1			34			16
Net OCI during the period	(250		)	—			—		—			34			(216		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—	$	(7	)	$	(2,244	)	$	(3,495	)

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	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives						Defined benefit plans
							Equity investees' AOCI			Prior service costs			Actuarial gain (loss)			Total
December 31, 2017	$	(1,089	)	$	(13	)	$	—		$	(7	)	$	(2,313	)	$	(3,422	)
Amounts arising during the period	(134		)	(1		)	—			(1		)	(1		)	(137		)
Reclassifications from AOCI	—			(7		)	—			1			70			64
Net OCI during the period	(134		)	(8		)	—			—			69			(73		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—		$	(7	)	$	(2,244	)	$	(3,495	)
March 31, 2017	$	(1,651	)	$	(14	)	$	(1	)	$	(8	)	$	(2,103	)	$	(3,777	)
Amounts arising during the period	231			(24		)	—			—			(11		)	196
Reclassifications from AOCI	—			25			1			1			31			58
Net OCI during the period	231			1			1			1			20			254
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
December 31, 2016	$	(1,627	)	$	(7	)	$	(1	)	$	(8	)	$	(2,135	)	$	(3,778	)
Amounts arising during the period	207			(30		)	—			—			(11		)	166
Reclassifications from AOCI	—			24			1			1			63			89
Net OCI during the period	207			(6		)	1			1			52			255
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
LKE
March 31, 2018							$	—		$	(9	)	$	(78	)	$	(87	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							—			1			(1		)	—
Net OCI during the period							—			1			—			1
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
December 31, 2017							$	—		$	(9	)	$	(79	)	$	(88	)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			1			2
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
March 31, 2017							$	—		$	(8	)	$	(60	)	$	(68	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			(10		)	(9		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)
December 31, 2016							$	(1	)	$	(8	)	$	(61	)	$	(70	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							1			1			2			4
Net OCI during the period							1			1			(9		)	(7		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)

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(PPL)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30.

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2018			2017			2018			2017			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(4	)	$	(5	)	Interest Expense
Cross-currency swaps	24			(29		)	12			(26		)	Other Income (Expense) - net
	—			(1		)	—			—			Interest Expense
Total Pre-tax	22			(32		)	8			(31		)
Income Taxes	(3		)	7			(1		)	7
Total After-tax	19			(25		)	7			(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 (a)	(1		)	(1		)	(1		)	(1		)
Net actuarial loss (a)	(43		)	(40		)	(88		)	(81		)
Total Pre-tax	(44		)	(41		)	(89		)	(82		)
Income Taxes	9			9			18			18
Total After-tax	(35		)	(32		)	(71		)	(64		)
Total reclassifications during the period	$	(16	)	$	(58	)	$	(64	)	$	(89	)

(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 Leases

In February 2016, the 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 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. One of these practical expedients allows entities to elect to (1) not reassess whether existing contracts contain leases, (2) carryforward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases. In January 2018, the FASB also issued additional guidance that provides for a practical expedient that allows entities to elect to not evaluate land easements as leases that exist or expired before the adoption date and were not previously accounted for as leases under current lease guidance. The Registrants plan to elect these practical expedients.

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The Registrants are currently assessing the impact of adopting this guidance as well as the transition method they will use. Key implementation activities in process of being completed include finalizing the lease inventory, concluding on open industry issues and identifying and implementing new controls and processes. The Registrants will adopt this guidance effective January 1, 2019.

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. 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 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.

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 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.

(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

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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' 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 six months ended June 30, 2018 with the same periods in 2017. For PPL, "Results of Operations" also includes "Segment Earnings" and "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 "Adjusted Gross Margins" and provide explanations of the non-GAAP financial measures and a reconciliation of the non-GAAP financial measures to the most comparable GAAP measure. The "2018 Outlook" discussion identifies key factors expected to impact 2018 earnings. For PPL Electric, LKE, LG&E and KU, a summary of earnings and 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. PPL Global is not a 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 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 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 operates seven fully regulated, high-performing utilities. These utilities are located in the U.K., Pennsylvania and Kentucky, constructive regulatory jurisdictions with distinct regulatory structures and customer classes. PPL believes this 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 strategy is to deliver best-in-sector operational performance, invest in a sustainable energy future, maintain a strong financial foundation, and engage 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 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.

For the U.S. businesses, central to our strategy is recovering capital project costs efficiently through various rate-making mechanisms, including periodic base rate case proceedings using forward test years, annual FERC formula rate mechanisms and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, 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 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. RAV growth is expected in the U.K. Regulated segment during the RIIO-ED1 price control period, which ends on March 31, 2023, and to result in earnings growth in 2018 through at least 2020. See "Item 1. Business - Segment Information - U.K. Regulated Segment" in PPL's 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 operational efficiency.

Financial and Operational Developments

Equity Forward Contracts (PPL)

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. Settlement of these forward sale agreements will occur no later than November 2019. PPL will not receive any proceeds or issue any shares of common stock until settlement of the forward sale agreements. PPL intends to use any net proceeds that it receives upon settlement for general corporate purposes.

The forward sale agreements are classified as equity transactions. As a result, no amounts will be recorded in the consolidated financial statements until the settlement of the forward sale agreements. Prior to any settlements, 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 8 to the Financial Statements for additional information.

U.S. Tax Reform (All Registrants)

Substantially all of the provisions of the TCJA, signed into law on December 22, 2017, are effective for taxable years beginning after December 31, 2017 and, to the extent such provisions are relevant to the Registrants, their impact has been reflected in the financial results for the three and six months ended June 30, 2018. With respect to the TCJA provisions applicable to the period ended December 31, 2017, although additional guidance has been issued by the U.S. Department of the Treasury and the IRS concerning the application or operation of those provisions, such guidance has not materially impacted the related amounts reported in the Registrants' financial statements for the periods ended June 30, 2018.

On August 1, 2018, the Department of Treasury and the IRS issued proposed regulations under Internal Revenue Code Section 965 to provide guidance relating to the transition tax upon the mandatory deemed repatriation of certain deferred foreign earnings. On August 3, 2018, the Department of Treasury and the IRS also issued proposed regulations on the new 100 percent depreciation deduction effective for assets placed in service after September 27, 2017. The Registrants are currently reviewing the proposed regulations to determine what impact the newly issued guidance may have on their financial statements.

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.

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 reduced tax rate, related to the remeasurement of deferred income taxes, as an increase in regulatory liabilities of $16 million and $19 million. LG&E and KU continue to evaluate other impacts of Kentucky state tax reform along with the associated regulatory considerations. PPL is evaluating the impact, if any, of unitary or elective consolidated income tax reporting on all its Registrants.

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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 the European Parliament, the European Council and by the 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 July 31, 2018, PPL's foreign exchange exposure related to budgeted earnings is 100% hedged for the remainder of 2018 at an average rate of $1.31 per GBP, 100% hedged for 2019 at an average rate of $1.39 per GBP and 50% hedged for 2020 at an average rate of $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)

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. 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. Ongoing tax savings are also expected to be addressed in LG&E's and KU's next Kentucky base rate case. LG&E and KU have indicated their intent to file an application for base rate changes during 2018 to be effective during spring 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

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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. On March 30, 2018, following receipt of the Attorney General's response, the KPSC issued an Order amending its March 28, 2018 Order to allow the parties to raise any relevant issues related to the TCJA. A hearing on this matter was held May 24, 2018. Post-hearing briefs have been filed and the case is now submitted to the KPSC for a decision.

LG&E and KU cannot predict the outcome of these proceedings.

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.

(PPL and PPL Electric)

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 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 $37 million relates to the period January 1, 2018 through June 30, 2018 and has been recorded as a noncurrent regulatory liability to be distributed to customers pursuant to a future rate adjustment. The remaining $35 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and will be passed back to customers through the negative surcharge beginning July 1, 2018.

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 Federal Energy Regulatory Commission, 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,

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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 joint transmission owners filing, submitted comments in response to the FERC's March 15, 2018 Notice of Inquiry. The filing submitted by the PJM joint transmission owners 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.

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.

The actual procedures for approval of a utility's application for alternative rates and rate mechanisms are not set forth in Act 58. Rather, the PUC must prescribe those procedures through a regulation or order within six months of the legislation's effective date.

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 December 2017, Ofgem initiated a consultation on a potential RIIO-ED1 mid-period review (MPR). The RIIO framework allows for an 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 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, 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 the RIIO-2 framework 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 a low-carbon future. Comments on the RIIO-2 framework were due in May 2018. On July 30, 2018, Ofgem published its decision following their RIIO-2 framework consultation after consideration of comments received. Ofgem confirmed the following points in the decision document:

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• 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. 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 made in the sector specific consultations or within the individual company business plan submissions. The promulgation of sector specific price controls 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. 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.

(PPL, LKE, LG&E and KU)

The businesses of LKE, LG&E and KU are subject to extensive federal, state and local environmental laws, rules and regulations, including those pertaining to CCRs, GHGs and ELGs. See Note 10 to the Financial Statements for a discussion of the other significant environmental matters.

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 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 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 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 (LKE and KU)

In September 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%. On March 22, 2018, KU reached a settlement agreement regarding the case, including the impact of the TCJA on rates, resulting in an increase in annual Virginia base electricity revenue by $2 million. This represents an increase of 2.8% with rates effective June 1, 2018. On May 8, 2018, the VSCC issued an order approving the settlement agreement.

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Acquisition of Solar Energy Solution Provider (PPL)

During the second quarter of 2018, PPL completed the acquisition of all the outstanding membership interests of Safari Energy, LLC (Safari Energy), a 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 financial results of Safari Energy will be reported within Corporate and 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 six months ended June 30, 2018 with the same periods in 2017. The "Segment Earnings" and "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 "Adjusted Gross Margins," and provide explanations of the non-GAAP financial measures and a reconciliation of those measures to the most comparable GAAP measure. The "2018 Outlook" discussion identifies key factors expected to impact 2018 earnings.

Tables analyzing changes in amounts between periods within "Statement of Income Analysis," "Segment Earnings" and "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.

(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 six months ended June 30, 2018 with the same periods in 2017. The "Earnings" discussion provides a summary of earnings. The "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 June 30 includes the following results.

	Three Months							Six Months
	2018		2017			$ Change		2018		2017			$ Change
Operating Revenues	$	1,848	$	1,725		$	123	$	3,974	$	3,676		$	298
Operating Expenses
Operation
Fuel	189		183			6		403		374			29
Energy purchases	148		136			12		389		351			38
Other operation and maintenance	506		432			74		974		902			72
Depreciation	273		246			27		542		488			54
Taxes, other than income	74		70			4		157		145			12
Total Operating Expenses	1,190		1,067			123		2,465		2,260			205
Other Income (Expense) - net	234		(68		)	302		191		(77		)	268
Interest Expense	235		222			13		474		439			35
Income Taxes	142		76			66		259		205			54
Net Income	$	515	$	292		$	223	$	967	$	695		$	272

Operating Revenues

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

	Three Months			Six Months
Domestic:
PPL Electric Distribution price	$	10		$	11
PPL Electric Distribution volume	12			32
PPL Electric PLR Revenue (a)	9			26
PPL Electric Transmission Formula Rate	22			50
PPL Electric TCJA refund (b)	(37		)	(37		)
LKE Volumes (c)	36			103
LKE Base rates	28			58
LKE ECR	6			13
LKE TCJA refund (b)	(37		)	(79		)
LKE DSM	(3		)	(11		)
LKE Fuel and other energy prices	(9		)	(7		)
Other	4			10
Total Domestic	41			169
U.K.:
Price	10			—
Volume	12			4
Foreign currency exchange rates	51			109
Engineering recharge income	11			19
Other	(2		)	(3		)
Total U.K.	82			129
Total	$	123		$	298

(a) The increases were primarily due to higher energy volumes.

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(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.

(c) The increases were primarily due to favorable weather in 2018.

Fuel

Fuel increased $6 million and $29 million for the three and six months endedJune 30, 2018 compared with 2017, primarily due to an increase in volumes driven by weather in 2018.

Energy Purchases

Energy purchases increased $12 million for the three months ended June 30, 2018 compared with 2017, primarily due to an increase in PLR volumes at PPL Electric.

Energy purchases increased $38 million for the six months endedJune 30, 2018 compared with 2017, primarily due to a $23 million increase in PLR volumes at PPL Electric and a $23 million increase in natural gas volumes at LG&E driven by weather in 2018, partially offset by a $10 million decrease in market prices for natural gas at LG&E.

Other Operation and Maintenance

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

	Three Months			Six Months
Domestic:
LKE timing and scope of generation maintenance outages	$	6		$	7
LKE vegetation management	3			3
LKE gas distribution maintenance and compliance	2			3
LKE storm costs	2			2
PPL Electric vegetation management	(5		)	(10		)
PPL Electric storm costs	12			16
PPL Electric payroll-related costs	(1		)	(14		)
PPL Electric Act 129	1			(2		)
PPL Electric bad debts	4			7
PPL Electric smart meter	2			4
PPL Electric contractor-related expenses	2			—
Other	19			7
U.K.:
Foreign currency exchange rates	10			21
Network maintenance	2			4
Third-party engineering	10			16
Other	5			8
Total	$	74		$	72

Depreciation

Depreciation increased $27 million and $54 million for the three and six months ended June 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 and 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 additions, net of retirements at LG&E and KU and the impact of foreign currency exchange rates at WPD.

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Other Income (Expense) - net

Other income (expense) - net increased $302 million for the three months ended June 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 $277 million and an increase in non-service cost credits from defined benefit plans of $22 million.

Other income (expense) - net increased $268 million for the six months ended June 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 $208 million and an increase in non-service cost credits from defined benefit plans of $52 million.

Interest Expense

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

	Three Months		Six Months
Long-term debt interest expense	$	4	$	16
Foreign currency exchange rates	8		17
Other	1		2
Total	$	13	$	35

Income Taxes 

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

	Three Months			Six Months
Change in pre-tax income	$	99		$	108
Reduction in U.S. federal income tax rate (a)	(56		)	(88		)
Valuation allowances adjustments	5			7
U.S. income tax on foreign earnings - net of foreign tax credit (b)	7			17
Federal and state tax reserve adjustments	3			3
Impact of U.K. Finance Acts	4			6
Amortization of excess deferred income taxes (a)	(9		)	(19		)
Kentucky state tax reform (c)	9			9
Stock-based compensation	4			8
Other	—			3
Total	$	66		$	54

(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.

(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 was recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

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

Segment Earnings

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

	Three Months									Six Months
	2018			2017			$ Change			2018			2017			$ Change
U.K. Regulated	$	394		$	148		$	246		$	591		$	434		$	157
Kentucky Regulated	77			79			(2		)	210			174			36
Pennsylvania Regulated	75			77			(2		)	223			156			67
Corporate and Other (a)	(31		)	(12		)	(19		)	(57		)	(69		)	12
Net Income	$	515		$	292		$	223		$	967		$	695		$	272

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(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 change in 2018 compared with 2017 is primarily due to the utilization of an estimated tax rate, which required tax benefits realized in the first quarter of 2017 to be recognized over the annual period.

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:

• 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.

• 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 14 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 June 30 were as follows:

	Three Months									Six Months
	2018			2017			$ Change			2018			2017			$ Change
U.K. Regulated	$	254		$	212		$	42		$	516		$	519		$	(3	)
Kentucky Regulated	86			79			7			219			175			44
Pennsylvania Regulated	75			77			(2		)	223			156			67
Corporate and Other	(31		)	(12		)	(19		)	(57		)	(69		)	12
Earnings from Ongoing Operations	$	384		$	356		$	28		$	901		$	781		$	120

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 61% of PPL's Net Income for the six months ended June 30, 2018 and 39% of PPL's assets at June 30, 2018.

Net Income and Earnings from Ongoing Operations for the periods ended June 30 include the following results.

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	Three Months							Six Months
	2018		2017			$ Change		2018		2017			$ Change
Operating revenues	$	584	$	502		$	82	$	1,199	$	1,070		$	129
Other operation and maintenance	137		106			31		269		213			56
Depreciation	63		57			6		125		112			13
Taxes, other than income	34		30			4		68		61			7
Total operating expenses	234		193			41		462		386			76
Other Income (Expense) - net	229		(69		)	298		182		(69		)	251
Interest Expense	97		97			—		204		191			13
Income Taxes	88		(5		)	93		124		(10		)	134
Net Income	394		148			246		591		434			157
Less: Special Items	140		(64		)	204		75		(85		)	160
Earnings from Ongoing Operations	$	254	$	212		$	42	$	516	$	519		$	(3	)

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 June 30.

	Income Statement Line Item	Three Months					Six Months
		2018		2017			2018		2017
Foreign currency economic hedges, net of tax of ($37), $34, ($20), $46 (a)	Other Income (Expense) - net	$	140	$	(64	)	$	75	$	(85	)
Total Special Items		$	140	$	(64	)	$	75	$	(85	)

(a) Represents unrealized gains (losses) on contracts that economically hedge anticipated GBP-denominated earnings.

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			Six Months
U.K.
U.K. Adjusted Gross Margins	$	22		$	5
Other operation and maintenance	(7		)	(11		)
Depreciation	(1		)	(2		)
Other Income (Expense) - net	15			31
Interest expense	8			3
Other	—			(3		)
Income taxes	(13		)	(17		)
U.S.
Interest expense and other	(3		)	(3		)
Income taxes	(4		)	(46		)
Foreign currency exchange, after-tax	25			40
Earnings from Ongoing Operations	42			(3		)
Special items, after-tax	204			160
Net Income	$	246		$	157

U.K.

• See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of U.K. Adjusted Gross Margins.

• Higher other income (expense) - net for the three and six month periods primarily from higher pension income due to an increase in expected returns on higher asset balances.

• Higher income taxes for the three month period primarily due to higher pre-tax income.

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U.S.

• Higher income taxes for the six month period primarily due to a $35 million tax benefit on accelerated pension contributions in the first quarter of 2017 and a $12 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 22% of PPL's Net Income for the six months endedJune 30, 2018 and 34% of PPL's assets at June 30, 2018.

Net Income and Earnings from Ongoing Operations for the periods ended June 30 include the following results.

	Three Months									Six Months
	2018			2017			$ Change			2018			2017			$ Change
Operating revenues	$	743		$	723		$	20		$	1,615		$	1,532		$	83
Fuel	189			183			6			403			374			29
Energy purchases	33			29			4			113			98			15
Other operation and maintenance	211			192			19			416			397			19
Depreciation	118			105			13			235			210			25
Taxes, other than income	18			16			2			35			32			3
Total operating expenses	569			525			44			1,202			1,111			91
Other Income (Expense) - net	1			(4		)	5			(2		)	(8		)	6
Interest Expense	69			66			3			136			131			5
Income Taxes	29			49			(20		)	65			108			(43		)
Net Income	77			79			(2		)	210			174			36
Less: Special Items	(9		)	—			(9		)	(9		)	(1		)	(8		)
Earnings from Ongoing Operations	$	86		$	79		$	7		$	219		$	175		$	44

The following after-tax gains (losses), which management considers special items, impacted the Kentucky Regulated segment's results and are excluded from Earnings from Ongoing Operations during the periods ended June 30.

	Income Statement Line Item	Three Months					Six Months
		2018			2017		2018			2017
Adjustment to investment, net of tax of $0, $0, $0, $0 (a)	Other Income (Expense) - net	$	—		$	—	$	—		$	(1	)
Kentucky state tax reform (b)	Income Taxes	(9		)	—		(9		)	—
Total Special Items		$	(9	)	$	—	$	(9	)	$	(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.

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 that management considers special on separate lines and not in their respective Statement of Income line items.

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	Three Months			Six Months
Kentucky Adjusted Gross Margins	$	15		$	43
Other operation and maintenance	(22		)	(23		)
Depreciation	(12		)	(23		)
Taxes, other than income	(5		)	(5		)
Other Income (Expense) - net	5			5
Interest Expense	(3		)	(5		)
Income Taxes	29			52
Earnings from Ongoing Operations	7			44
Special items, after-tax	(9		)	(8		)
Net Income	$	(2	)	$	36

• 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 a $6 million increase in costs related to the timing and scope of generation maintenance outages and increases in other costs that were not individually significant in comparison to the prior year.

• Higher other operation and maintenance expense for the six month period primarily due to a $7 million increase in costs related to the timing and scope of generation maintenance outages and increases in other costs that were not individually significant in comparison to the prior year.

• Higher depreciation expense for the three month period due to a $7 million increase related to higher depreciation rates effective July 1, 2017 and a $5 million increase related to additions to PP&E, net of retirements.

• Higher depreciation expense for the six month period due to a $12 million increase related to higher depreciation rates effective July 1, 2017 and an $11 million increase related to additions to PP&E, net of retirements.

• Lower income taxes for the three month period primarily due to a $16 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 $9 million decrease related to lower pre-tax income and a $6 million decrease related to higher amortization of excess deferred income taxes as a result of the TCJA.

• Lower income taxes for the six month period primarily due to a $42 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, and an $11 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 23% of PPL's Net Income for the six months endedJune 30, 2018 and 26% of PPL's assets at June 30, 2018.

Net Income and Earnings from Ongoing Operations for the periods ended June 30 include the following results.

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	Three Months							Six Months
	2018		2017		$ Change			2018		2017		$ Change
Operating revenues	$	517	$	500	$	17		$	1,156	$	1,073	$	83
Energy purchases	115		107		8			276		253		23
Other operation and maintenance	159		140		19			292		303		(11		)
Depreciation	88		76		12			173		151		22
Taxes, other than income	22		23		(1		)	54		52		2
Total operating expenses	384		346		38			795		759		36
Other Income (Expense) - net	8		6		2			14		6		8
Interest Expense	39		36		3			76		69		7
Income Taxes	27		47		(20		)	76		95		(19		)
Net Income	75		77		(2		)	223		156		67
Less: Special Items (a)	—		—		—			—		—		—
Earnings from Ongoing Operations	$	75	$	77	$	(2	)	$	223	$	156	$	67

(a) There are no items that management considers special for the periods presented.

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 on a separate line and not in their respective Statement of Income line items.

	Three Months			Six Months
Pennsylvania Adjusted Gross Margins	$	(5	)	$	43
Other operation and maintenance	(7		)	20
Depreciation	(9		)	(15		)
Taxes, other than income	—			(1		)
Other Income (Expense) - net	2			8
Interest Expense	(3		)	(7		)
Income Taxes	20			19
Net Income	$	(2	)	$	67

• See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Pennsylvania Adjusted Gross Margins.

• Higher other operation and maintenance expense for the three month period primarily due to $5 million of nonrecoverable storm expenses and $4 million of higher bad debt expenses, partially offset by $5 million of lower vegetation management expenses.

• Lower other operation and maintenance expense for the six month period primarily due to $17 million of lower corporate service costs allocated to PPL Electric, $14 million of lower payroll related expenses and $10 million of lower vegetation management expenses, partially offset by $12 million of nonrecoverable storm expenses and $7 million of higher bad debt expenses.

• Higher depreciation expense for the three and six month periods 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, net of retirements.

• 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 $13 million and lower pre-tax income resulting in $9 million of lower income taxes.

• Lower income taxes for the six 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 $38 million, partially offset by higher pre-tax income resulting in $20 million of higher income taxes.

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Reconciliation of Earnings from Ongoing Operations

The following tables contain after-tax gains (losses), in total, which management considers special items, that are excluded from Earnings from Ongoing Operations and a reconciliation to PPL's "Net Income" for the periods ended June 30.

	2018 Three Months
	U.K. Regulated			KY Regulated			PA Regulated		Corporate and Other			Total
Net Income	$	394		$	77		$	75	$	(31	)	$	515
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($37)	140			—			—		—			140
Kentucky state tax reform	—			(9		)	—		—			(9		)
Total Special Items	140			(9		)	—		—			131
Earnings from Ongoing Operations	$	254		$	86		$	75	$	(31	)	$	384
	2017 Three Months
	U.K. Regulated			KY Regulated			PA Regulated		Corporate and Other			Total
Net Income	$	148		$	79		$	77	$	(12	)	$	292
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $34	(64		)	—			—		—			(64		)
Total Special Items	(64		)	—			—		—			(64		)
Earnings from Ongoing Operations	$	212		$	79		$	77	$	(12	)	$	356
	2018 Six Months
	U.K. Regulated			KY Regulated			PA Regulated		Corporate and Other			Total
Net Income	$	591		$	210		$	223	$	(57	)	$	967
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($20)	75			—			—		—			75
Kentucky state tax reform	—			(9		)	—		—			(9		)
Total Special Items	75			(9		)	—		—			66
Earnings from Ongoing Operations	$	516		$	219		$	223	$	(57	)	$	901
	2017 Six Months
	U.K. Regulated			KY Regulated			PA Regulated		Corporate and Other			Total
Net Income	$	434		$	174		$	156	$	(69	)	$	695
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of $46	(85		)	—			—		—			(85		)
Adjustment to investment, net of tax of $0	—			(1		)	—		—			(1		)
Total Special Items	(85		)	(1		)	—		—			(86		)
Earnings from Ongoing Operations	$	519		$	175		$	156	$	(69	)	$	781

Adjusted Gross Margins

Management also utilizes the following non-GAAP financial measures as indicators of performance for its businesses:

• "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

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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 June 30 as well as the change between periods. The factors that gave rise to the changes are described following the table.

	Three Months							Six Months
	2018		2017		$ Change			2018		2017		$ Change
U.K. Regulated
U.K. Adjusted Gross Margins	$	538	$	469	$	69		$	1,111	$	1,005	$	106
Impact of changes in foreign currency exchange rates					47							101
U.K. Adjusted Gross Margins excluding impact of foreign currency exchange rates					$	22						$	5
Kentucky Regulated
Kentucky Adjusted Gross Margins
LG&E	$	216	$	207	$	9		$	457	$	433	$	24
KU	265		259		6			559		540		19
Total Kentucky Adjusted Gross Margins	$	481	$	466	$	15		$	1,016	$	973	$	43
Pennsylvania Regulated
Pennsylvania Adjusted Gross Margins
Distribution	$	192	$	219	$	(27	)	$	470	$	477	$	(7	)
Transmission	137		115		22			273		223		50
Total Pennsylvania Adjusted Gross Margins	$	329	$	334	$	(5	)	$	743	$	700	$	43

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U.K. Adjusted Gross Margins

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased for the three months ended June 30, 2018 compared with 2017, primarily due to $10 million from the April 1, 2018 price increase and $12 million of higher volumes.

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased for the six months ended June 30, 2018 compared with 2017, primarily due to $10 million from the April 1, 2018 price increase and $4 million of higher volumes, partially offset by $10 million from the April 1, 2017 price decrease, driven by lower true-up mechanisms partially offset by higher base demand revenue.

Kentucky Adjusted Gross Margins

Kentucky Adjusted Gross Margins increased for the three months ended June 30, 2018 compared with 2017, primarily due to higher base rates of $28 million ($15 million at LG&E and $13 million at KU) as new base rates were approved by the KPSC effective July 1, 2017, $20 million of increased sales volumes related to favorable weather in 2018 ($8 million at LG&E and $12 million at KU) and returns on additional environmental capital investments of $5 million ($3 million at LG&E and $2 million at KU), partially offset by $37 million of estimated income tax savings owed to customers ($17 million at LG&E and $20 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 Adjusted Gross Margins increased for the six months ended June 30, 2018 compared with 2017, primarily due to higher base rates of $58 million ($32 million at LG&E and $26 million at KU) as new base rates were approved by the KPSC effective July 1, 2017, $51 million of increased sales volumes related to favorable weather in 2018 ($16 million at LG&E and $35 million at KU) and returns on additional environmental capital investments of $10 million ($6 million at LG&E and $4 million at KU), partially offset by $79 million of estimated income tax savings owed to customers ($37 million at LG&E and $42 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.

Pennsylvania Adjusted Gross Margins

Distribution

Distribution Adjusted Gross Margins decreased for the three months ended June 30, 2018 compared with 2017, primarily due to the $34 million net of gross receipts tax impact of the estimated income tax savings owed to customers as a result 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 $7 million of higher electricity sales volumes and $2 million of returns on additional Smart Meter capital investments.

Distribution Adjusted Gross Margins decreased for the six months ended June 30, 2018 compared with 2017, primarily due to the $34 million net of gross receipts tax impact of the estimated income tax savings owed to customers 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, effective January 1, 2018, partially offset by $25 million of higher electricity sales volumes and $5 million of returns on additional Smart Meter capital investments.

Transmission

Transmission Adjusted Gross Margins increased for the three months ended June 30, 2018 compared with 2017, primarily due to increases of $17 million from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability and $5 million as a result of a higher PPL zonal peak load billing factor which affected transmission revenues in the second quarter of 2018.

Transmission Adjusted Gross Margins increased for the six months ended June 30, 2018 compared with 2017, primarily due to an increase of $39 million from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability and $11 million as a result of a higher PPL zonal peak load billing factor in the first five months of 2018.

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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 June 30.

	2018 Three Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	574	(c)	$	743	$	517	$	14		$	1,848
Operating Expenses
Fuel	—			189		—		—			189
Energy purchases	—			33		115		—			148
Other operation and maintenance	36			23		43		404			506
Depreciation	—			17		8		248			273
Taxes, other than income	—			—		22		52			74
Total Operating Expenses	36			262		188		704			1,190
Total	$	538		$	481	$	329	$	(690	)	$	658
	2017 Three Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	491	(c)	$	723	$	500	$	11		$	1,725
Operating Expenses
Fuel	—			183		—		—			183
Energy purchases	—			29		107		—			136
Other operation and maintenance	22			26		31		353			432
Depreciation	—			16		5		225			246
Taxes, other than income	—			3		23		44			70
Total Operating Expenses	22			257		166		622			1,067
Total	$	469		$	466	$	334	$	(611	)	$	658
	2018 Six Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,179	(c)	$	1,615	$	1,156	$	24		$	3,974
Operating Expenses
Fuel	—			403		—		—			403
Energy purchases	—			113		276		—			389
Other operation and maintenance	68			48		69		789			974
Depreciation	—			34		16		492			542
Taxes, other than income	—			1		52		104			157
Total Operating Expenses	68			599		413		1,385			2,465
Total	$	1,111		$	1,016	$	743	$	(1,361	)	$	1,509

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	2017 Six Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,050	(c)	$	1,532	$	1,073	$	21		$	3,676
Operating Expenses
Fuel	—			374		—		—			374
Energy purchases	—			98		253		—			351
Other operation and maintenance	45			52		60		745			902
Depreciation	—			32		9		447			488
Taxes, other than income	—			3		51		91			145
Total Operating Expenses	45			559		373		1,283			2,260
Total	$	1,005		$	973	$	700	$	(1,262	)	$	1,416

(a) Represents amounts excluded from Adjusted Gross Margins.

(b) As reported on the Statements of Income.

(c) Excludes ancillary revenues of $10 million and $20 million for the three and six months ended June 30, 2018 and $11 million and $20 million for the three and six months ended June 30, 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)

Higher net income is projected in 2018 compared with 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 by higher assumed GBP exchange rates and higher pension income, partially offset by higher taxes.

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

Higher net income is projected in 2018 compared with 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 relatively flat, driven by favorable weather and higher base electricity and gas rates effective July 1, 2017, offset by higher operation and maintenance expense, higher depreciation expense, higher interest expense and a lower tax shield on holding company interest and expenses.

(PPL's Pennsylvania Regulated Segment and PPL Electric)

Higher net income is projected in 2018 compared with 2017, primarily driven by higher transmission earnings, partially offset by higher depreciation expense and higher interest expense.

(PPL's Corporate and Other Category)

Lower costs are projected in 2018 compared with 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 7 and 10 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' 2017 Form 10-K for a discussion of the risks, uncertainties and factors that may impact future earnings.

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

Statement of Income Analysis

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

	Three Months							Six Months
	2018		2017		$ Change			2018		2017		$ Change
Operating Revenues	$	517	$	500	$	17		$	1,156	$	1,073	$	83
Operating Expenses
Operation
Energy purchases	115		107		8			276		253		23
Other operation and maintenance	159		139		20			292		302		(10		)
Depreciation	88		76		12			173		151		22
Taxes, other than income	22		23		(1		)	54		52		2
Total Operating Expenses	384		345		39			795		758		37
Other Income (Expense) - net	7		4		3			13		4		9
Interest Income from Affiliate	1		1		—			1		1		—
Interest Expense	39		36		3			76		69		7
Income Taxes	27		47		(20		)	76		95		(19		)
Net Income	$	75	$	77	$	(2	)	$	223	$	156	$	67

Operating Revenues

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

	Three Months			Six Months
Distribution price	$	10		$	11
Distribution volume	12			32
PLR (a)	9			26
Transmission Formula Rate	22			50
TCJA refund (b)	(37		)	(37		)
Other	1			1
Total	$	17		$	83

(a) The increases were primarily due to higher energy volumes as described below.

(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.

Energy Purchases

Energy purchases increased $8 million and $23 million for the three and six months ended June 30, 2018 compared with 2017, primarily due to higher PLR volumes.

Other Operation and Maintenance

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

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	Three Months			Six Months
Corporate service costs	$	(1	)	$	(17	)
Vegetation management	(5		)	(10		)
Storm costs	12			16
Payroll-related costs	(1		)	(14		)
Act 129	1			(2		)
Bad debts	4			7
Smart Meter	2			4
Contractor-related expenses	2			—
Other	6			6
Total	$	20		$	(10	)

Depreciation

Depreciation increased $12 million and $22 million for the three and six months ended June 30, 2018 compared with 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 $9 million for the six months ended June 30, 2018 compared with 2017, primarily due to a $4 million increase related to higher AFUDC equity rates and a $3 million increase in non-service cost credits from defined benefit plans.

Interest Expense

Interest expense increased $3 million and $7 million for the three and six months ended June 30, 2018 compared with 2017, primarily due to the May 2017 issuance of $475 million of 3.950% First Mortgage Bonds due 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 June 30, 2018 compared with 2017 was due to:

	Three Months			Six Months
Change in pre-tax income	$	(9	)	$	20
Reduction in U.S. federal income tax rate (a)	(13		)	(38		)
Amortization of excess deferred income taxes (a)	(3		)	(8		)
Stock-based compensation	3			5
Other	2			2
Total	$	(20	)	$	(19	)

(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				Six Months Ended
	June 30,				June 30,
	2018		2017		2018		2017
Net Income	$	75	$	77	$	223	$	156
Special items, gains (losses), after-tax (a)	—		—		—		—

(a) There are no items that management considers special for the periods presented.

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Earnings were flat for the three month period in 2018 compared with 2017, driven primarily by returns on additional capital investments in transmission, offset by higher operation and maintenance expense and higher depreciation expense.

Earnings increased for the six month period in 2018 compared with 2017, driven primarily by returns on additional capital investments in transmission, higher distribution sales volumes and lower operation and maintenance expense, partially offset by higher depreciation expense.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Pennsylvania Adjusted Gross Margins on a separate line and not in their respective Statement of Income line items.

	Three Months			Six Months
Pennsylvania Adjusted Gross Margins	$	(5	)	$	43
Other operation and maintenance	(8		)	19
Depreciation	(9		)	(15		)
Taxes, other than income	—			(1		)
Other Income (Expense) - net	3			9
Interest Expense	(3		)	(7		)
Income Taxes	20			19
Net Income	$	(2	)	$	67

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 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 June 30. 

	2018 Three Months							2017 Three Months
	PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	517	$	—		$	517	$	500	$	—		$	500
Operating Expenses
Energy purchases	115		—			115		107		—			107
Other operation and maintenance	43		116			159		31		108			139
Depreciation	8		80			88		5		71			76
Taxes, other than income	22		—			22		23		—			23
Total Operating Expenses	188		196			384		166		179			345
Total	$	329	$	(196	)	$	133	$	334	$	(179	)	$	155
	2018 Six Months							2017 Six Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,156	$	—		$	1,156	$	1,073	$	—		$	1,073
Operating Expenses
Energy purchases	276		—			276		253		—			253
Other operation and maintenance	69		223			292		60		242			302
Depreciation	16		157			173		9		142			151
Taxes, other than income	52		2			54		51		1			52
Total Operating Expenses	413		382			795		373		385			758
Total	$	743	$	(382	)	$	361	$	700	$	(385	)	$	315

(a) Represents amounts excluded from Adjusted Gross Margins.

(b) As reported on the Statements of Income.

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LKE: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

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

	Three Months								Six Months
	2018		2017			$ Change			2018			2017			$ Change
Operating Revenues	$	743	$	723		$	20		$	1,615		$	1,532		$	83
Operating Expenses
Operation
Fuel	189		183			6			403			374			29
Energy purchases	33		29			4			113			98			15
Other operation and maintenance	211		192			19			416			397			19
Depreciation	118		105			13			235			210			25
Taxes, other than income	18		16			2			35			32			3
Total Operating Expenses	569		525			44			1,202			1,111			91
Other Income (Expense) - net	1		(4		)	5			(2		)	(8		)	6
Interest Expense	52		50			2			102			99			3
Interest Expense with Affiliate	6		4			2			11			8			3
Income Taxes	31		53			(22		)	70			116			(46		)
Net Income	$	86	$	87		$	(1	)	$	228		$	190		$	38

Operating Revenues

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

	Three Months			Six Months
Volumes (a)	$	36		$	103
Base rates	28			58
ECR	6			13
TCJA refund (b)	(37		)	(79		)
DSM	(3		)	(11		)
Fuel and other energy prices	(9		)	(7		)
Other	(1		)	6
Total	$	20		$	83

(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 increased $6 million and $29 million for the three and six months endedJune 30, 2018 compared with 2017, primarily due to an increase in volumes driven by weather in 2018.

Energy Purchases

Energy purchases increased $15 million for the six months endedJune 30, 2018 compared with 2017, primarily due to a $23 million increase in natural gas volumes driven by weather in 2018, partially offset by a $10 million decrease in market prices for natural gas.

102

Other Operation and Maintenance

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

	Three Months		Six Months
Timing and scope of generation maintenance outages	$	6	$	7
Vegetation management	3		3
Gas distribution maintenance and compliance	2		3
Storm costs	2		2
Other	6		4
Total	$	19	$	19

Depreciation

Depreciation increased $13 million for the three months ended June 30, 2018 compared with 2017, primarily due to an $8 million increase related to higher depreciation rates effective July 1, 2017 and a $4 million increase related to additions to PP&E, net of retirements.

Depreciation increased $25 million for the six months endedJune 30, 2018 compared with 2017, primarily due to a $15 million increase related to higher depreciation rates effective July 1, 2017 and a $9 million increase related to additions to PP&E, net of retirements.

Income Taxes

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

	Three Months			Six Months
Reduction in U.S. federal income tax rate (a)	$	(16	)	$	(42	)
Amortization of excess deferred income taxes (a)	(6		)	(11		)
Change in pre-tax income	(9		)	(3		)
Kentucky state tax reform (b)	9			9
Other	—			1
Total	$	(22	)	$	(46	)

(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					Six Months Ended
	June 30,					June 30,
	2018			2017		2018			2017
Net Income	$	86		$	87	$	228		$	190
Special items, gains (losses), after-tax	(9		)	—		(9		)	(1		)

Excluding special items, earnings increased for the three and six month period in 2018 compared with 2017, primarily due to higher base electricity and gas rates effective July 1, 2017 and higher sales volumes driven by favorable weather, partially offset by higher other operation and maintenance expense 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 and items that management considers special on separate lines and not in their respective Statement of Income line items.  

103

	Three Months			Six Months
Adjusted Gross Margins	$	15		$	43
Other operation and maintenance	(22		)	(23		)
Depreciation	(12		)	(23		)
Taxes, other than income	(5		)	(5		)
Other Income (Expense) - net	5			5
Interest Expense	(4		)	(6		)
Income Taxes	31			55
Special items, gains (losses), after-tax (a)	(9		)	(8		)
Net Income	$	(1	)	$	38

(a) See PPL's "Results of Operations - Segment Earnings - Kentucky Regulated Segment" for details of the special 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."

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 June 30.

	2018 Three Months							2017 Three Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	743	$	—		$	743	$	723	$	—		$	723
Operating Expenses
Fuel	189		—			189		183		—			183
Energy purchases	33		—			33		29		—			29
Other operation and maintenance	23		188			211		26		166			192
Depreciation	17		101			118		16		89			105
Taxes, other than income	—		18			18		3		13			16
Total Operating Expenses	262		307			569		257		268			525
Total	$	481	$	(307	)	$	174	$	466	$	(268	)	$	198
	2018 Six Months							2017 Six Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,615	$	—		$	1,615	$	1,532	$	—		$	1,532
Operating Expenses
Fuel	403		—			403		374		—			374
Energy purchases	113		—			113		98		—			98
Other operation and maintenance	48		368			416		52		345			397
Depreciation	34		201			235		32		178			210
Taxes, other than income	1		34			35		3		29			32
Total Operating Expenses	599		603			1,202		559		552			1,111
Total	$	1,016	$	(603	)	$	413	$	973	$	(552	)	$	421

(a) Represents amounts excluded from Adjusted Gross Margins.

(b) As reported on the Statements of Income.

104

LG&E: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

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

	Three Months								Six Months
	2018			2017		$ Change			2018			2017			$ Change
Operating Revenues
Retail and wholesale	$	331		$	320	$	11		$	738		$	694		$	44
Electric revenue from affiliate	4			4		—			16			21			(5		)
Total Operating Revenues	335			324		11			754			715			39
Operating Expenses
Operation
Fuel	72			69		3			151			149			2
Energy purchases	28			25		3			104			89			15
Energy purchases from affiliate	2			3		(1		)	8			5			3
Other operation and maintenance	93			86		7			182			171			11
Depreciation	49			45		4			97			89			8
Taxes, other than income	9			9		—			18			17			1
Total Operating Expenses	253			237		16			560			520			40
Other Income (Expense) - net	(1		)	1		(2		)	(2		)	(3		)	1
Interest Expense	19			19		—			37			36			1
Income Taxes	12			27		(15		)	33			60			(27		)
Net Income	$	50		$	42	$	8		$	122		$	96		$	26

Operating Revenues

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

	Three Months			Six Months
Volumes (a)	$	16		$	44
Base rates	16			32
ECR	2			7
TCJA refund (b)	(17		)	(37		)
Fuel and other energy prices	(7		)	(10		)
DSM	(1		)	(5		)
Other	2			8
Total	$	11		$	39

(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 increased $3 million for the three months endedJune 30, 2018 compared with 2017, primarily due to an increase in volumes driven by weather in 2018.

105

Energy Purchases

Energy purchases increased $3 million for the three months ended June 30, 2018 compared with 2017, primarily due to an increase in natural gas volumes driven by weather in 2018.

Energy purchases increased $15 million for the six months ended June 30, 2018 compared with 2017, primarily due to a $23 million increase in natural gas volumes driven by weather in 2018, partially offset by a $10 million decrease in market prices for natural gas.

Other Operation and Maintenance

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

	Three Months		Six Months
Gas distribution maintenance and compliance	$	2	$	3
Timing and scope of generation maintenance outages	1		2
Storm costs	2		2
Other	2		4
Total	$	7	$	11

Depreciation

Depreciation increased $4 million for the three months ended June 30, 2018 compared with 2017, due to a $2 million increase related to higher depreciation rates effective July 1, 2017 and a $2 million increase related to additions to PP&E, net of retirements.

Depreciation increased $8 million for the six months ended June 30, 2018 compared with 2017, due to a $4 million increase related to higher depreciation rates effective July 1, 2017 and a $4 million increase related to additions to PP&E, net of retirements.

Income Taxes

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

	Three Months			Six Months
Reduction in U.S. federal income tax rate (a)	$	(9	)	$	(22	)
Amortization of excess deferred income taxes (a)	(3		)	(5		)
Change in pre-tax income	(3		)	—
Total	$	(15	)	$	(27	)

(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				Six Months Ended
	June 30,				June 30,
	2018		2017		2018		2017
Net Income	$	50	$	42	$	122	$	96
Special items, gains (losses), after-tax (a)	—		—		—		—

(a) There are no items management considers special for the periods presented.

Earnings increased for the three and six month periods in 2018 compared with 2017, primarily due to higher base electricity and gas rates effective July 1, 2017 and higher sales volumes driven by favorable weather, partially offset by higher other operation and maintenance expense and higher depreciation expense.

106

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.

	Three Months			Six Months
Adjusted Gross Margins	$	9		$	24
Other operation and maintenance	(7		)	(12		)
Depreciation	(5		)	(10		)
Taxes, other than income	(2		)	(3		)
Other Income (Expense) - net	(2		)	1
Interest Expense	—			(1		)
Income Taxes	15			27
Net Income	$	8		$	26

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."

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 June 30.

	2018 Three Months							2017 Three Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	335	$	—		$	335	$	324	$	—		$	324
Operating Expenses
Fuel	72		—			72		69		—			69
Energy purchases, including affiliate	30		—			30		28		—			28
Other operation and maintenance	10		83			93		10		76			86
Depreciation	7		42			49		8		37			45
Taxes, other than income	—		9			9		2		7			9
Total Operating Expenses	119		134			253		117		120			237
Total	$	216	$	(134	)	$	82	$	207	$	(120	)	$	87
	2018 Six Months							2017 Six Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	754	$	—		$	754	$	715	$	—		$	715
Operating Expenses
Fuel	151		—			151		149		—			149
Energy purchases, including affiliate	112		—			112		94		—			94
Other operation and maintenance	19		163			182		20		151			171
Depreciation	15		82			97		17		72			89
Taxes, other than income	—		18			18		2		15			17
Total Operating Expenses	297		263			560		282		238			520
Total	$	457	$	(263	)	$	194	$	433	$	(238	)	$	195

(a) Represents amounts excluded from Adjusted Gross Margins.

(b) As reported on the Statements of Income.

107

KU: Statement of Income Analysis, Earnings and Adjusted Gross Margins

Statement of Income Analysis

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

	Three Months								Six Months
	2018		2017			$ Change			2018		2017			$ Change
Operating Revenues
Retail and wholesale	$	412	$	403		$	9		$	877	$	838		$	39
Electric revenue from affiliate	2		3			(1		)	8		5			3
Total Operating Revenues	414		406			8			885		843			42
Operating Expenses
Operation
Fuel	117		114			3			252		225			27
Energy purchases	5		4			1			9		9			—
Energy purchases from affiliate	4		4			—			16		21			(5		)
Other operation and maintenance	112		100			12			217		208			9
Depreciation	70		61			9			138		121			17
Taxes, other than income	9		7			2			17		15			2
Total Operating Expenses	317		290			27			649		599			50
Other Income (Expense) - net	3		(2		)	5			—		(4		)	4
Interest Expense	25		24			1			50		48			2
Income Taxes	14		34			(20		)	38		73			(35		)
Net Income	$	61	$	56		$	5		$	148	$	119		$	29

Operating Revenues

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

	Three Months			Six Months
Volumes (a)	$	18		$	56
Base rates	12			26
ECR	4			6
Fuel and other energy prices	(2		)	2
TCJA refund (b)	(20		)	(42		)
DSM	(2		)	(6		)
Other	(2		)	—
Total	$	8		$	42

(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 increased $3 million and $27 million for the three and six months endedJune 30, 2018 compared with 2017, primarily due to an increase in volumes driven by weather in 2018.

108

Other Operation and Maintenance

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

	Three Months		Six Months
Timing and scope of generation maintenance outages	$	5	$	6
Vegetation management	3		4
Other	4		(1		)
Total	$	12	$	9

Depreciation

Depreciation increased $9 million for the three months ended June 30, 2018 compared with 2017, primarily due to a $6 million increase related to higher depreciation rates effective July 1, 2017 and a $2 million increase related to additions to PP&E, net of retirements.

Depreciation increased $17 million for the six months endedJune 30, 2018 compared with 2017, primarily due to an $11 million increase related to higher depreciation rates effective July 1, 2017 and a $5 million increase related to additions to PP&E, net of retirements.

Income Taxes

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

	Three Months			Six Months
Reduction in U.S. federal income tax rate (a)	$	(10	)	$	(26	)
Amortization of excess deferred income taxes (a)	(3		)	(6		)
Change in pre-tax income	(6		)	(2		)
Other	(1		)	(1		)
Total	$	(20	)	$	(35	)

(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				Six Months Ended
	June 30,				June 30,
	2018		2017		2018		2017
Net Income	$	61	$	56	$	148	$	119
Special items, gains (losses), after-tax	—		—		—		(1		)

Earnings increased for the three and six month periods in 2018 compared with 2017, primarily due to higher base electricity rates effective July 1, 2017 and higher sales volumes driven by favorable weather, partially offset by higher other operation and maintenance expense 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.

109

	Three Months			Six Months
Adjusted Gross Margins	$	6		$	19
Other operation and maintenance	(15		)	(12		)
Depreciation	(7		)	(13		)
Taxes, other than income	(3		)	(2		)
Other Income (Expense) - net	5			3
Interest Expense	(1		)	(2		)
Income Taxes	20			35
Special items, gains (losses), after-tax (a)	—			1
Net Income	$	5		$	29

(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."

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 June 30.

	2018 Three Months							2017 Three Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	414	$	—		$	414	$	406	$	—		$	406
Operating Expenses
Fuel	117		—			117		114		—			114
Energy purchases, including affiliate	9		—			9		8		—			8
Other operation and maintenance	13		99			112		16		84			100
Depreciation	10		60			70		8		53			61
Taxes, other than income	—		9			9		1		6			7
Total Operating Expenses	149		168			317		147		143			290
Total	$	265	$	(168	)	$	97	$	259	$	(143	)	$	116
	2018 Six Months							2017 Six Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	885	$	—		$	885	$	843	$	—		$	843
Operating Expenses
Fuel	252		—			252		225		—			225
Energy purchases, including affiliate	25		—			25		30		—			30
Other operation and maintenance	29		188			217		32		176			208
Depreciation	19		119			138		15		106			121
Taxes, other than income	1		16			17		1		14			15
Total Operating Expenses	326		323			649		303		296			599
Total	$	559	$	(323	)	$	236	$	540	$	(296	)	$	244

(a) Represents amounts excluded from Adjusted Gross Margins.

(b) As reported on the Statements of Income.

110

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
June 30, 2018
Cash and cash equivalents	$	852	$	489	$	39	$	19	$	20
Short-term debt	1,864		—		316		183		133
Long-term debt due within one year	203		—		203		194		9
Notes payable with affiliates			—		99		—		—
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 June 30, 2018, $2 million of cash and cash equivalents were denominated in GBP. If these amounts would be remitted as dividends, PPL would not anticipate an incremental U.S. tax cost. See Note 5 to the Financial Statements in PPL's 2017 Form 10-K for additional information on undistributed earnings of WPD.

Net cash provided by (used in) operating, investing and financing activities for the six month periods ended June 30, and the changes between periods, were as follows.

	PPL			PPL Electric			LKE			LG&E			KU
2018
Operating activities	$	1,325		$	364		$	440		$	255		$	274
Investing activities	(1,649		)	(521		)	(564		)	(296		)	(266		)
Financing activities	695			597			133			45			(3		)
2017
Operating activities	$	790		$	279		$	511		$	264		$	257
Investing activities	(1,385		)	(824		)	(355		)	(177		)	(177		)
Financing activities	711			591			(150		)	(85		)	(75		)
Change  - Cash Provided (Used)
Operating activities	$	535		$	85		$	(71	)	$	(9	)	$	17
Investing activities	(264		)	303			(209		)	(119		)	(89		)
Financing activities	(16		)	6			283			130			72

Operating Activities

The components of the change in cash provided by (used in) operating activities for the six months ended June 30, 2018 compared with 2017 were as follows.

111

	PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Net income	$	272		$	67		$	38		$	26		$	29
Non-cash components	(279		)	(25		)	(46		)	(32		)	(51		)
Working capital	129			36			46			59			80
Defined benefit plan funding	346			(4		)	(93		)	(54		)	(31		)
Other operating activities	67			11			(16		)	(8		)	(10		)
Total	$	535		$	85		$	(71	)	$	(9	)	$	17

(PPL)

PPL's cash provided by operating activities in 2018 increased $535 million compared with 2017.

• Net income increased $272 million between periods and included a decrease in non-cash charges of $279 million. The decrease in non-cash charges was primarily due to an increase in unrealized gains on hedging activities, an increase in the U.K. net periodic defined benefit credits (primarily due to an increase in expected returns on higher asset balances) and a decrease 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 in 2017 and book versus tax plant timing differences and net operating losses at EU) partially offset by an increase in depreciation expense (primarily due to additional assets placed into service, net of retirements, and higher depreciation rates effective July 1, 2017 at LG&E and KU and the impact of foreign currency exchange rates at WPD).

• The $129 million increase in cash from changes in working capital was primarily due to a decrease in net regulatory assets and liabilities (primarily due to the impact of the TCJA and timing of rate recovery mechanisms) and an increase in taxes payable (primarily due to an increase in current income tax benefits in 2017).

• Defined benefit plan funding was $346 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 $85 million compared with 2017.

• Net income increased $67 million between the periods and included a decrease in non-cash charges of $25 million. The decrease in non-cash charges was primarily driven by a $31 million decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and net operating losses).

• The $36 million increase in cash from changes in working capital was primarily due to a $24 million increase in accounts receivable and a $13 million increase in unbilled revenues due to an increase in sales volumes and returns on additional capital investments.

• The $11 million increase in cash provided by other operating activities was primarily due to an increase in non-current regulatory liabilities (primarily due to a $37 million TCJA liability) partially offset by an increase in non-current regulatory assets (primarily due to $21 million of storm costs).

(LKE)

LKE's cash provided by operating activities in 2018decreased$71 million compared with 2017.

• Net income increased $38 million between the periods and included a decrease in non-cash charges of $46 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 timing of rate recovery mechanisms), an increase in accounts 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 taxes payable (primarily due to timing of payments), a

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decrease in other current liabilities (primarily due to timing of payments) and an increase in fuel inventory (primarily due to timing of fuel purchases and payments).

• Defined benefit plan funding was $93 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 2018decreased$9 million compared with 2017.

• Net income increased $26 million between the periods and included a decrease in non-cash charges of $32 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) 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 $54 million higher in 2018.

• The decrease in cash from LG&E's other operating activities was primarily driven by an increase in ARO expenditures.

(KU)

KU's cash provided by operating activities in 2018increased$17 million compared with 2017.

• Net income increased $29 million between the periods and included a decrease in non-cash charges of $51 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), an increase in accounts 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) and 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 six months ended June 30, 2018 compared with 2017 was as follows. 

	PPL			PPL Electric		LKE			LG&E			KU
Decrease (Increase)	$	(154	)	$	32	$	(209	)	$	(119	)	$	(89	)

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For PPL, the increase in expenditures was due to higher project expenditures at LKE, LG&E and KU partially offset by lower project expenditures at PPL Electric and WPD. 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. 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 increase in expenditures for LKE, LG&E and KU was primarily due to increased spending for environmental water projects at LG&E's Mill Creek and Trimble County plants and increased spending for environmental water projects at KU's Ghent plant.

Financing Activities

(All Registrants)

The components of the change in cash provided by (used in) financing activities for the six months ended June 30, 2018 compared with 2017 were as follows.

	PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	(200	)	$	(72	)	$	100		$	100		$	—
Debt issuance/retirement with affiliate, net				—			250			—			—
Stock issuances/redemptions, net	(30		)	—			—			—			—
Dividends	(29		)	(68		)	—			41			(26		)
Capital contributions/distributions, net				(150		)	57			43			45
Change in short-term debt, net	234			295			(1		)	(54		)	53
Notes payable with affiliate				—			(122		)	—			—
Other financing activities	9			1			(1		)	—			—
Total	$	(16	)	$	6		$	283		$	130		$	72

See Note 8 to the Financial Statements in this Form 10-Q for information on 2018 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 7 to the Financial Statements in the Registrants' 2017 Form 10-K for information on 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 June 30, 2018, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:

External

	Committed Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity
PPL Capital Funding Credit Facilities	$	1,350	$	—	$	1,019	$	331
PPL Electric Credit Facility	650		—		1		649
LKE Credit Facility	75		—		—		75
LG&E Credit Facility	700		200		183		317
KU Credit Facilities	598		—		331		267
Total LKE	1,373		200		514		659
Total U.S. Credit Facilities (a)	$	3,373	$	200	$	1,534	$	1,639
Total U.K. Credit Facilities (b)	£	1,185	£	413	£	—	£	772

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(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 - 18%, LG&E - 33% and KU - 37%.

(b) The amounts borrowed at June 30, 2018 were a USD-denominated borrowing of $200 million and GBP-denominated borrowings which equated to $349 million. The unused capacity reflects the USD-denominated borrowing amount borrowed in GBP of £150 million as of the date borrowed. At June 30, 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 17% of the total committed capacity.

See Note 8 to the Financial Statements for further discussion of the Registrants' credit facilities.

Intercompany (LKE, LG&E and KU)

	Committed Capacity		Borrowed		Non-affiliate Used Capacity		Unused Capacity
LKE Credit Facility	$	300	$	99	$	—	$	201
LG&E Money Pool (a)	500		—		183		317
KU Money Pool (a)	500		—		133		367

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

Commercial Paper(All Registrants)

PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary. 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 June 30, 2018:

	Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding	$	1,000	$	999	$	1
PPL Electric	650		—		650
LG&E	350		183		167
KU	350		133		217
Total LKE	700		316		384
Total PPL	$	2,350	$	1,315	$	1,035

Long-term Debt (All Registrants)

See Note 8 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 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. Settlement of these forward sale agreements will occur no later than November

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2019. PPL will not receive any proceeds or issue any shares of common stock until settlement of the forward sale agreements. PPL intends to use any net proceeds that it receives upon settlement for general corporate purposes. See Note 8 to the Financial Statements for additional information.

ATM Program

For the three and six months ended June 30, 2018, PPL issued 1.2 million and 4.2 million shares of common stock and received proceeds of $34 million and $119 million. See Note 8 to the Financial Statements for further discussion of the ATM program.

Common Stock Dividends

In May 2018, PPL declared a quarterly common stock dividend, payable July 2, 2018, of 41.0 cents per share (equivalent to $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.

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 2018:

(PPL)

In March 2018, Moody's and S&P assigned ratings of Baa1 and A- to WPD (South Wales)'s £30 million 0.01% Index-linked Senior Notes due 2036.

In May 2018, Moody's and S&P assigned ratings of Baa1 and A- to WPD (West Midlands)'s £30 million 0.01% Index-linked Senior Notes due 2028.

(PPL and PPL Electric)

In June 2018, Moody's and S&P assigned ratings of A1 and A to PPL Electric's $400M 4.15% First Mortgage Bonds due 2048.

(PPL, LKE and LG&E)

In 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 to the County of Trimble, Kentucky's $35 million 2.55% Pollution Control Revenue Bonds, 2001 Series B (Louisville Gas and Electric Company Project) due 2027, previously issued on behalf of LG&E.

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In April 2018, Moody's assigned a rating of A1 and S&P confirmed its rating of A to the County of Jefferson, Kentucky's $35 million 2.55% Pollution Control Revenue Bonds, 2001 Series B (Louisville Gas and Electric Company Project) due 2027, previously issued on behalf of LG&E.

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 14 to the Financial Statements for a discussion of "Credit Risk-Related Contingent Features," including a discussion of the potential additional collateral requirements for PPL, LKE and LG&E for derivative contracts in a net liability position at June 30, 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' 2017 Form 10-K.

Risk Management

Market Risk

(All Registrants)

See Notes 13 and 14 to the Financial Statements for information about the Registrants' risk management objectives, valuation techniques and accounting designations.

The forward-looking information presented below provides estimates of what may occur in the future, assuming certain adverse market conditions and model assumptions. Actual future results may differ materially from those presented. These are not precise indicators of expected future losses, but are rather only indicators of possible losses under normal market conditions at a given confidence level.

Interest Rate Risk

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.

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The following interest rate hedges were outstanding at June 30, 2018.

	Exposure Hedged		Fair Value, Net - Asset (Liability) (a)			Effect of a 10% Adverse Movement in Rates (b)			Maturities Ranging Through
PPL
Cash flow hedges
Cross-currency swaps (c)	$	702	$	101		$	(81	)	2028
Economic hedges
Interest rate swaps (d)	147		(21		)	(2		)	2033
LKE
Economic hedges
Interest rate swaps (d)	147		(21		)	(2		)	2033
LG&E
Economic hedges
Interest rate swaps (d)	147		(21		)	(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 June 30, 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 June 30, 2018 is shown below.

	10% Adverse Movement in Rates
PPL	$	658
PPL Electric	193
LKE	177
LG&E	63
KU	94

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 translation risk of expected earnings, firm commitments, recognized assets or liabilities, anticipated transactions and net investments.

The following foreign currency hedges were outstanding at June 30, 2018.

	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)	£	1,992	$	110	$	(244	)	2020

(a) Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability.

(b) To economically hedge the translation risk of expected earnings denominated in GBP.

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(All Registrants)

Commodity Price Risk

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

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

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

Volumetric Risk

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

• 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 regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 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.

Credit Risk(All Registrants)

See Notes 13 and 14 to the Financial Statements in this Form 10-Q and "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Risk Management - Credit Risk" in the Registrants' 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 $143 million for the six months ended June 30, 2018, which primarily reflected a $227 million decrease to PP&E, a $45 million decrease to goodwill and a $2 million increase to other net liabilities, partially offset by a $131 million decrease to long-term debt. Changes in this exchange rate resulted in a foreign currency translation gain of $207 million for the six months ended June 30, 2017, which primarily reflected a $367 million increase to PP&E and $79 million increase to goodwill partially offset by a $216 million increase to long-term debt and a $23 million increase 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. See Note 11 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' 2017 Form 10-K for information on the more significant activities.

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

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significant. In addition, costs may increase significantly if the requirements or scope of environmental laws or regulations, or similar rules, are expanded or changed. Costs may take the form of increased capital expenditures or operating and maintenance expenses, monetary fines, penalties or other restrictions. Many of these environmental law considerations are also applicable to the operations of key suppliers, or customers, such as coal producers and industrial power users, and may impact the 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 Note 10 to the Financial Statements for a discussion of the more significant environmental matters including Legal Matters, NAAQS, Climate Change, CCRs, and ELGs. Additionally, see "Item 1. Business - Environmental Matters" in the Registrants' 2017 Form 10-K for additional information.

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.

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' 2017 Form 10-K for a discussion of each critical accounting policy.

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

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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 June 30, 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' second 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 tax litigation, regulatory, environmental and other matters, which information is incorporated by reference into this Part II, see:

• "Item 3. Legal Proceedings" in each Registrant's 2017 Form 10-K; and

• Notes 7 and 10 to the Financial Statements.

Item 1A. Risk Factors

There have been no material changes in the Registrants' risk factors from those disclosed in "Item 1A. Risk Factors" of the Registrants' 2017 Form 10-K.

Item 4. Mine Safety Disclosures

Not applicable.

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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*1(a)	-	Final Terms, dated May 11, 2018, of Western Power Distribution (West Midlands) plc £30,000,000 RPI Index Linked Senior Unsecured Notes due March 2028
4(a)	-	Supplemental Indenture No. 20, dated as of June 1, 2018, of PPL Electric Utilities Corporation to The Bank of New York Mellon, as Trustee (Exhibit 4(a) to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 14, 2018)
4(b)	-	Officer’s Certificate, dated June 14, 2018, pursuant to Section 201 and Section 301 of the Indenture (Exhibit 4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated June 14, 2018)
10(a)	-	Confirmation of Forward Sale Transaction, dated May 8, 2018, between the Company and JPMorgan Chase Bank, National Association, London Branch (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 11, 2018)
10(b)	-	Confirmation of Forward Sale Transaction, dated May 8, 2018, between the Company and Barclays Bank PLC (Exhibit 10.2 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 11, 2018)
10(c)	-	Additional Confirmation of Forward Sale Transaction, dated May 10, 2018, between the Company and JPMorgan Chase Bank, National Association, London Branch (Exhibit 10.3 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 11, 2018)
10(d)	-	Additional Confirmation of Forward Sale Transaction, dated May 8, 2018, between the Company and Barclays Bank PLC (Exhibit 10.4 to PPL Corporation Form 8-K Report (File No. 1-11459) dated May 11, 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 June 30, 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 June 30, 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:	August 7, 2018	/s/  Stephen K. Breininger
		Stephen K. Breininger Vice President and Controller
		(Principal Accounting Officer)
		PPL Electric Utilities Corporation
		(Registrant)
Date:	August 7, 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:	August 7, 2018	/s/  Kent W. Blake
		Kent W. Blake Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

124

EX-1.A

Exhibit 1(a)

PROHIBITION OF SALES TO EEA RETAIL INVESTORS – The Notes are not intended to be offered, sold or otherwise made available to and should not be offered, sold or otherwise made available to any retail investor in the European Economic Area ("EEA"). For these purposes, a retail investor means a person who is one (or more) of: (i) a retail client as defined in point (11) of Article 4(1) of Directive 2014/65/EU ("MiFID II"); or (ii) a customer within the meaning of Directive 2002/92/EC ("Insurance MediationDirective"), where that customer would not qualify as a professional client as defined in point (10) of Article 4(1) of MiFID II. Consequently no key information document required by Regulation (EU) No 1286/2014 (the "PRIIPs Regulation") for offering or selling the Notes or otherwise making them available to retail investors in the EEA has been prepared and therefore offering or selling the Notes or otherwise making them available to any retail investor in the EEA may be unlawful under the PRIIPs Regulation.

11 May 2018

Western Power Distribution (West Midlands) plc

Issue of GBP 30,000,000 RPI Index Linked Senior Unsecured Notes due May 2028

under the £3,000,000,000

Euro Medium Term Note Programme

Part A

Contractual Terms

Terms used herein shall be deemed to be defined as such for the purposes of the Conditions set forth in the Prospectus dated 15 September 2017 and the supplement dated 15 March 2018, which together constitute a base prospectus (the Prospectus) for the purposes of the Prospectus Directive (Directive 2003/71/EC), as amended (the Prospectus Directive). This document constitutes the Final Terms of the Notes described herein for the purposes of Article 5.4 of the Prospectus Directive and must be read in conjunction with such Prospectus as so supplemented. Full information on the Issuer and the offer of the Notes is only available on the basis of the combination of these Final Terms and the Prospectus as so supplemented. The Prospectus and the supplemental Prospectus are available for viewing at www.westernpower.co.uk and during normal business hours at Avonbank, Feeder Road, Bristol BS2 0TB and copies may be obtained from Avonbank, Feeder Road, Bristol BS2 0TB. The Prospectus and (in the case of Notes listed and admitted to trading on the regulated market of the London Stock Exchange) the applicable Final Terms will also be published on the website of the London Stock Exchange: www.londonstockexchange.com/exchange/news/market-news/market-news-home.html.

1	Issuer:		Western Power Distribution (West Midlands) plc
2	(i)	Series Number:	2018-2
	(ii)	Tranche Number:	1
	(iii)	Date on which the Notes will be consolidated and form a single Series	Not Applicable
3	Specified Currency or Currencies:		Pounds Sterling (“£”)
4	Aggregate Nominal Amount:
	(i)	Series:	£ 30,000,000
	(ii)	Tranche:	£ 30,000,000
5	(i)	Issue Price of Tranche:	102.655 per cent. of the Aggregate Nominal Amount

6	(i)	Specified Denominations:	£100,000 and integral multiples of £1,000 in excess thereof up to and including £199,000. No Notes in definitive form will be issued with a denomination of integral multiples above £199,000.
	(ii)	Calculation Amount:	£1,000
7	(i)	Issue Date:	16 May 2018
	(ii)	Interest Commencement Date:	Issue Date
8	Maturity Date:		16 May 2028
9	Interest Basis:		Index Linked Interest (further particulars specified below)
10	Redemption Basis:		Subject to any purchase and cancellation or early redemption, the Notes will be redeemed on the Maturity Date at 100per cent. of their nominal amount
11	Change of Interest Basis or Redemption/ Payment Basis:		Not Applicable
12	Put/Call Options:		Restructuring Put Option
			(further particulars specified in paragraph 22)
13	Date approval by Committee of the Board of Directors for issuance of Notes obtained:		8 May 2018
Provisions Relating to Interest (if any) Payable
14	Fixed Rate Note Provisions		Applicable
	(i)	Rate of Interest:	0.01 per cent. per annum payable semi-annually in arrear (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio)
	(ii)	Interest Payment Dates:	16 May and 16 November in each year from and including 16 November 2018 to and including the Maturity Date
	(iii)	Fixed Coupon Amount:	£0.050 per Calculation Amount per semi-annual period (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio))
	(iv)	Broken Amount:	Not Applicable
	(v)	Day Count Fraction:	Actual/Actual ICMA
	(vi)	Determination Dates:	16 May and 16 November in each year
15	Floating Rate Note Provisions		Not Applicable
16	Zero Coupon Note Provisions		Not Applicable
17	Index Linked Interest Note Provisions		Applicable
	(i)	Rate of Interest:	Fixed, calculated in accordance with paragraph 14 above
	(ii)	Minimum Indexation Factor:	Not Applicable
	(iii)	Maximum Indexation Factor:	Not Applicable
	(iv)	Base Index Figure:	278.19677 calculated as an interpolation between RPI figures in February 2018 and March 2018
	(v)	Limited Indexation Month(s):	Not Applicable
	(vi)	Reference Gilt:	1.25 per cent. Index-Linked Treasury Stock due 2027
	(vii)	Index Figure applicable	3 months lag
18	Ratings Downgrade Rate Adjustment		Not Applicable
Provisions Relating to Redemption
19	Index Linked Redemption Provisions		Applicable
	(i)	Minimum Indexation Factor:	Not Applicable
	(ii)	Maximum Indexation Factor:	Not Applicable

	(iii)	Base Index Figure:	278.19677 calculated as an interpolation between RPI figures in February 2018 and March 2018
	(iv)	Reference Gilt:	1.25 per cent. Index-Linked Treasury Stock due 2027
	(v)	Index Figure applicable	3 months lag
	(vi)	Redeemable in part:	Not Applicable
20	Issuer Call		Not Applicable
21	Investor Put		Applicable (Condition 6(g) (Redemption at the Option of Noteholders on a Restructuring Event) applies)
	(i)	Optional Redemption Date(s):	On the Put Date (as specified in the relevant Put Event Notice) (where (Condition 6(g) (Redemption at the Option of Noteholders on a Restructuring Event) applies)
	(ii)	Notice Period:	As per Condition 6(g) (Redemption at the Option of Noteholders on a Restructuring Event)
	(iii)	Optional Redemption Amount(s):	£1,000 (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio) and paragraph 19 above) per Calculation Amount
22	Restructuring Put Option		Applicable 6(g) (Redemption at the Option of the Noteholders on a Restructuring Event) applies
	(i)	Optional Redemption Amount(s):	£1,000 (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio) and paragraph 19 above) per Calculation Amount
23	Final Redemption Amount:		£1,000 (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio) and paragraph 19 above) per Calculation Amount
24	Early Redemption Amount payable on redemption for taxation reasons or on event of default		£1,000 (as adjusted in accordance with Condition 7(a) (Application of the Index Ratio) and paragraph 19 above) per Calculation Amount
General Provisions Applicable to the Notes
25	Form of Notes:		Bearer
	(i)	if issued in Bearer form:	Temporary Global Note exchangeable for a permanent Global Note which is exchangeable for Definitive Notes in the limited circumstances specified in the permanent Global Note.
		New Global Note/NSS:	Yes (NGN)
26	Additional Financial Centre(s) or other special provisions relating to payment dates:		Not Applicable
27	Talons for future Coupons to be attached to Definitive Notes:		No

Signed on behalf of

Western Power Distribution (West Midlands) plc

_______________________________________

By:     I R WILLIAMS

Part B

Other Information

1	Listing and Admission to Trading
	(i)	Listing and admission to trading:	Application is expected to be made by the Issuer (or on its behalf) for the Notes to be admitted to trading on the London Stock Exchange’s regulated market and listing on the Official List of the UK Listing Authority and this is expected to be effective from 16 May 2018
	(ii)	Estimate of total expenses related to admission to trading:	£1750
2	Ratings
	Ratings:		The Notes to be issued have been rated:
			Baa1 (Stable) by Moody's Investors Service Limited (Moody's); and
			A- (Stable) by Standard & Poor's Credit Market Services Europe Limited (S&P)
			Each of Moody's and S&P is established in the European Union and is registered under Regulation (EC) No. 1060/2009 (as amended)
3	Interests of Natural and Legal Persons Involved in the Issue
	Save for any fees payable to the Managers, so far as the Issuer is aware, no person involved in the issue of the Notes has an interest material to the offer.
4	Reasons for the Offer, Estimated Net Proceeds and Total Expenses
	(i)	Reasons for the offer	See the section entitled “Use of proceeds” in the Prospectus
	(ii)	Estimated net proceeds:	Not Applicable
	(iii)	Estimated total expenses:	Not Applicable
5	Yield (Fixed Rate Notes only)
	Indication of yield:		0.252 per cent.
6	Operational Information
	(i)	ISIN Code:	XS1821535678
	(ii)	Common Code:	182153567
	(iii)	Any clearing system(s) other than Euroclear Bank SA/NV and Clearstream Banking S.A. and the relevant identification number(s):	Not Applicable
	(iv)	Delivery:	Delivery against payment
	(v)	Names and addresses of additional Paying Agent(s) (if any):	Not applicable

	(vi)	Intended to be held in a manner which would allow Eurosystem eligibility:	Yes. Note that the designation "yes" simply means that the Notes are intended upon issue to be deposited with one of the international central securities depositories (ICSD) as common safekeeper and registered in the name of a nominee of one of the ICSDs acting as common safekeeper, that is, held under the NSS, and does not necessarily mean that the Notes will be recognised as eligible collateral for Eurosystem monetary policy and intra day credit operations by the Eurosystem either upon issue or at any or all times during their life. Such recognition will depend upon the European Central Bank (the ECB) being satisfied that Eurosystem eligibility criteria have been met.
7	Distribution
	(i)	Method of distribution:	Non-syndicated
	(ii)	If syndicated, names and addresses of Managers):	Not Applicable
	(iii)	Date of Dealer Agreement:	15 September 2017
	(iv)	Stabilisation Manager(s) (if any):	Not Applicable
	(v)	If non-syndicated, name and address of relevant Dealer:	RBC Europe Limited Riverbank House 2 Swan Lane London EC4R 3BF
	(vi)	U.S. Selling Restrictions:	Reg. S Compliance Category 2; TEFRA D not applicable
	(vii)	Prohibition of Sales to EEA Retail Investors:	Applicable

EX-12.A

Exhibit 12(a)

PPL CORPORATION AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND

PREFERRED STOCK DIVIDENDS

(Millions of Dollars)

	Six Months Ended June 30,		Years Ended December 31,
	2018		2017		2016			2015 (a)			2014 (a)		2013 (a)
Earnings, as defined:
Income from Continuing Operations Before Income Taxes	$	1,226	$	1,912	$	2,550		$	2,068		$	2,129	$	1,728
Adjustment to reflect earnings from equity method investments on a cash basis	—		1		(1		)	(1		)	—		—
	1,226		1,913		2,549			2,067			2,129		1,728
Total fixed charges as below	486		927		917			1,054			1,095		1,096
Less:
Capitalized interest	4		4		4			11			11		11
Interest expense and fixed charges related to discontinued operations	—		—		—			150			186		235
Total fixed charges included in Income from Continuing Operations Before Income Taxes	482		923		913			893			898		850
Total earnings	$	1,708	$	2,836	$	3,462		$	2,960		$	3,027	$	2,578
Fixed charges, as defined:
Interest charges (b)	$	481	$	912	$	900		$	1,038		$	1,073	$	1,058
Estimated interest component of operating rentals	5		15		17			16			22		38
Total fixed charges (c)	$	486	$	927	$	917		$	1,054		$	1,095	$	1,096
Ratio of earnings to fixed charges (d)	3.5		3.1		3.8			2.8			2.8		2.4

(a) Reflects PPL's former Supply segment as Discontinued Operations.

(b) Includes interest on long-term and short-term debt, as well as amortization of debt discount, expense and premium - net.

(c) Interest on unrecognized tax benefits is not included in fixed charges.

(d) PPL, the parent holding company, does not have any preferred stock outstanding; therefore, the ratio of earnings to combined fixed charges and preferred stock dividends is the same as the ratio of earnings to fixed charges.

EX-12.B

Exhibit 12(b)

PPL ELECTRIC UTILITIES CORPORATION AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND

PREFERRED STOCK DIVIDENDS

(Millions of Dollars)

	Six Months Ended June 30,		Years Ended December 31,
	2018		2017		2016		2015		2014		2013
Earnings, as defined:
Income Before Income Taxes	$	299	$	575	$	552	$	416	$	423	$	317
Total fixed charges as below	82		153		141		139		131		117
Total earnings	$	381	$	728	$	693	$	555	$	554	$	434
Fixed charges, as defined:
Interest charges (a)	$	80	$	149	$	137	$	135	$	127	$	113
Estimated interest component of operating rentals	2		4		4		4		4		4
Total fixed charges (b)	$	82	$	153	$	141	$	139	$	131	$	117
Ratio of earnings to fixed charges (c)	4.6		4.8		4.9		4.0		4.2		3.7

(a) Includes interest on long-term and short-term debt, as well as amortization of debt discount, expense and premium - net.

(b) Interest on unrecognized tax benefits is not included in fixed charges.

(c) PPL Electric does not have any preferred stock outstanding; therefore, the ratio of earnings to combined fixed charges and preferred stock dividends is the same as the ratio of earnings to fixed charges.

EX-12.C

Exhibit 12(c)

LG&E AND KU ENERGY LLC AND SUBSIDIARIES

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

(Millions of Dollars)

	Six Months Ended June 30,		Years Ended December 31,
	2018		2017		2016			2015			2014			2013
Earnings, as defined:
Income from Continuing Operations Before Income Taxes	$	298	$	691	$	686		$	603		$	553		$	551
Adjustment to reflect earnings from equity method investments on a cash basis	—		1		(1		)	(1		)	(1		)	(1		)
	298		692		685			602			552			550
Total fixed charges as below	118		224		223			189			173			151
Total earnings	$	416	$	916	$	908		$	791		$	725		$	701
Fixed charges, as defined:
Interest charges (a) (b)	$	113	$	215	$	214		$	181		$	167		$	145
Estimated interest component of operating rentals	5		9		9			8			6			6
Total fixed charges	$	118	$	224	$	223		$	189		$	173		$	151
Ratio of earnings to fixed charges	3.5		4.1		4.1			4.2			4.2			4.6

(a) Includes interest on long-term and short-term debt, as well as amortization of loss on reacquired debt and amortization of debt discount, expense and premium - net.

(b) Includes a credit for amortization of a fair market value adjustment of $7 million in 2013.

EX-12.D

Exhibit 12(d)

LOUISVILLE GAS AND ELECTRIC COMPANY

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

(Millions of Dollars)

	Six Months Ended June 30,		Years Ended December 31,
	2018		2017		2016		2015		2014		2013
Earnings, as defined:
Income Before Income Taxes	$	155	$	344	$	329	$	299	$	272	$	257
Total fixed charges as below	40		76		76		61		51		36
Total earnings	$	195	$	420	$	405	$	360	$	323	$	293
Fixed charges, as defined:
Interest charges (a) (b)	$	37	$	71	$	71	$	57	$	49	$	34
Estimated interest component of operating rentals	3		5		5		4		2		2
Total fixed charges	$	40	$	76	$	76	$	61	$	51	$	36
Ratio of earnings to fixed charges	4.9		5.5		5.3		5.9		6.3		8.1

(a) Includes interest on long-term and short-term debt, as well as amortization of loss on reacquired debt and amortization of debt discount, expense and premium - net.

(b) Includes a credit for amortization of a fair market value adjustment of $7 million in 2013.

EX-12.E

Exhibit 12(e)

KENTUCKY UTILITIES COMPANY

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

(Millions of Dollars)

	Six Months Ended June 30,		Years Ended December 31,
	2018		2017		2016			2015			2014			2013
Earnings, as defined:
Income Before Income Taxes	$	186	$	418	$	428		$	374		$	355		$	360
Adjustment to reflect earnings from equity method investments on a cash basis			1		(1		)	(1		)	(1		)	(1		)
	186		419		427			373			354			359
Total fixed charges as below	52		100		100			86			80			73
Total earnings	$	238	$	519	$	527		$	459		$	434		$	432
Fixed charges, as defined:
Interest charges (a)	$	50	$	96	$	96		$	82		$	77		$	70
Estimated interest component of operating rentals	2		4		4			4			3			3
Total fixed charges	$	52	$	100	$	100		$	86		$	80		$	73
Ratio of earnings to fixed charges	4.6		5.2		5.3			5.3			5.4			5.9

(a) Includes interest on long-term and short-term debt, as well as amortization of loss on reacquired debt and amortization of debt discount, expense and premium - net.

EX-31.A

Exhibit 31(a)

CERTIFICATION

I, WILLIAM H. SPENCE, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  William H. Spence
		William H. Spence
		Chairman, President and Chief Executive Officer
		(Principal Executive Officer)
		PPL Corporation

EX-31.B

Exhibit 31(b)

CERTIFICATION

I, VINCENT SORGI, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Vincent Sorgi
		Vincent Sorgi
		Senior Vice President and Chief Financial Officer
		(Principal Financial Officer)
		PPL Corporation

EX-31.C

Exhibit 31(c)

CERTIFICATION

I, GREGORY N. DUDKIN, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Gregory N. Dudkin
		Gregory N. Dudkin
		President
		(Principal Executive Officer)
		PPL Electric Utilities Corporation

EX-31.D

Exhibit 31(d)

CERTIFICATION

I, MARLENE C. BEERS, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Marlene C. Beers
		Marlene C. Beers
		Vice President - Finance and Regulatory Affairs and Controller
		(Principal Financial Officer)
		PPL Electric Utilities Corporation

EX-31.E

Exhibit 31(e)

CERTIFICATION

I, PAUL W. THOMPSON, certify that:

1. I have reviewed this quarterly report on Form 10-Q of LG&E and KU Energy LLC (the "registrant");

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		LG&E and KU Energy LLC

EX-31.F

Exhibit 31(f)

CERTIFICATION

I, KENT W. BLAKE, certify that:

1. I have reviewed this quarterly report on Form 10-Q of LG&E and KU Energy LLC (the "registrant");

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		LG&E and KU Energy LLC

EX-31.G

Exhibit 31(g)

CERTIFICATION

I, PAUL W. THOMPSON, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		Louisville Gas and Electric Company

EX-31.H

Exhibit 31(h)

CERTIFICATION

I, KENT W. BLAKE, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		Louisville Gas and Electric Company

EX-31.I

Exhibit 31(i)

CERTIFICATION

I, PAUL W. THOMPSON, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		Kentucky Utilities Company

EX-31.J

Exhibit 31(j)

CERTIFICATION

I, KENT W. BLAKE, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 7, 2018	/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		Kentucky Utilities Company

EX-32.A

Exhibit 32(a)

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

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

FOR PPL CORPORATION'S FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2018

In connection with the quarterly report on Form 10-Q of PPL Corporation (the "Company") for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, William H. Spence, the Principal Executive Officer of the Company, and Vincent Sorgi, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

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

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

Date:	August 7, 2018	/s/  William H. Spence
		William H. Spence
		Chairman, President and Chief Executive Officer
		(Principal Executive Officer)
		PPL Corporation
		/s/  Vincent Sorgi
		Vincent Sorgi
		Senior Vice President and Chief Financial Officer
		(Principal Financial Officer)
		PPL Corporation

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

EX-32.B

Exhibit 32(b)

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

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

FOR PPL ELECTRIC UTILITIES CORPORATION'S FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2018

In connection with the quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "Company") for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Gregory N. Dudkin, the Principal Executive Officer of the Company, and Marlene C. Beers, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

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

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

Date:	August 7, 2018	/s/  Gregory N. Dudkin
		Gregory N. Dudkin
		President
		(Principal Executive Officer)
		PPL Electric Utilities Corporation
		/s/  Marlene C. Beers
		Marlene C. Beers
		Vice President - Finance and Regulatory Affairs and Controller
		(Principal Financial Officer)
		PPL Electric Utilities Corporation

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

EX-32.C

Exhibit 32(c)

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

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

FOR LG&E AND KU ENERGY LLC'S FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2018

In connection with the quarterly report on Form 10-Q of LG&E and KU Energy LLC (the "Company") for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Paul W. Thompson, the Principal Executive Officer of the Company, and Kent W. Blake, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		LG&E and KU Energy LLC
		/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		LG&E and KU Energy LLC

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

EX-32.D

Exhibit 32(d)

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

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

FOR LOUISVILLE GAS AND ELECTRIC COMPANY'S FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2018

In connection with the quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "Company") for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Paul W. Thompson, the Principal Executive Officer of the Company, and Kent W. Blake, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		Louisville Gas and Electric Company
		/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		Louisville Gas and Electric Company

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

EX-32.E

Exhibit 32(e)

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

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

FOR KENTUCKY UTILITIES COMPANY'S FORM 10-Q FOR THE QUARTER ENDED JUNE 30, 2018

In connection with the quarterly report on Form 10-Q of Kentucky Utilities Company (the "Company") for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Paul W. Thompson, the Principal Executive Officer of the Company, and Kent W. Blake, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

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

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

Date:	August 7, 2018	/s/  Paul W. Thompson
		Paul W. Thompson
		Chairman of the Board, Chief Executive Officer and President
		(Principal Executive Officer)
		Kentucky Utilities Company
		/s/  Kent W. Blake
		Kent W. Blake
		Chief Financial Officer
		(Principal Financial Officer)
		Kentucky Utilities Company

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

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 31, 2018
Document Entity Information [Line Items]
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Amendment Flag	false
Entity Registrant Name	PPL Corp
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		699,570,660
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	PPL ELECTRIC UTILITIES CORP
Entity Central Index Key	0000317187
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		66,368,056
LG And E And KU Energy LLC [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LG&E & KU Energy LLC
Entity Central Index Key	0001518339
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	LOUISVILLE GAS & ELECTRIC CO
Entity Central Index Key	0000060549
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Amendment Flag	false
Entity Registrant Name	KENTUCKY UTILITIES CO
Entity Central Index Key	0000055387
Entity Well-known Seasoned Issuer	No
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		37,817,878

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018		Jun. 30, 2017
Operating Revenues
Operating Revenues		$ 1,848	$ 1,725	$ 3,974		$ 3,676
Operation
Fuel		189	183	403		374
Energy purchases		148	136	389		351
Other operation and maintenance		506	432	974		902
Depreciation		273	246	542		488
Taxes, other than income		74	70	157		145
Total Operating Expenses		1,190	1,067	2,465		2,260
Operating Income		658	658	1,509		1,416
Other Income (Expense) - net		234	(68)	191		(77)
Interest Expense		235	222	474		439
Income Before Income Taxes		657	368	1,226		900
Income Taxes		142	76	259		205
Net Income		$ 515	$ 292	$ 967		$ 695
Net Income:
Basic (in dollars per share)		$ 0.74	$ 0.43	$ 1.39		$ 1.02
Diluted (in dollars per share)		0.73	0.43	1.38		1.01
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.41	$ 0.395	$ 0.82		$ 0.79
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		699,006	683,841	696,772		682,370
Diluted (in shares)		700,976	686,351	698,161		684,725
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 517	$ 500	$ 1,156		$ 1,073
Operation
Energy purchases		115	107	276		253
Other operation and maintenance		159	139	292		302
Depreciation		88	76	173		151
Taxes, other than income		22	23	54		52
Total Operating Expenses		384	345	795		758
Operating Income		133	155	361		315
Other Income (Expense) - net		7	4	13		4
Interest Income from Affiliate		1	1	1		1
Interest Expense		39	36	76		69
Income Before Income Taxes		102	124	299		251
Income Taxes		27	47	76		95
Net Income	[1]	75	77	223		156
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		743	723	1,615		1,532
Operation
Fuel		189	183	403		374
Energy purchases		33	29	113		98
Other operation and maintenance		211	192	416		397
Depreciation		118	105	235		210
Taxes, other than income		18	16	35		32
Total Operating Expenses		569	525	1,202		1,111
Operating Income		174	198	413		421
Other Income (Expense) - net		1	(4)	(2)		(8)
Interest Expense		52	50	102		99
Interest Expense with Affiliate		6	4	11		8
Income Before Income Taxes		117	140	298		306
Income Taxes		31	53	70		116
Net Income		86	87	228	[2]	190	[2]
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		331	320	738		694
Electric revenue from affiliate		4	4	16		21
Operating Revenues		335	324	754		715
Operation
Fuel		72	69	151		149
Energy purchases		28	25	104		89
Energy purchases from affiliate		2	3	8		5
Other operation and maintenance		93	86	182		171
Depreciation		49	45	97		89
Taxes, other than income		9	9	18		17
Total Operating Expenses		253	237	560		520
Operating Income		82	87	194		195
Other Income (Expense) - net		(1)	1	(2)		(3)
Interest Expense		19	19	37		36
Income Before Income Taxes		62	69	155		156
Income Taxes		12	27	33		60
Net Income	[1]	50	42	122		96
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		412	403	877		838
Electric revenue from affiliate		2	3	8		5
Operating Revenues		414	406	885		843
Operation
Fuel		117	114	252		225
Energy purchases		5	4	9		9
Energy purchases from affiliate		4	4	16		21
Other operation and maintenance		112	100	217		208
Depreciation		70	61	138		121
Taxes, other than income		9	7	17		15
Total Operating Expenses		317	290	649		599
Operating Income		97	116	236		244
Other Income (Expense) - net		3	(2)	0		(4)
Interest Expense		25	24	50		48
Income Before Income Taxes		75	90	186		192
Income Taxes		14	34	38		73
Net Income	[2]	$ 61	$ 56	$ 148		$ 119

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018		Jun. 30, 2017
Net Income	$ 515	$ 292	$ 967		$ 695
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	(250)	231	(134)		207
Qualifying derivatives, net of tax	19	(24)	(1)		(30)
Defined benefit plans:
Prior service costs, net of tax	(1)	0	(1)		0
Net actuarial gain (loss), net of tax	0	(11)	(1)		(11)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	(19)	25	(7)		24
Equity investees' other comprehensive (income) loss, net of tax	0	1	0		1
Defined benefit plans:
Prior service costs, net of tax	1	1	1		1
Net actuarial (gain) loss, net of tax	34	31	70		63
Total other comprehensive income (loss)	(216)	254	(73)		255
Comprehensive income	299	546	894		950
LG And E And KU Energy LLC [Member]
Net Income	86	87	228	[1]	190	[1]
Defined benefit plans:
Net actuarial gain (loss), net of tax	1	(11)	0		(11)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	0	0		1
Defined benefit plans:
Prior service costs, net of tax	1	1	1		1
Net actuarial (gain) loss, net of tax	(1)	1	1		2
Total other comprehensive income (loss)	1	(9)	2		(7)
Comprehensive income	$ 87	$ 78	$ 230		$ 183

[1] Net income approximates comprehensive income.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Tax effect of foreign currency translation adjustments arising during the period	$ (2)	$ 0	$ (2)	$ (1)
Tax effect of qualifying derivatives arising during the period	(4)	5	0	7
Tax effect of defined benefit plans - prior service costs arising during period	0	0	0	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	0	7	0	7
Tax effect of qualifying derivatives reclassified from accumulated other comprehensive income (loss)	3	(7)	1	(7)
Tax effect of equity investees' other comprehensive (income) loss reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of prior service costs reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	(9)	(9)	(18)	(18)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	0	7	0	7
Tax effect of equity investees' other comprehensive (income) loss reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of prior service costs reclassified from accumulated other comprehensive income (loss)	0	0	0	0
Tax effect of net actuarial (gain) loss reclassified from accumulated other comprehensive income (loss)	$ 0	$ (1)	$ (1)	$ (2)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
Cash Flows from Operating Activities
Net Income		$ 967	$ 695
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		542	488
Amortization		34	45
Defined benefit plans - (income) expense		(101)	(45)
Deferred income taxes and investment tax credits		171	201
Unrealized (gains) losses on derivatives, and other hedging activities		(91)	135
Stock-based compensation expense		16	22
Other		(9)	(5)
Change in current assets and current liabilities
Accounts receivable		46	26
Accounts payable		(90)	(92)
Unbilled revenues		91	70
Fuel, materials and supplies		32	42
Prepayments		(60)	(66)
Taxes payable		28	(27)
Regulatory assets and liabilities, net		42	(19)
Accrued interest		(79)	(77)
Other current liabilities		(47)	(52)
Other		(16)	13
Other operating activities
Defined benefit plans - funding		(206)	(552)
Proceeds from transfer of excess benefit funding		65	0
Other assets		(67)	(1)
Other liabilities		57	(11)
Net cash provided by operating activities		1,325	790
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,527)	(1,373)
Purchase of available-for-sale securities		(65)	0
Other investing activities		(57)	(12)
Net cash used in investing activities		(1,649)	(1,385)
Cash Flows from Financing Activities
Issuance of long-term debt		584	594
Retirement of long-term debt		(250)	(60)
Issuance of common stock		147	177
Payment of common stock dividends		(558)	(529)
Net increase (decrease) in short-term debt		788	554
Other financing activities		(16)	(25)
Net cash provided by (used in) financing activities		695	711
Effect of Exchange Rate on Cash, Cash Equivalents and Restricted Cash		(7)	7
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		364	123
Cash and Cash Equivalents at Beginning of Period		485
Cash and Cash Equivalents at End of Period		852
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		511	367
Cash, Cash Equivalents and Restricted Cash at End of Period		875	490
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		329	284
Accrued expenditures for intangible assets at June 30,		59	56
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net Income	[1]	223	156
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		173	151
Amortization		11	15
Defined benefit plans - (income) expense		0	7
Deferred income taxes and investment tax credits		53	84
Other		(9)	(4)
Change in current assets and current liabilities
Accounts receivable		37	13
Accounts payable		(60)	(59)
Unbilled revenues		30	17
Prepayments		(47)	(52)
Taxes payable		(1)	(4)
Regulatory assets and liabilities, net		(27)	(12)
Other		1	(6)
Other operating activities
Defined benefit plans - funding		(28)	(24)
Other assets		(41)	(4)
Other liabilities		49	1
Net cash provided by operating activities		364	279
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(518)	(550)
Net decrease in notes receivable from affiliate		0	(270)
Other investing activities		(3)	(4)
Net cash used in investing activities		(521)	(824)
Cash Flows from Financing Activities
Issuance of long-term debt		398	470
Net increase (decrease) in short-term debt		0	(295)
Contributions from parent		425	575
Payment of common stock dividends to parent		(222)	(154)
Other financing activities		(4)	(5)
Net cash provided by (used in) financing activities		597	591
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		440	46
Cash and Cash Equivalents at Beginning of Period		49
Cash and Cash Equivalents at End of Period		489
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51	15
Cash, Cash Equivalents and Restricted Cash at End of Period		491	61
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		180	157
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net Income	[2]	228	190
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		235	210
Amortization		9	14
Defined benefit plans - (income) expense		8	12
Deferred income taxes and investment tax credits		30	91
Other		(1)	0
Change in current assets and current liabilities
Accounts receivable		16	13
Accounts payable		(10)	(28)
Accounts payable to affiliates		1	0
Unbilled revenues		40	23
Fuel, materials and supplies		26	41
Taxes payable		(25)	3
Regulatory assets and liabilities, net		69	(7)
Other		(40)	(14)
Other operating activities
Defined benefit plans - funding		(122)	(29)
Expenditures for asset retirement obligations		(26)	(12)
Other assets		(1)	(2)
Other liabilities		3	6
Net cash provided by operating activities		440	511
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(564)	(355)
Net cash used in investing activities		(564)	(355)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate		(126)	(4)
Issuance of long-term debt with affiliate		250	0
Issuance of long-term debt		100	60
Retirement of long-term debt		0	(60)
Distributions to member		(161)	(218)
Net increase (decrease) in short-term debt		72	73
Other financing activities		(2)	(1)
Net cash provided by (used in) financing activities		133	(150)
Cash and Cash Equivalents, Period Increase (Decrease)		9	6
Cash and Cash Equivalents at Beginning of Period		30	13
Cash and Cash Equivalents at End of Period		39	19
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		112	83
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net Income	[1]	122	96
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		97	89
Amortization		7	7
Defined benefit plans - (income) expense		2	3
Deferred income taxes and investment tax credits		18	57
Change in current assets and current liabilities
Accounts receivable		11	9
Accounts receivable from affiliates		6	11
Accounts payable		(12)	(17)
Accounts payable to affiliates		(3)	(3)
Unbilled revenues		24	14
Fuel, materials and supplies		31	33
Taxes payable		(2)	(23)
Regulatory assets and liabilities, net		32	(3)
Other		(7)	0
Other operating activities
Defined benefit plans - funding		(57)	(3)
Expenditures for asset retirement obligations		(10)	(7)
Other liabilities		(4)	1
Net cash provided by operating activities		255	264
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(296)	(177)
Net cash used in investing activities		(296)	(177)
Cash Flows from Financing Activities
Issuance of long-term debt		100	60
Retirement of long-term debt		0	(60)
Net increase (decrease) in short-term debt		(16)	38
Contributions from parent		43	0
Payment of common stock dividends to parent		(81)	(122)
Other financing activities		(1)	(1)
Net cash provided by (used in) financing activities		45	(85)
Cash and Cash Equivalents, Period Increase (Decrease)		4	2
Cash and Cash Equivalents at Beginning of Period		15	5
Cash and Cash Equivalents at End of Period		19	7
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		57	40
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net Income	[2]	148	119
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		138	121
Amortization		2	6
Defined benefit plans - (income) expense		0	2
Deferred income taxes and investment tax credits		9	70
Other		(1)	0
Change in current assets and current liabilities
Accounts receivable		4	5
Accounts payable		11	(1)
Accounts payable to affiliates		(12)	(15)
Unbilled revenues		16	9
Fuel, materials and supplies		(5)	8
Taxes payable		4	(29)
Regulatory assets and liabilities, net		37	(4)
Other		(11)	(9)
Other operating activities
Defined benefit plans - funding		(52)	(21)
Expenditures for asset retirement obligations		(16)	(5)
Other assets		(1)	(3)
Other liabilities		3	4
Net cash provided by operating activities		274	257
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(266)	(177)
Net cash used in investing activities		(266)	(177)
Cash Flows from Financing Activities
Net increase (decrease) in short-term debt		88	35
Contributions from parent		45	0
Payment of common stock dividends to parent		(136)	(110)
Net cash provided by (used in) financing activities		(3)	(75)
Cash and Cash Equivalents, Period Increase (Decrease)		5	5
Cash and Cash Equivalents at Beginning of Period		15	7
Cash and Cash Equivalents at End of Period		20	12
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		$ 55	$ 43

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Jun. 30, 2018	Dec. 31, 2017
Assets, Current [Abstract]
Cash and cash equivalents		$ 852	$ 485
Accounts receivable (less reserve:)
Customer		675	681
Other		66	100
Unbilled revenues		453	543
Fuel, materials and supplies		288	320
Prepayments		126	66
Price risk management assets		78	49
Regulatory assets		27	34
Other current assets		62	50
Total Current Assets		2,600	2,294
Property, Plant and Equipment
Regulated utility plant		38,999	38,228
Less: accumulated depreciation - regulated utility plant		7,083	6,785
Regulated utility plant, net		31,916	31,443
Non-regulated property, plant and equipment		370	384
Less: accumulated depreciation - non-regulated property, plant and equipment		108	110
Non-regulated property, plant and equipment, net		262	274
Construction work in progress		1,645	1,375
Property, Plant and Equipment, net		33,823	33,092
Other Noncurrent Assets
Regulatory assets		1,530	1,504
Goodwill		3,308	3,258
Other intangibles		694	697
Pension benefit asset		498	284
Price risk management assets		185	215
Other noncurrent assets		192	135
Total Other Noncurrent Assets		6,407	6,093
Total Assets		42,830	41,479
Current Liabilities
Short-term debt		1,864	1,080
Long-term debt due within one year		203	348
Accounts payable		804	924
Taxes		132	105
Interest		203	282
Dividends		287	273
Customer deposits		271	292
Regulatory liabilities		137	95
Other current liabilities		547	624
Total Current Liabilities		4,448	4,023
Long-term Debt
Long-term Debt		20,217	19,847
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		2,632	2,462
Investment tax credits		128	129
Accrued pension obligations		665	800
Asset retirement obligations		297	312
Regulatory liabilities		2,747	2,704
Other deferred credits and noncurrent liabilities		456	441
Total Deferred Credits and Other Noncurrent Liabilities		6,925	6,848
Commitments and Contingent Liabilities
Equity
Common stock	[1]	7	7
Additional paid-in capital		10,462	10,305
Earnings reinvested		4,266	3,871
Accumulated other comprehensive loss		(3,495)	(3,422)
Total Equity		11,240	10,761
Total Liabilities and Equity		42,830	41,479
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		489	49
Accounts receivable (less reserve:)
Customer		289	279
Other		23	71
Accounts receivable from affiliates		11	0
Unbilled revenues		97	127
Fuel, materials and supplies		28	34
Prepayments		53	6
Regulatory assets		16	16
Other current assets		13	6
Total Current Assets		1,019	588
Property, Plant and Equipment
Regulated utility plant		11,140	10,785
Less: accumulated depreciation - regulated utility plant		2,815	2,778
Regulated utility plant, net		8,325	8,007
Construction work in progress		586	508
Property, Plant and Equipment, net		8,911	8,515
Other Noncurrent Assets
Regulatory assets		737	709
Other intangibles		260	259
Other noncurrent assets		56	11
Total Other Noncurrent Assets		1,053	979
Total Assets		10,983	10,082
Current Liabilities
Accounts payable		374	386
Accounts payable to affiliates		29	31
Taxes		7	8
Interest		37	36
Regulatory liabilities		66	86
Other current liabilities		99	98
Total Current Liabilities		612	645
Long-term Debt
Long-term Debt		3,693	3,298
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,225	1,154
Accrued pension obligations		212	246
Regulatory liabilities		692	668
Other deferred credits and noncurrent liabilities		131	79
Total Deferred Credits and Other Noncurrent Liabilities		2,260	2,147
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		3,154	2,729
Earnings reinvested		900	899
Total Equity		4,418	3,992
Total Liabilities and Equity		10,983	10,082
LG And E And KU Energy LLC [Member]
Assets, Current [Abstract]
Cash and cash equivalents		39	30
Accounts receivable (less reserve:)
Customer		229	246
Other		45	44
Unbilled revenues		163	203
Fuel, materials and supplies		229	254
Prepayments		31	25
Regulatory assets		11	18
Other current assets		6	8
Total Current Assets		753	828
Property, Plant and Equipment
Regulated utility plant		13,346	13,187
Less: accumulated depreciation - regulated utility plant		1,955	1,785
Regulated utility plant, net		11,391	11,402
Construction work in progress		880	627
Property, Plant and Equipment, net		12,271	12,029
Other Noncurrent Assets
Regulatory assets		793	795
Goodwill		996	996
Other intangibles		82	86
Other noncurrent assets		75	68
Total Other Noncurrent Assets		1,946	1,945
Total Assets		14,970	14,802
Current Liabilities
Short-term debt		316	244
Long-term debt due within one year		203	98
Notes payable with affiliates		99	225
Accounts payable		266	338
Accounts payable to affiliates		8	7
Taxes		41	66
Price risk management liabilities		4	4
Interest		32	32
Customer deposits		59	58
Regulatory liabilities		71	9
Asset retirement obligations		84	85
Other current liabilities		124	161
Total Current Liabilities		1,307	1,327
Long-term Debt
Long-term debt		4,657	4,661
Long-term debt to affiliate		650	400
Long-term Debt		5,307	5,061
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		878	866
Investment tax credits		127	129
Accrued pension obligations		259	365
Asset retirement obligations		248	271
Regulatory liabilities		2,055	2,036
Price risk management liabilities		17	22
Other deferred credits and noncurrent liabilities		140	162
Total Deferred Credits and Other Noncurrent Liabilities		3,724	3,851
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(86)	(88)
Member's Equity		4,632	4,563
Total Liabilities and Equity		14,970	14,802
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		19	15
Accounts receivable (less reserve:)
Customer		104	116
Other		14	13
Accounts receivable from affiliates		18	24
Unbilled revenues		67	91
Fuel, materials and supplies		100	131
Prepayments		16	11
Regulatory assets		11	12
Other current assets		2	3
Total Current Assets		351	416
Property, Plant and Equipment
Regulated utility plant		5,653	5,587
Less: accumulated depreciation - regulated utility plant		678	614
Regulated utility plant, net		4,975	4,973
Construction work in progress		455	305
Property, Plant and Equipment, net		5,430	5,278
Other Noncurrent Assets
Regulatory assets		406	411
Goodwill		389	389
Other intangibles		50	53
Other noncurrent assets		23	12
Total Other Noncurrent Assets		868	865
Total Assets		6,649	6,559
Current Liabilities
Short-term debt		183	199
Long-term debt due within one year		194	98
Accounts payable		132	179
Accounts payable to affiliates		21	23
Taxes		23	25
Price risk management liabilities		4	4
Interest		11	11
Customer deposits		28	27
Regulatory liabilities		34	3
Asset retirement obligations		17	24
Other current liabilities		47	52
Total Current Liabilities		694	645
Long-term Debt
Long-term Debt		1,614	1,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		581	572
Investment tax credits		34	35
Accrued pension obligations		0	45
Asset retirement obligations		95	97
Regulatory liabilities		922	919
Price risk management liabilities		17	22
Other deferred credits and noncurrent liabilities		81	86
Total Deferred Credits and Other Noncurrent Liabilities		1,730	1,776
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,755	1,712
Earnings reinvested		432	391
Total Equity		2,611	2,527
Total Liabilities and Equity		6,649	6,559
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		20	15
Accounts receivable (less reserve:)
Customer		125	130
Other		31	30
Unbilled revenues		96	112
Fuel, materials and supplies		129	123
Prepayments		15	14
Regulatory assets		0	6
Other current assets		4	5
Total Current Assets		420	435
Property, Plant and Equipment
Regulated utility plant		7,683	7,592
Less: accumulated depreciation - regulated utility plant		1,275	1,170
Regulated utility plant, net		6,408	6,422
Construction work in progress		424	321
Property, Plant and Equipment, net		6,832	6,743
Other Noncurrent Assets
Regulatory assets		387	384
Goodwill		607	607
Other intangibles		32	33
Other noncurrent assets		75	52
Total Other Noncurrent Assets		1,101	1,076
Total Assets		8,353	8,254
Current Liabilities
Short-term debt		133	45
Long-term debt due within one year		9	0
Accounts payable		121	137
Accounts payable to affiliates		42	53
Taxes		23	19
Interest		16	16
Customer deposits		31	31
Regulatory liabilities		37	6
Asset retirement obligations		67	61
Other current liabilities		35	46
Total Current Liabilities		514	414
Long-term Debt
Long-term Debt		2,320	2,328
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		690	691
Investment tax credits		93	94
Accrued pension obligations		0	36
Asset retirement obligations		153	174
Regulatory liabilities		1,133	1,117
Other deferred credits and noncurrent liabilities		36	43
Total Deferred Credits and Other Noncurrent Liabilities		2,105	2,155
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,661	2,616
Earnings reinvested		445	433
Total Equity		3,414	3,357
Total Liabilities and Equity		$ 8,353	$ 8,254

[1] 1,560,000 shares authorized; 699,128 and 693,398 shares issued and outstanding at June 30, 2018 and December 31, 2017.

[2] 170,000 shares authorized; 66,368 shares issued and outstanding at June 30, 2018 and December 31, 2017.

[3] 75,000 shares authorized; 21,294 shares issued and outstanding at June 30, 2018 and December 31, 2017.

[4] 80,000 shares authorized; 37,818 shares issued and outstanding at June 30, 2018 and December 31, 2017.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 55	$ 51
Equity
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,560,000	1,560,000
Common stock shares issued (in shares)	699,128	693,398
Common stock shares outstanding (in shares)	699,128	693,398
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 27	$ 24
Equity
Common stock, no par value (in dollars per share)	$ 0.00	$ 0.00
Common stock shares authorized (in shares)	170,000	170,000
Common stock shares issued (in shares)	66,368	66,368
Common stock shares outstanding (in shares)	66,368	66,368
LG And E And KU Energy LLC [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 26	$ 25
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 1	$ 1
Equity
Common stock, no par value (in dollars per share)	$ 0.00	$ 0.00
Common stock shares authorized (in shares)	75,000	75,000
Common stock shares issued (in shares)	21,294	21,294
Common stock shares outstanding (in shares)	21,294	21,294
Kentucky Utilities Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 1	$ 1
Equity
Common stock, no par value (in dollars per share)	$ 0.00	$ 0.00
Common stock shares authorized (in shares)	80,000	80,000
Common stock shares issued (in shares)	37,818	37,818
Common stock shares outstanding (in shares)	37,818	37,818

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions		Total	Common Stock [Member]		Additional Paid-in Capital [Member]	Earnings Reinvested [Member]	Accumulated Other Comprehensive Loss [Member]	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member] Common Stock [Member]		PPL Electric Utilities Corp [Member] Additional Paid-in Capital [Member]	PPL Electric Utilities Corp [Member] Earnings Reinvested [Member]	LG And E And KU Energy LLC [Member]		Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member] Common Stock [Member]		Louisville Gas And Electric Co [Member] Additional Paid-in Capital [Member]	Louisville Gas And Electric Co [Member] Earnings Reinvested [Member]	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member] Common Stock [Member]		Kentucky Utilities Co [Member] Additional Paid-in Capital [Member]	Kentucky Utilities Co [Member] Earnings Reinvested [Member]	Kentucky Utilities Co [Member] Accumulated Other Comprehensive Loss [Member]
Balance at beginning of period - shares at Dec. 31, 2016			679,731	[1]						66,368	[2]							21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2016		$ 9,899	$ 7		$ 9,841	$ 3,829	$ (3,778)	$ 3,391		$ 364		$ 2,154	$ 873			$ 2,476		$ 424		$ 1,682	$ 370	$ 3,323		$ 308		$ 2,616	$ 400	$ (1)
Balance at beginning of period at Dec. 31, 2016														$ 4,667
Common stock shares issued	[1]		5,742
Common stock issued		202			202
Stock-based compensation		(20)			(20)
Net Income		695				695		156	[5]				156	190	[6]	96	[5]				96	119	[6]				119
Capital contributions from parent								575				575
Dividends and dividend equivalents		(541)				(541)
Dividends declared on common stock								(154)					(154)			(122)					(122)	(110)					(110)
Distributions to member														(218)
Other comprehensive income (loss)		255					255							(7)								1						1
Balance at end of period - shares at Jun. 30, 2017			685,473	[1]						66,368	[2]							21,294	[3]					37,818	[4]
Balance at end of period at Jun. 30, 2017		$ 10,490	$ 7		10,023	3,983	(3,523)	$ 3,968		$ 364		2,729	875			$ 2,450		$ 424		1,682	344	$ 3,333		$ 308		2,616	409	0
Balance at end of period at Jun. 30, 2017														4,632
Balance at beginning of period - shares at Dec. 31, 2017		693,398	693,398	[1]				66,368		66,368	[2]					21,294		21,294	[3]			37,818		37,818	[4]
Balance at beginning of period at Dec. 31, 2017		$ 10,761	$ 7		10,305	3,871	(3,422)	$ 3,992		$ 364		2,729	899			$ 2,527		$ 424		1,712	391	$ 3,357		$ 308		2,616	433	0
Balance at beginning of period at Dec. 31, 2017														4,563
Common stock shares issued	[1]		5,730
Common stock issued		163			163
Stock-based compensation		(6)			(6)
Net Income		967				967		223	[5]				223	228	[6]	122	[5]				122	148	[6]				148
Capital contributions from parent								425				425				43				43		45				45
Dividends and dividend equivalents		(572)				(572)
Dividends declared on common stock								$ (222)					(222)			$ (81)					(81)	$ (136)					(136)
Distributions to member														(161)
Other comprehensive income (loss)		$ (73)					(73)							2
Balance at end of period - shares at Jun. 30, 2018		699,128	699,128	[1]				66,368		66,368	[2]					21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Jun. 30, 2018		$ 11,240	$ 7		$ 10,462	$ 4,266	$ (3,495)	$ 4,418		$ 364		$ 3,154	$ 900			$ 2,611		$ 424		$ 1,755	$ 432	$ 3,414		$ 308		$ 2,661	$ 445	$ 0
Balance at end of period at Jun. 30, 2018														$ 4,632

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

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

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

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

[5] Net income equals comprehensive income.

[6] Net income approximates comprehensive income.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical)	6 Months Ended
	Jun. 30, 2018 vote
Vote per share of PPL's common stock	1

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Interim Financial Statements

6 Months Ended

Jun. 30, 2018

Interim Financial Statements [Abstract]

Interim Financial Statements

1. Interim Financial Statements

(All Registrants)

Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each 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, 2017 is derived from that Registrant's 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 2017 Form 10-K. The results of operations for the three and six months ended June 30, 2018 are not necessarily indicative of the results to be expected for the full year ending December 31, 2018 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2018

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

2. Summary of Significant Accounting Policies

(All Registrants)

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

New Accounting Guidance Adopted (All Registrants)

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 as a result of 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, the non-service cost components of net periodic benefit costs were in a net credit position for the three and six months ended June 30, 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 $6 million ($5 million after-tax or $0.01 per share) and $11 million ($9 million after-tax or $0.01 per share) for the three and six months ended June 30, 2018. For PPL Electric, LG&E and 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					Six Months
	2018			2017		2018			2017
PPL	$	66		$	44	$	134		$	82
PPL Electric	1			1		3			—
LKE	—			—		2			(2		)
LG&E	(2		)	—		(1		)	(2		)
KU	1			—		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.

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
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Cash and cash equivalents	$	852	$	485	$	489	$	49
Restricted cash - current (a)	3		3		2		2
Restricted cash - noncurrent (a)	20		23		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	875	$	511	$	491	$	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."

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Segment and Related Information

6 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Segment and Related Information

3. Segment and Related Information

(PPL)

See Note 2 in PPL's 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 June 30 are as follows:

	Three Months						Six Months
	2018			2017			2018			2017
Operating Revenues from external customers
U.K. Regulated	$	584		$	502		$	1,199		$	1,070
Kentucky Regulated	743			723			1,615			1,532
Pennsylvania Regulated	517			500			1,156			1,073
Corporate and Other	4			—			4			1
Total	$	1,848		$	1,725		$	3,974		$	3,676
Net Income
U.K. Regulated (a)	$	394		$	148		$	591		$	434
Kentucky Regulated	77			79			210			174
Pennsylvania Regulated	75			77			223			156
Corporate and Other	(31		)	(12		)	(57		)	(69		)
Total	$	515		$	292		$	967		$	695

(a) Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 14 for additional information.

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

	June 30, 2018		December 31, 2017
Assets
U.K. Regulated (a)	$	16,839	$	16,813
Kentucky Regulated	14,636		14,468
Pennsylvania Regulated	10,995		10,082
Corporate and Other (b)	360		116
Total	$	42,830	$	41,479

(a) Includes $12.6 billion and $12.5 billion of net PP&E as of June 30, 2018 and December 31, 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.

(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.

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Revenue from Contracts with Customers

6 Months Ended

Jun. 30, 2018

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

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.

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.

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 primarily 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 June 30, 2018.

	Three Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,848		$	517		$	743		$	335		$	414
Revenues derived from:
Alternative revenue programs (b)	9			—			9			6			3
Other (c)	(13		)	(2		)	(4		)	(2		)	(2		)
Revenues from Contracts with Customers	$	1,844		$	515		$	748		$	339		$	415

	Six Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	3,974		$	1,156		$	1,615		$	754		$	885
Revenues derived from:
Alternative revenue programs (b)	41			2			39			20			19
Other (c)	(28		)	(6		)	(9		)	(3		)	(6		)
Revenues from Contracts with Customers	$	3,987		$	1,152		$	1,645		$	771		$	898

(a) PPL includes $584 million and $1,199 million for the three and six months ended June 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 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 $414 million and $101 million for the three months ended June 30, 2018 and $946 million and $206 million for the six months ended June 30, 2018.

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

	Three Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	547	$	—	$	—	$	—	$	—
Residential	588		300		288		146		142
Commercial	296		89		207		107		100
Industrial	155		12		143		45		98
Other (b)	114		13		67		30		37
Wholesale - municipal	31		—		31		—		31
Wholesale - other (c)	12		—		12		11		7
Transmission	101		101		—		—		—
Revenues from Contracts with Customers	$	1,844	$	515	$	748	$	339	$	415

	Six Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,131	$	—	$	—	$	—	$	—
Residential	1,392		708		684		343		341
Commercial	621		187		434		231		203
Industrial	310		25		285		89		196
Other (b)	220		26		135		61		74
Wholesale - municipal	61		—		61		—		61
Wholesale - other (c)	46		—		46		47		23
Transmission	206		206		—		—		—
Revenues from Contracts with Customers	$	3,987	$	1,152	$	1,645	$	771	$	898

(a) Represents customers of WPD.

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

(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.

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

	Three Months		Six Months
PPL	$	3	$	13
PPL Electric	3		10
LKE	1		3
LG&E	—		1
KU	1		2

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 June 30, 2018	38		14		8		4		3

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

	Six Months
PPL	$	18
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 June 30, 2018, PPL had $70 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $50 million within the next 12 months.

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Earnings Per Share

6 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

Earnings Per Share

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. 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 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 June 30 used in the EPS calculation are:

	Three Months				Six Months
	2018		2017		2018		2017
Income (Numerator)
Net income	$	515	$	292	$	967	$	695
Less amounts allocated to participating securities	—		—		1		1
Net income available to PPL common shareowners - Basic and Diluted	$	515	$	292	$	966	$	694
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	699,006		683,841		696,772		682,370
Add incremental non-participating securities:
Share-based payment awards	173		2,510		491		2,355
Forward sale agreements	1,797		—		898		—
Weighted-average shares - Diluted EPS	700,976		686,351		698,161		684,725
Basic EPS
Net Income available to PPL common shareowners	$	0.74	$	0.43	$	1.39	$	1.02
Diluted EPS
Net Income available to PPL common shareowners	$	0.73	$	0.43	$	1.38	$	1.01

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

	Three Months		Six Months
	2018	2017	2018	2017
Stock-based compensation plans (a)	12	564	488	1,451
DRIP	526	369	1,011	814

(a) Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors.

See Note 8 for additional information on common stock issued under the ATM Program.

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

	Three Months		Six Months
	2018	2017	2018	2017
Stock options	441	696	336	696
Restricted stock units	23	—	21	—

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Income Taxes

6 Months Ended

Jun. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes

6. Income Taxes

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

(PPL)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	138		$	129		$	257		$	315
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			10			25			23
Valuation allowance adjustments	5			—			12			5
Impact of lower U.K. income tax rates relative to U.S. income tax rates (a)	(6		)	(40		)	(13		)	(88		)
U.S. income tax on foreign earnings - net of foreign tax credit (a) (b)	—			(7		)	1			(16		)
Federal and state tax reserve adjustments	3			—			3			—
Impact of the U.K. Finance Acts	(2		)	(6		)	(3		)	(9		)
Depreciation and other items not normalized	(2		)	(2		)	(4		)	(5		)
Amortization of excess deferred income taxes (a)	(9		)	—			(19		)	—
Deferred tax impact of state tax reform (c)	9			—			9			—
Interest benefit on U.K. financing entities	(4		)	(4		)	(9		)	(8		)
Stock-based compensation	—			(4		)	1			(7		)
Other	—			—			(1		)	(5		)
Total increase (decrease)	4			(53		)	2			(110		)
Total income taxes	$	142		$	76		$	259		$	205

(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 was recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

(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.

(PPL Electric)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	22		$	44		$	63		$	88
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	8			9			24			17
Depreciation and other items not normalized	(1		)	(2		)	(3		)	(4		)
Amortization of excess deferred income taxes (a)	(3		)	—			(8		)	—
Stock-based compensation	—			(3		)	—			(5		)
Other	1			(1		)	—			(1		)
Total increase (decrease)	5			3			13			7
Total income taxes	$	27		$	47		$	76		$	95

(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						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	25		$	49		$	63		$	107
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	3			5			11			11
Deferred tax impact of state tax reform (c)	9			—			9			—
Amortization of excess deferred income taxes (a)	(6		)	—			(11		)	—
Other	—			(1		)	(2		)	(2		)
Total increase (decrease)	6			4			7			9
Total income taxes	$	31		$	53		$	70		$	116

(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					Six Months
	2018			2017		2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	13		$	24	$	33		$	55
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3		6			6
Amortization of excess deferred income taxes (a)	(3		)	—		(5		)	—
Other	—			—		(1		)	(1		)
Total increase (decrease)	(1		)	3		—			5
Total income taxes	$	12		$	27	$	33		$	60

(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.

(KU)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	16		$	32		$	39		$	67
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3			7			7
Amortization of excess deferred income taxes (a)	(3		)	—			(6		)	—
Other	(1		)	(1		)	(2		)	(1		)
Total increase (decrease)	(2		)	2			(1		)	6
Total income taxes	$	14		$	34		$	38		$	73

(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.

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 reduced tax rate, related to the remeasurement of deferred income taxes, as an increase in regulatory liabilities of $16 million and $19 million. LG&E and KU continue to evaluate other impacts of Kentucky state tax reform along with the associated regulatory considerations. PPL is evaluating the impact, if any, of unitary or elective consolidated income tax reporting on all its Registrants.

U.S. Tax Reform(All Registrants)

On August 1, 2018, the Department of Treasury and the IRS issued proposed regulations under Internal Revenue Code Section 965 to provide guidance relating to the transition tax upon the mandatory deemed repatriation of certain deferred foreign earnings. On August 3, 2018, the Department of Treasury and the IRS also issued proposed regulations on the new 100 percent depreciation deduction effective for assets placed in service after September 27, 2017. The Registrants are currently reviewing the proposed regulations to determine what, if any, impact the newly issued guidance may have on their financial statements.

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Utility Rate Regulation

6 Months Ended

Jun. 30, 2018

Regulated Operations [Abstract]

Utility Rate Regulation

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
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—
Smart meter rider	15		15		15		15
Plant outage costs	6		3		—		—
Gas supply clause	5		4		—		—
Other	1		1		1		1
Total current regulatory assets (a)	$	27	$	34	$	16	$	16
Noncurrent Regulatory Assets:
Defined benefit plans	$	857	$	880	$	491	$	504
Taxes recoverable through future rates	3		3		3		3
Storm costs (b)	47		33		21		—
Unamortized loss on debt	49		54		25		29
Interest rate swaps	21		26		—		—
Terminated interest rate swaps	89		92		—		—
Accumulated cost of removal of utility plant	182		173		182		173
AROs	260		234		—		—
Act 129 compliance rider	15		—		15		—
Other	7		9		—		—
Total noncurrent regulatory assets	$	1,530	$	1,504	$	737	$	709

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Generation supply charge	$	30	$	34	$	30	$	34
Transmission service charge	4		9		4		9
Environmental cost recovery	25		1		—		—
Universal service rider	20		26		20		26
Transmission formula rate	11		9		11		9
Fuel adjustment clause	5		3		—		—
TCJA customer refund (c)	33		—		—		—
Storm damage expense rider	1		8		1		8
Other	8		5		—		—
Total current regulatory liabilities	$	137	$	95	$	66	$	86
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	—	$	—
Power purchase agreement - OVEC (d)	64		68		—		—
Net deferred taxes (e)	1,858		1,853		652		668
Defined benefit plans	31		27		—		—
Terminated interest rate swaps	72		74		—		—
TCJA customer refund (f)	37		—		37		—
Other	7		5		3		—
Total noncurrent regulatory liabilities	$	2,747	$	2,704	$	692	$	668

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—		—		6
Plant outage costs	6		3		6		3		—		—
Gas supply clause	5		4		5		4		—		—
Total current regulatory assets	$	11	$	18	$	11	$	12	$	—	$	6
Noncurrent Regulatory Assets:
Defined benefit plans	$	366	$	376	$	231	$	234	$	135	$	142
Storm costs	26		33		14		18		12		15
Unamortized loss on debt	24		25		15		16		9		9
Interest rate swaps	21		26		21		26		—		—
Terminated interest rate swaps	89		92		52		54		37		38
AROs	260		234		71		61		189		173
Other	7		9		2		2		5		7
Total noncurrent regulatory assets	$	793	$	795	$	406	$	411	$	387	$	384

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Environmental cost recovery	$	25	$	1	$	14	$	—	$	11	$	1
Fuel adjustment clause	5		3		1		—		4		3
Gas line tracker	2		3		2		3		—		—
TCJA customer refund (c)	33		—		15		—		18		—
Other	6		2		2		—		4		2
Total current regulatory liabilities	$	71	$	9	$	34	$	3	$	37	$	6
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	280	$	282	$	398	395
Power purchase agreement - OVEC (d)	64		68		44		47		20		21
Net deferred taxes (e)	1,206		1,185		561		552		645		633
Defined benefit plans	31		27		—		—		31		27
Terminated interest rate swaps	72		74		36		37		36		37
Other	4		5		1		1		3		4
Total noncurrent regulatory liabilities	$	2,055	$	2,036	$	922	$	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 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)

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 full deployment is expected to be completed in 2021 with estimated capital costs of $155 million and $104 million for KU and LG&E electric service and $62 million for LG&E gas service. The full Advanced Metering Systems deployment is expected to result in incremental operation and maintenance costs during the deployment phase of $17 million and $11 million for KU and LG&E electric service and $3 million for LG&E gas service. A hearing on this matter was held July 24, 2018. LG&E and KU cannot predict the outcome of this proceeding.

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. 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. Ongoing tax savings are also expected to be addressed in LG&E's and KU's next Kentucky base rate case. LG&E and KU have indicated their intent to file an application for base rate changes during 2018 to be effective during spring 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. On March 30, 2018, following receipt of the Attorney General's response, the KPSC issued an Order amending its March 28, 2018 Order to allow the parties to raise any relevant issues related to the TCJA. A hearing on this matter was held May 24, 2018. Post-hearing briefs have been filed and the case is now submitted to the KPSC for a decision.

LG&E and KU cannot predict the outcome of these proceedings.

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 requesting the KPSC to review and rule upon the recoverability of the franchise fee.

On March 14, 2018, the KPSC issued an order authorizing the franchise fee to be recovered only from LG&E's Louisville/Jefferson County customers in the franchise area. As a result, the franchise fee will continue to be zero in accordance with the 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 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 $37 million relates to the period January 1, 2018 through June 30, 2018 and has been recorded as a noncurrent regulatory liability to be distributed to customers pursuant to a future rate adjustment. The remaining $35 million is the estimated impact for the period July 1, 2018 through December 31, 2018 and will be passed back to customers through the negative surcharge beginning July 1, 2018.

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 Federal Energy Regulatory Commission, 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 joint transmission owners filing, submitted comments in response to the FERC's March 15, 2018 Notice of Inquiry. The filing submitted by the PJM joint transmission owners 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 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 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 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.

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 six months ended June 30, 2018, PPL Electric purchased $297 million and $673 million of accounts receivable from alternate suppliers. During the three and six months ended June 30, 2017, PPL Electric purchased $288 million and $644 million of accounts receivable from alternate suppliers.

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Financing Activities

6 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Financing Activities

8. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and 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:

	June 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
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2023	£	210	£	150	£	—	£	60	£	148	£	—
Term Loan Facility (b)	Dec. 2018	130		130		—		—		—		—
WPD (South West)
Syndicated Credit Facility	July 2021	245		—		—		245		—		—
WPD (East Midlands)
Syndicated Credit Facility (c)	July 2021	300		99		—		201		180		—
WPD (West Midlands)
Syndicated Credit Facility (d)	July 2021	300		34		—		266		120		—
Uncommitted Credit Facilities		130		—		4		126		—		4
Total U.K. Credit Facilities (e)		£	1,315	£	413	£	4	£	898	£	448	£	4
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2023	$	950	$	—	$	950	$	—	$	—	$	230
Syndicated Credit Facility	Nov. 2018	300		—		49		251		—		—
Bilateral Credit Facility	Mar. 2019	100		—		20		80		—		18
Total PPL Capital Funding Credit Facilities		$	1,350	$	—	$	1,019	$	331	$	—	$	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	$	—	$	183	$	317	$	—	$	199
Term Loan Credit Facility	Oct. 2019	200		200		—		—		100		—
Total LG&E Credit Facilities		$	700	$	200	$	183	$	317	$	100	$	199
KU
Syndicated Credit Facility	Jan. 2023	$	400	$	—	$	133	$	267	$	—	$	45
Letter of Credit Facility	Oct. 2020	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	331	$	267	$	—	$	243

(a) The amounts borrowed at June 30, 2018 and December 31, 2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at 2.81% and 2.17%. The unused capacity reflects the amount borrowed in GBP of £150 million as of the date borrowed.

(b) The amount borrowed at June 30, 2018 was a GBP-denominated borrowing which equated to $173 million and bore interest at 1.75%.

(c) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $132 millionand $244 million and bore interest at 0.90% and 0.89%.

(d) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $45 million and $162 million and bore interest at 0.90% and 0.89%.

(e) At June 30, 2018, the unused capacity under the U.K. credit facilities was $1.2 billion.

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:

	June 30, 2018							December 31, 2017
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	2.42%	$	1,000	$	999	$	1	1.64%	$	230
PPL Electric		650		—		650			—
LG&E	2.33%	350		183		167		1.83%	199
KU	2.34%	350		133		217		1.97%	45
Total		$	2,350	$	1,315	$	1,035		$	474

(PPL Electric, LKE, and LG&E)

See Note 11 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

In March 2018, WPD (South Wales) issued £30 million of 0.01% Index-linked Senior Notes due 2036. WPD (South Wales) received proceeds of £31 million, which equated to $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 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.

(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 and for general corporate purposes.

(PPL, LKE and LG&E)

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

In May 2018, the County of Trimble, 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.

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.

(PPL, LKE and KU)

In July 2018, KU redeemed, at par, its $9 million County of Trimble, Kentucky, Environmental Facilities Revenue Bonds, 2007 Series A (Kentucky Utilities Company Project) due 2037.

(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 with 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. Settlement of these forward sale agreements will occur no later than November 2019. Upon any physical settlement 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. PPL will not receive any proceeds or issue any shares of common stock until settlement of the forward sale agreements. PPL intends to use any net proceeds that it receives upon settlement for general corporate purposes.

The forward sale agreements are classified as equity transactions. As a result, no amounts will be recorded in the consolidated financial statements until the settlement of the forward sale agreements. Prior to any settlements, 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.

ATM Program

In February 2018, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $1.0 billion of its common stock through an at-the-market offering program; including a forward sales component. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. PPL issued 1.2 million and 4.2 million shares of common stock and received gross proceeds of $34 million and $119 million for the three and six months ended June 30, 2018.

Distributions

In May 2018, PPL declared a quarterly common stock dividend, payable July 2, 2018, of 41.0 cents per share (equivalent to $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.

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Defined Benefits

6 Months Ended

Jun. 30, 2018

Retirement Benefits [Abstract]

Defined Benefits

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 its subsidiaries, and LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	15		$	21		$	18		$	31		$	32		$	42		$	37
Interest cost	39			42			47			44			78			84			94			87
Expected return on plan assets	(62		)	(58		)	(150		)	(127		)	(124		)	(115		)	(300		)	(252		)
Amortization of:
Prior service cost	3			3			—			—			5			5			—			—
Actuarial loss	19			14			38			36			41			34			77			71
Net periodic defined benefit costs (credits) before special termination benefits	14			16			(44		)	(29		)	31			40			(87		)	(57		)
Special termination benefits (a)	—			(1		)	—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	14		$	15		$	(44	)	$	(29	)	$	31		$	41		$	(87	)	$	(57	)

(a) 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LKE
Service cost	$	5		$	5		$	12		$	12
Interest cost	16			18			32			34
Expected return on plan assets	(25		)	(24		)	(51		)	(46		)
Amortization of:
Prior service cost	2			2			4			4
Actuarial loss (a)	8			4			18			15
Net periodic defined benefit costs (b)	$	6		$	5		$	15		$	19

(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 $6 million for the three and six months ended June 30, 2018 and $5 million for the six months ended June 30, 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			3			6			6
Expected return on plan assets	(6		)	(6		)	(11		)	(11		)
Amortization of:
Prior service cost	2			1			3			2
Actuarial loss (a)	1			1			3			4
Net periodic defined benefit costs (b)	$	1		$	—		$	2		$	2

(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 six months ended June 30, 2018 and 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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						Six Months
	2018			2017			2018			2017
PPL
Service cost	$	3		$	2		$	4		$	4
Interest cost	7			6			10			12
Expected return on plan assets	(9		)	(5		)	(13		)	(11		)
Amortization of prior service cost	1			(1		)	—			(1		)
Net periodic defined benefit costs	$	2		$	2		$	1		$	4
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			2			4			4
Expected return on plan assets	(2		)	(2		)	(4		)	(3		)
Amortization of:
Prior service cost	1			—			1			—
Actuarial gain	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	1		$	1		$	2		$	3

(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 11 for 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 June 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				Six Months
	2018		2017		2018		2017
PPL Electric	$	3	$	5	$	7	$	13
LG&E	2		2		4		5
KU	1		1		2		5

(All Registrants)

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

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

10. Commitments and Contingencies

Legal Matters

(All Registrants)

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

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 alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant, which had three coal-fired units retired in 2015. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In July 2014, the court dismissed the 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 District Court issued an order dismissing PPL as a defendant and dismissing the final federal claim against LG&E. On April 13, 2017, the federal District Court issued an order declining to exercise supplemental jurisdiction on the state law claims and dismissed the case in its entirety. On June 16, 2017, the plaintiffs filed a class action complaint in Jefferson Circuit Court, Kentucky, against LG&E 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 and 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 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 sought injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act 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 sought assessment of civil penalties and an award of litigation costs and attorney fees. On December 28, 2017 the U.S. District Court for the Eastern District of Kentucky 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. KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan, and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. PPL, LKE and KU cannot predict the outcome of these matters and an estimate or range of possible losses cannot be determined.

Regulatory Issues(All Registrants)

See Note 7 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

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

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

PPL Electric, LG&E 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 an estimate or range of possible losses 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 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. 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. 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 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 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. 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 the need for further nitrogen oxide reductions from fossil-fueled plants to address interstate impacts. Although PPL, LKE, LG&E and KU are unable to predict the outcome of ongoing and future evaluations by the EPA and the states, such evaluations could potentially result in requirements for nitrogen oxide reductions beyond those currently required under the 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 nonattainment. In July 2013, the EPA finalized nonattainment designations for parts of the country, including part of Jefferson County in Kentucky. 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.

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 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.

Additionally, the March 2017 Executive Order directed the EPA to review its 2015 greenhouse gas rules 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 Clean Power Plan

There continues to be uncertainty about the EPA's regulation of existing coal-fired power plants. In 2015, the EPA had finalized rules imposing GHG emission standards for both new and existing power plants and had proposed a federal implementation plan that would apply to any states that failed to submit an acceptable state implementation plan to reduce GHG emissions on a state-by-state basis (the 2015 EPA Rules).

Following legal challenges to the 2015 EPA Rules, a stay of those rules by the U.S. Supreme Court and the March 2017 Executive Order requiring the EPA to review the 2015 EPA Rules, in October 2017, the EPA proposed to rescind the 2015 EPA Rules and, in December 2017, released an advanced notice of proposed rulemaking for a replacement (Replacement Rules) which contemplates GHG reductions based on "inside the fence" measures implemented at individual plants. The contemplated approach in the Replacement Rules is a more limited approach than that taken in the 2015 EPA Rules which had included assumed increased levels of fuel switching and renewable energy in determining the level of emission reduction required by each state. At present, the 2015 EPA Rules remain stayed and the Replacement Rules have not yet been published.

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 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 are consistent with the EPA's notice of proposed rulemaking on the Replacement Rules.

LG&E and KU are monitoring developments at the state and federal level. Until there is more clarity about the potential requirements that may be imposed under the Replacement Rules and Kentucky's implementation plan, 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 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.

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. On March 1, 2018, the EPA proposed amendments to the CCR rule primarily relating to impoundment closure and remediation requirements. On July 18, 2018, the EPA released a pre-publication copy of a signed 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. 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. Revisions to the current rule could potentially result in additional costs.

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 Franklin County, Kentucky Circuit Court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. 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 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 future.

LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. On January 26, 2018, KU filed an application requesting a CPCN and approval of amendments to the second phase of its compliance plan for 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 beginning in 2015 and continue to record adjustments as required. See Note 16 below and Note 19 in the Registrants' 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 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.

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. 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. 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 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 a review of part two later in 2018.

Superfund and Other Remediation

PPL Electric, LG&E and KU are potentially responsible for investigating, responding to agency inquiries, implementing various preventative measures, and/or remediating contamination under programs other than those described in the 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 about such additional sites to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

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.

As of June 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 the paragraph above. 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.

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 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.

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 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

(LKE and KU)

KU has 68 employees that are represented by the IBEW labor union. Contract negotiations with the IBEW commenced in July 2018. The current three-year agreement, scheduled to expire on August 1, 2018, was extended to August 9, 2018. Although union members voted to reject a recent agreement reached by KU and the IBEW, negotiations are continuing. KU cannot predict the outcome of these negotiations but does not expect the ultimate outcome of this matter, including terms of any potential new agreement, or lack thereof, to have a material impact on KU.

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.

(All Registrants)

The table below details guarantees provided as of June 30, 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." The total recorded liability at June 30, 2018 was $6 million for PPL and not significant for LKE. The total recorded liability at December 31, 2017 was $17 million for PPL and $11 million for LKE. 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 June 30, 2018			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2020
WPD guarantee of pension and other obligations of unconsolidated entities	82		(c)
PPL Electric
Guarantee of inventory value	20		(d)	2020
LKE
Indemnification of lease termination and other divestitures	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.

(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 June 30, 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. 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.

(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 $115 million at June 30, 2018, consisting of LG&E's share of $80 million and KU's share of $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 2017 Form 10-K for additional information on the OVEC power purchase contract.

In March 2018, a sponsor with a pro-rata share of certain OVEC obligations of 4.85% filed for bankruptcy under Chapter 11 and is seeking to reject the OVEC power purchase contract, which action OVEC and certain sponsors are contesting. 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.

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Related Party Transactions

6 Months Ended

Jun. 30, 2018

PPL Electric Utilities Corp [Member]

Related Party Transactions [Line Items]

Related Party Transactions

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 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 June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of June 30, 2018 was $650 million. No balance was outstanding at June 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread.

(LKE)

LKE maintains a $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. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2018 and December 31, 2017, $99 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at June 30, 2018 and December 31, 2017 were 3.50% and 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 June 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 millionten-year note with a PPL affiliate with an interest rate of 3.5%. At June 30, 2018 and December 31, 2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $3 million and $7 million for the three and six months ending June 30, 2018 and 2017.

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 May and November. At June 30, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $2 million for the three and six months ending June 30, 2018.

Other(PPL Electric, LG&E and KU)

See Note 9 for discussions regarding intercompany allocations associated with defined benefits.

LG And E And KU Energy LLC [Member]

Related Party Transactions [Line Items]

Related Party Transactions

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 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 June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of June 30, 2018 was $650 million. No balance was outstanding at June 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread.

(LKE)

LKE maintains a $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. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2018 and December 31, 2017, $99 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at June 30, 2018 and December 31, 2017 were 3.50% and 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 June 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 millionten-year note with a PPL affiliate with an interest rate of 3.5%. At June 30, 2018 and December 31, 2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $3 million and $7 million for the three and six months ending June 30, 2018 and 2017.

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 May and November. At June 30, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $2 million for the three and six months ending June 30, 2018.

Other(PPL Electric, LG&E and KU)

See Note 9 for discussions regarding intercompany allocations associated with defined benefits.

Louisville Gas And Electric Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

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 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 June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of June 30, 2018 was $650 million. No balance was outstanding at June 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread.

(LKE)

LKE maintains a $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. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2018 and December 31, 2017, $99 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at June 30, 2018 and December 31, 2017 were 3.50% and 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 June 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 millionten-year note with a PPL affiliate with an interest rate of 3.5%. At June 30, 2018 and December 31, 2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $3 million and $7 million for the three and six months ending June 30, 2018 and 2017.

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 May and November. At June 30, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $2 million for the three and six months ending June 30, 2018.

Other(PPL Electric, LG&E and KU)

See Note 9 for discussions regarding intercompany allocations associated with defined benefits.

Kentucky Utilities Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

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 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 June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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

Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a revolving line of credit with a PPL Electric subsidiary. In June 2018, the revolving line of credit was increased by $250 million and the limit as of June 30, 2018 was $650 million. No balance was outstanding at June 30, 2018 and December 31, 2017. The interest rates on borrowings are equal to one-month LIBOR plus a spread.

(LKE)

LKE maintains a $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. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At June 30, 2018 and December 31, 2017, $99 million and $225 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at June 30, 2018 and December 31, 2017 were 3.50% and 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 June 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 millionten-year note with a PPL affiliate with an interest rate of 3.5%. At June 30, 2018 and December 31, 2017, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on this note was $3 million and $7 million for the three and six months ending June 30, 2018 and 2017.

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 May and November. At June 30, 2018, the note was reflected in "Long-term debt to affiliate" on the Balance Sheets. The proceeds were used to repay its outstanding notes payable with a PPL Energy Funding subsidiary. Interest expense on this note was $2 million for the three and six months ending June 30, 2018.

Other(PPL Electric, LG&E and KU)

See Note 9 for discussions regarding intercompany allocations associated with defined benefits.

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Other Income (Expense) - net

6 Months Ended

Jun. 30, 2018

Other Income (Expense) Net [Line Items]

Other Income (Expense) - net

12. Other Income (Expense) - net

(PPL)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months					Six Months
	2018		2017			2018		2017
Other Income
Economic foreign currency exchange contracts (Note 14)	$	164	$	(113	)	$	52	$	(156	)
Defined benefit plans - non-service credits (Note 9)	66		44			134		82
Interest income	2		—			2		1
AFUDC - equity component	5		4			10		6
Miscellaneous	—		—			1		9
Total Other Income	237		(65		)	199		(58		)
Other Expense
Charitable contributions	1		1			5		5
Miscellaneous	2		2			3		14
Total Other Expense	3		3			8		19
Other Income (Expense) - net	$	234	$	(68	)	$	191	$	(77	)

(PPL Electric)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months				Six Months
	2018		2017		2018		2017
Other Income
AFUDC - equity component	$	5	$	4	$	10	$	6
Defined benefit plans - non-service credits (Note 9)	1		1		3		—
Miscellaneous	1		—		1		—
Total Other Income	7		5		14		6
Other Expense
Charitable contributions	—		—		1		1
Miscellaneous	—		1		—		1
Total Other Expense	—		1		1		2
Other Income (Expense) - net	$	7	$	4	$	13	$	4

PPL Electric Utilities Corp [Member]

Other Income (Expense) Net [Line Items]

Other Income (Expense) - net

12. Other Income (Expense) - net

(PPL)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months					Six Months
	2018		2017			2018		2017
Other Income
Economic foreign currency exchange contracts (Note 14)	$	164	$	(113	)	$	52	$	(156	)
Defined benefit plans - non-service credits (Note 9)	66		44			134		82
Interest income	2		—			2		1
AFUDC - equity component	5		4			10		6
Miscellaneous	—		—			1		9
Total Other Income	237		(65		)	199		(58		)
Other Expense
Charitable contributions	1		1			5		5
Miscellaneous	2		2			3		14
Total Other Expense	3		3			8		19
Other Income (Expense) - net	$	234	$	(68	)	$	191	$	(77	)

(PPL Electric)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months				Six Months
	2018		2017		2018		2017
Other Income
AFUDC - equity component	$	5	$	4	$	10	$	6
Defined benefit plans - non-service credits (Note 9)	1		1		3		—
Miscellaneous	1		—		1		—
Total Other Income	7		5		14		6
Other Expense
Charitable contributions	—		—		1		1
Miscellaneous	—		1		—		1
Total Other Expense	—		1		1		2
Other Income (Expense) - net	$	7	$	4	$	13	$	4

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Fair Value Measurements

6 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

Fair Value Measurements

13. Fair Value Measurements

(All Registrants)

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

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	852	$	852	$	—	$	—	$	485	$	485	$	—	$	—
Restricted cash and cash equivalents (a)	23		23		—		—		26		26		—		—
Special use funds (a)	65		65		—		—		—		—		—		—
Price risk management assets (b):
Foreign currency contracts	163		—		163		—		163		—		163		—
Cross-currency swaps	100		—		100		—		101		—		101		—
Total price risk management assets	263		—		263		—		264		—		264		—
Total assets	$	1,203	$	940	$	263	$	—	$	775	$	511	$	264	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Foreign currency contracts	53		—		53		—		148		—		148		—
Total price risk management liabilities	$	74	$	—	$	74	$	—	$	174	$	—	$	174	$	—
PPL Electric
Assets
Cash and cash equivalents	$	489	$	489	$	—	$	—	$	49	$	49	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	491	$	491	$	—	$	—	$	51	$	51	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Total assets	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
LG&E
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
KU
Assets
Cash and cash equivalents	$	20	$	20	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	20	$	20	$	—	$	—	$	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.

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 for 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. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.

	June 30, 2018				December 31, 2017
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	20,420	$	23,448	$	20,195	$	23,783
PPL Electric	3,693		3,950		3,298		3,769
LKE	5,510		5,801		5,159		5,670
LG&E	1,808		1,884		1,709		1,865
KU	2,329		2,480		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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Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

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

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

Volumetric Risk

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

• 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 regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 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.

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 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 $28 million obligation to return cash collateral under master netting arrangements at June 30, 2018 and a $20 million obligation to return cash collateral under master netting arrangements at December 31, 2017.

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

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

LKE, LG&E and KU had no cash collateral posted under master netting arrangements at June 30, 2018 and December 31, 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 portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.

Cash Flow Hedges(PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL held no such contracts at June 30, 2018.

For the three and six months ended June 30, 2018 and 2017, PPL had no hedge ineffectiveness associated with interest rate derivatives.

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

For the three and six months ended June 30, 2018 and 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 six months ended June 30, 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At June 30, 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 June 30, 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. There were no contracts outstanding at June 30, 2018.

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

Economic Activity

PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings. At June 30, 2018, the total exposure hedged by PPL was approximately £2.0 billion (approximately $2.8 billion based on contracted rates). These contracts have termination dates ranging from July 2018 through 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 7 for amounts recorded in regulatory assets and regulatory liabilities at June 30, 2018 and December 31, 2017.

See Note 1 in each Registrant's 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.

	June 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
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	$	—	$	—	$	—	$	4	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	5		—		—		—		4		—		—		—
Foreign currency contracts	—		—		73		31		—		—		45		67
Total current	5		—		73		35		4		—		45		71
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		17		—		—		—		22
Cross-currency swaps (b)	95		—		—		—		97		—		—		—
Foreign currency contracts	—		—		90		22		—		—		118		81
Total noncurrent	95		—		90		39		97		—		118		103
Total derivatives	$	100	$	—	$	163	$	74	$	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 June 30, 2018.

							Three Months					Six 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)
	Three Months		Six Months
Cash Flow Hedges:
Interest rate swaps	$	—	$	—		Interest expense	$	(2	)	$	—	$	(4	)	$	—
Cross-currency swaps	23		(1		)	Other income (expense) - net	24			—		12			—
Total	$	23	$	(1	)		$	22		$	—	$	8		$	—
Net Investment Hedges:
Foreign currency contracts	$	12	$	11

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	164		$	52
Interest rate swaps	Interest expense	(2		)	(3		)
	Total	$	162		$	49
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017.

								Three Months					Six 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)
	Three Months			Six Months
Cash Flow Hedges:
Interest rate swaps	$	(2	)	$	(2	)	Interest expense	$	(2	)	$	—	$	(4	)	$	(1	)
Cross-currency swaps	(27		)	(35		)	Interest expense	(1		)	—		—			—
							Other income (expense) - net	(29		)	—		(26		)	—
Total	$	(29	)	$	(37	)		$	(32	)	$	—	$	(30	)	$	(1	)
Net Investment Hedges:
Foreign currency contracts	$	—		$	—

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	(113	)	$	(156	)
Interest rate swaps	Interest expense	(1		)	(3		)
	Total	$	(114	)	$	(159	)
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

(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.

	June 30, 2018				December 31, 2017
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	4	$	—	$	4
Total current	—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		17		—		22
Total noncurrent	—		17		—		22
Total derivatives	$	—	$	21	$	—	$	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 June 30, 2018.

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(1	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

(PPL, LKE, LG&E and KU)

Offsetting Derivative Instruments

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

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

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
June 30, 2018
Treasury Derivatives
PPL	$	263	$	43	$	28	$	192	$	74	$	43	$	—	$	31
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

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 June 30, 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:

	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	17	$	7	$	7
Aggregate fair value of collateral posted on these derivative instruments	—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	17		7		7

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

XML

Asset Retirement Obligations

6 Months Ended

Jun. 30, 2018

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

LG And E And KU Energy LLC [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

Louisville Gas And Electric Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

Kentucky Utilities Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

XML

Accumulated Other Comprehensive Income (Loss)

6 Months Ended

Jun. 30, 2018

Accumulated Other Comprehensive Income (Loss) [Line Items]

Accumulated Other Comprehensive Income (Loss)

16. Accumulated Other Comprehensive Income (Loss)

(PPL and LKE)

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

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives					Defined benefit plans
							Equity investees' AOCI		Prior service costs			Actuarial gain (loss)			Total
PPL
March 31, 2018	$	(973	)	$	(21	)	$	—	$	(7	)	$	(2,278	)	$	(3,279	)
Amounts arising during the period	(250		)	19			—		(1		)	—			(232		)
Reclassifications from AOCI	—			(19		)	—		1			34			16
Net OCI during the period	(250		)	—			—		—			34			(216		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—	$	(7	)	$	(2,244	)	$	(3,495	)

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives						Defined benefit plans
							Equity investees' AOCI			Prior service costs			Actuarial gain (loss)			Total
December 31, 2017	$	(1,089	)	$	(13	)	$	—		$	(7	)	$	(2,313	)	$	(3,422	)
Amounts arising during the period	(134		)	(1		)	—			(1		)	(1		)	(137		)
Reclassifications from AOCI	—			(7		)	—			1			70			64
Net OCI during the period	(134		)	(8		)	—			—			69			(73		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—		$	(7	)	$	(2,244	)	$	(3,495	)
March 31, 2017	$	(1,651	)	$	(14	)	$	(1	)	$	(8	)	$	(2,103	)	$	(3,777	)
Amounts arising during the period	231			(24		)	—			—			(11		)	196
Reclassifications from AOCI	—			25			1			1			31			58
Net OCI during the period	231			1			1			1			20			254
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
December 31, 2016	$	(1,627	)	$	(7	)	$	(1	)	$	(8	)	$	(2,135	)	$	(3,778	)
Amounts arising during the period	207			(30		)	—			—			(11		)	166
Reclassifications from AOCI	—			24			1			1			63			89
Net OCI during the period	207			(6		)	1			1			52			255
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
LKE
March 31, 2018							$	—		$	(9	)	$	(78	)	$	(87	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							—			1			(1		)	—
Net OCI during the period							—			1			—			1
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
December 31, 2017							$	—		$	(9	)	$	(79	)	$	(88	)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			1			2
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
March 31, 2017							$	—		$	(8	)	$	(60	)	$	(68	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			(10		)	(9		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)
December 31, 2016							$	(1	)	$	(8	)	$	(61	)	$	(70	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							1			1			2			4
Net OCI during the period							1			1			(9		)	(7		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)

(PPL)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30.

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2018			2017			2018			2017			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(4	)	$	(5	)	Interest Expense
Cross-currency swaps	24			(29		)	12			(26		)	Other Income (Expense) - net
	—			(1		)	—			—			Interest Expense
Total Pre-tax	22			(32		)	8			(31		)
Income Taxes	(3		)	7			(1		)	7
Total After-tax	19			(25		)	7			(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 (a)	(1		)	(1		)	(1		)	(1		)
Net actuarial loss (a)	(43		)	(40		)	(88		)	(81		)
Total Pre-tax	(44		)	(41		)	(89		)	(82		)
Income Taxes	9			9			18			18
Total After-tax	(35		)	(32		)	(71		)	(64		)
Total reclassifications during the period	$	(16	)	$	(58	)	$	(64	)	$	(89	)

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

LG And E And KU Energy LLC [Member]

Accumulated Other Comprehensive Income (Loss) [Line Items]

Accumulated Other Comprehensive Income (Loss)

16. Accumulated Other Comprehensive Income (Loss)

(PPL and LKE)

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

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives					Defined benefit plans
							Equity investees' AOCI		Prior service costs			Actuarial gain (loss)			Total
PPL
March 31, 2018	$	(973	)	$	(21	)	$	—	$	(7	)	$	(2,278	)	$	(3,279	)
Amounts arising during the period	(250		)	19			—		(1		)	—			(232		)
Reclassifications from AOCI	—			(19		)	—		1			34			16
Net OCI during the period	(250		)	—			—		—			34			(216		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—	$	(7	)	$	(2,244	)	$	(3,495	)

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives						Defined benefit plans
							Equity investees' AOCI			Prior service costs			Actuarial gain (loss)			Total
December 31, 2017	$	(1,089	)	$	(13	)	$	—		$	(7	)	$	(2,313	)	$	(3,422	)
Amounts arising during the period	(134		)	(1		)	—			(1		)	(1		)	(137		)
Reclassifications from AOCI	—			(7		)	—			1			70			64
Net OCI during the period	(134		)	(8		)	—			—			69			(73		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—		$	(7	)	$	(2,244	)	$	(3,495	)
March 31, 2017	$	(1,651	)	$	(14	)	$	(1	)	$	(8	)	$	(2,103	)	$	(3,777	)
Amounts arising during the period	231			(24		)	—			—			(11		)	196
Reclassifications from AOCI	—			25			1			1			31			58
Net OCI during the period	231			1			1			1			20			254
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
December 31, 2016	$	(1,627	)	$	(7	)	$	(1	)	$	(8	)	$	(2,135	)	$	(3,778	)
Amounts arising during the period	207			(30		)	—			—			(11		)	166
Reclassifications from AOCI	—			24			1			1			63			89
Net OCI during the period	207			(6		)	1			1			52			255
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
LKE
March 31, 2018							$	—		$	(9	)	$	(78	)	$	(87	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							—			1			(1		)	—
Net OCI during the period							—			1			—			1
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
December 31, 2017							$	—		$	(9	)	$	(79	)	$	(88	)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			1			2
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
March 31, 2017							$	—		$	(8	)	$	(60	)	$	(68	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			(10		)	(9		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)
December 31, 2016							$	(1	)	$	(8	)	$	(61	)	$	(70	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							1			1			2			4
Net OCI during the period							1			1			(9		)	(7		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)

(PPL)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30.

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2018			2017			2018			2017			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(4	)	$	(5	)	Interest Expense
Cross-currency swaps	24			(29		)	12			(26		)	Other Income (Expense) - net
	—			(1		)	—			—			Interest Expense
Total Pre-tax	22			(32		)	8			(31		)
Income Taxes	(3		)	7			(1		)	7
Total After-tax	19			(25		)	7			(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 (a)	(1		)	(1		)	(1		)	(1		)
Net actuarial loss (a)	(43		)	(40		)	(88		)	(81		)
Total Pre-tax	(44		)	(41		)	(89		)	(82		)
Income Taxes	9			9			18			18
Total After-tax	(35		)	(32		)	(71		)	(64		)
Total reclassifications during the period	$	(16	)	$	(58	)	$	(64	)	$	(89	)

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

XML

New Accounting Guidance Pending Adoption

6 Months Ended

Jun. 30, 2018

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Description of New Accounting Pronouncements Not yet Adopted [Text Block]

17. New Accounting Guidance Pending Adoption

(All Registrants)

Accounting for Leases

In February 2016, the 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 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. One of these practical expedients allows entities to elect to (1) not reassess whether existing contracts contain leases, (2) carryforward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases. In January 2018, the FASB also issued additional guidance that provides for a practical expedient that allows entities to elect to not evaluate land easements as leases that exist or expired before the 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 as well as the transition method they will use. Key implementation activities in process of being completed include finalizing the lease inventory, concluding on open industry issues and identifying and implementing new controls and processes. The Registrants will adopt this guidance effective January 1, 2019.

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. 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 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.

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 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.

(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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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2018

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Accounting Pronouncements, Policy

New Accounting Guidance Adopted (All Registrants)

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 as a result of 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, the non-service cost components of net periodic benefit costs were in a net credit position for the three and six months ended June 30, 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 $6 million ($5 million after-tax or $0.01 per share) and $11 million ($9 million after-tax or $0.01 per share) for the three and six months ended June 30, 2018. For PPL Electric, LG&E and 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					Six Months
	2018			2017		2018			2017
PPL	$	66		$	44	$	134		$	82
PPL Electric	1			1		3			—
LKE	—			—		2			(2		)
LG&E	(2		)	—		(1		)	(2		)
KU	1			—		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.

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
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Cash and cash equivalents	$	852	$	485	$	489	$	49
Restricted cash - current (a)	3		3		2		2
Restricted cash - noncurrent (a)	20		23		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	875	$	511	$	491	$	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."

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Fair Value Measurements (Policies)

6 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

Fair Value Transfer, Policy

Transfers between levels are recognized at end-of-reporting-period values.

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Derivative Instruments and Hedging Activities (Policies)

6 Months Ended

Jun. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives, Offsetting Fair Value Amounts, Policy

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

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Adoption of Accounting Guidance (Tables)

6 Months Ended

Jun. 30, 2018

Adoption of Accounting Guidance [Abstract]

Schedule of Non-Service Benefits Costs (Credits) [Table Text Block]

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					Six Months
	2018			2017		2018			2017
PPL	$	66		$	44	$	134		$	82
PPL Electric	1			1		3			—
LKE	—			—		2			(2		)
LG&E	(2		)	—		(1		)	(2		)
KU	1			—		2			(1		)

Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement

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

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Cash and cash equivalents	$	852	$	485	$	489	$	49
Restricted cash - current (a)	3		3		2		2
Restricted cash - noncurrent (a)	20		23		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	875	$	511	$	491	$	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."

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Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Segment and Related Information

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

	Three Months						Six Months
	2018			2017			2018			2017
Operating Revenues from external customers
U.K. Regulated	$	584		$	502		$	1,199		$	1,070
Kentucky Regulated	743			723			1,615			1,532
Pennsylvania Regulated	517			500			1,156			1,073
Corporate and Other	4			—			4			1
Total	$	1,848		$	1,725		$	3,974		$	3,676
Net Income
U.K. Regulated (a)	$	394		$	148		$	591		$	434
Kentucky Regulated	77			79			210			174
Pennsylvania Regulated	75			77			223			156
Corporate and Other	(31		)	(12		)	(57		)	(69		)
Total	$	515		$	292		$	967		$	695

(a) Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 14 for additional information.

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

	June 30, 2018		December 31, 2017
Assets
U.K. Regulated (a)	$	16,839	$	16,813
Kentucky Regulated	14,636		14,468
Pennsylvania Regulated	10,995		10,082
Corporate and Other (b)	360		116
Total	$	42,830	$	41,479

(a) Includes $12.6 billion and $12.5 billion of net PP&E as of June 30, 2018 and December 31, 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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Revenue from Contracts with Customers (Tables)

6 Months Ended

Jun. 30, 2018

Revenue from Contracts with Customers [Line Items]

Reconciliation of Revenue from Contracts with Customers [Table Text Block]

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

	Three Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,848		$	517		$	743		$	335		$	414
Revenues derived from:
Alternative revenue programs (b)	9			—			9			6			3
Other (c)	(13		)	(2		)	(4		)	(2		)	(2		)
Revenues from Contracts with Customers	$	1,844		$	515		$	748		$	339		$	415

	Six Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	3,974		$	1,156		$	1,615		$	754		$	885
Revenues derived from:
Alternative revenue programs (b)	41			2			39			20			19
Other (c)	(28		)	(6		)	(9		)	(3		)	(6		)
Revenues from Contracts with Customers	$	3,987		$	1,152		$	1,645		$	771		$	898

(a) PPL includes $584 million and $1,199 million for the three and six months ended June 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 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.

Disaggregation of Revenue [Table Text Block]

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

	Three Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	547	$	—	$	—	$	—	$	—
Residential	588		300		288		146		142
Commercial	296		89		207		107		100
Industrial	155		12		143		45		98
Other (b)	114		13		67		30		37
Wholesale - municipal	31		—		31		—		31
Wholesale - other (c)	12		—		12		11		7
Transmission	101		101		—		—		—
Revenues from Contracts with Customers	$	1,844	$	515	$	748	$	339	$	415

	Six Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,131	$	—	$	—	$	—	$	—
Residential	1,392		708		684		343		341
Commercial	621		187		434		231		203
Industrial	310		25		285		89		196
Other (b)	220		26		135		61		74
Wholesale - municipal	61		—		61		—		61
Wholesale - other (c)	46		—		46		47		23
Transmission	206		206		—		—		—
Revenues from Contracts with Customers	$	3,987	$	1,152	$	1,645	$	771	$	898

(a) Represents customers of WPD.

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

(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.

Credit Loss Recognized from Contracts with Customers [Table Text Block]

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

	Three Months		Six Months
PPL	$	3	$	13
PPL Electric	3		10
LKE	1		3
LG&E	—		1
KU	1		2

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

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 June 30, 2018	38		14		8		4		3

Contract With Customer Liability Revenue Recognized [Table Text Block]

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

	Six Months
PPL	$	18
PPL Electric	8
LKE	8
LG&E	4
KU	4

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

Basic and Diluted EPS Computations

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

	Three Months				Six Months
	2018		2017		2018		2017
Income (Numerator)
Net income	$	515	$	292	$	967	$	695
Less amounts allocated to participating securities	—		—		1		1
Net income available to PPL common shareowners - Basic and Diluted	$	515	$	292	$	966	$	694
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	699,006		683,841		696,772		682,370
Add incremental non-participating securities:
Share-based payment awards	173		2,510		491		2,355
Forward sale agreements	1,797		—		898		—
Weighted-average shares - Diluted EPS	700,976		686,351		698,161		684,725
Basic EPS
Net Income available to PPL common shareowners	$	0.74	$	0.43	$	1.39	$	1.02
Diluted EPS
Net Income available to PPL common shareowners	$	0.73	$	0.43	$	1.38	$	1.01

Common Stock Issuances

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

	Three Months		Six Months
	2018	2017	2018	2017
Stock-based compensation plans (a)	12	564	488	1,451
DRIP	526	369	1,011	814

(a) Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors.

Antidilutive Securities Excluded From Diluted EPS

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

	Three Months		Six Months
	2018	2017	2018	2017
Stock options	441	696	336	696
Restricted stock units	23	—	21	—

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2018

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

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

(PPL)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	138		$	129		$	257		$	315
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			10			25			23
Valuation allowance adjustments	5			—			12			5
Impact of lower U.K. income tax rates relative to U.S. income tax rates (a)	(6		)	(40		)	(13		)	(88		)
U.S. income tax on foreign earnings - net of foreign tax credit (a) (b)	—			(7		)	1			(16		)
Federal and state tax reserve adjustments	3			—			3			—
Impact of the U.K. Finance Acts	(2		)	(6		)	(3		)	(9		)
Depreciation and other items not normalized	(2		)	(2		)	(4		)	(5		)
Amortization of excess deferred income taxes (a)	(9		)	—			(19		)	—
Deferred tax impact of state tax reform (c)	9			—			9			—
Interest benefit on U.K. financing entities	(4		)	(4		)	(9		)	(8		)
Stock-based compensation	—			(4		)	1			(7		)
Other	—			—			(1		)	(5		)
Total increase (decrease)	4			(53		)	2			(110		)
Total income taxes	$	142		$	76		$	259		$	205

(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 was recognized over the annual period as a result of utilizing an estimated annual effective tax rate.

(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.

PPL Electric Utilities Corp [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

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

(PPL Electric)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	22		$	44		$	63		$	88
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	8			9			24			17
Depreciation and other items not normalized	(1		)	(2		)	(3		)	(4		)
Amortization of excess deferred income taxes (a)	(3		)	—			(8		)	—
Stock-based compensation	—			(3		)	—			(5		)
Other	1			(1		)	—			(1		)
Total increase (decrease)	5			3			13			7
Total income taxes	$	27		$	47		$	76		$	95

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

LG And E And KU Energy LLC [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

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

(LKE)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	25		$	49		$	63		$	107
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	3			5			11			11
Deferred tax impact of state tax reform (c)	9			—			9			—
Amortization of excess deferred income taxes (a)	(6		)	—			(11		)	—
Other	—			(1		)	(2		)	(2		)
Total increase (decrease)	6			4			7			9
Total income taxes	$	31		$	53		$	70		$	116

(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.

Louisville Gas And Electric Co [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

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

(LG&E)
	Three Months					Six Months
	2018			2017		2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	13		$	24	$	33		$	55
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3		6			6
Amortization of excess deferred income taxes (a)	(3		)	—		(5		)	—
Other	—			—		(1		)	(1		)
Total increase (decrease)	(1		)	3		—			5
Total income taxes	$	12		$	27	$	33		$	60

(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 Utilities Co [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

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

(KU)
	Three Months						Six Months
	2018			2017			2018			2017
Federal income tax on Income Before Income Taxes at statutory tax rate (a)	$	16		$	32		$	39		$	67
Increase (decrease) due to:
State income taxes, net of federal income tax benefit (b)	2			3			7			7
Amortization of excess deferred income taxes (a)	(3		)	—			(6		)	—
Other	(1		)	(1		)	(2		)	(1		)
Total increase (decrease)	(2		)	2			(1		)	6
Total income taxes	$	14		$	34		$	38		$	73

(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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Utility Rate Regulation (Tables)

6 Months Ended

Jun. 30, 2018

Utility Rate Regulation [Line Items]

Regulatory Assets and Liabilities

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

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—
Smart meter rider	15		15		15		15
Plant outage costs	6		3		—		—
Gas supply clause	5		4		—		—
Other	1		1		1		1
Total current regulatory assets (a)	$	27	$	34	$	16	$	16
Noncurrent Regulatory Assets:
Defined benefit plans	$	857	$	880	$	491	$	504
Taxes recoverable through future rates	3		3		3		3
Storm costs (b)	47		33		21		—
Unamortized loss on debt	49		54		25		29
Interest rate swaps	21		26		—		—
Terminated interest rate swaps	89		92		—		—
Accumulated cost of removal of utility plant	182		173		182		173
AROs	260		234		—		—
Act 129 compliance rider	15		—		15		—
Other	7		9		—		—
Total noncurrent regulatory assets	$	1,530	$	1,504	$	737	$	709

	PPL				PPL Electric
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Generation supply charge	$	30	$	34	$	30	$	34
Transmission service charge	4		9		4		9
Environmental cost recovery	25		1		—		—
Universal service rider	20		26		20		26
Transmission formula rate	11		9		11		9
Fuel adjustment clause	5		3		—		—
TCJA customer refund (c)	33		—		—		—
Storm damage expense rider	1		8		1		8
Other	8		5		—		—
Total current regulatory liabilities	$	137	$	95	$	66	$	86
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	—	$	—
Power purchase agreement - OVEC (d)	64		68		—		—
Net deferred taxes (e)	1,858		1,853		652		668
Defined benefit plans	31		27		—		—
Terminated interest rate swaps	72		74		—		—
TCJA customer refund (f)	37		—		37		—
Other	7		5		3		—
Total noncurrent regulatory liabilities	$	2,747	$	2,704	$	692	$	668

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Assets:
Environmental cost recovery	$	—	$	5	$	—	$	5	$	—	$	—
Generation formula rate	—		6		—		—		—		6
Plant outage costs	6		3		6		3		—		—
Gas supply clause	5		4		5		4		—		—
Total current regulatory assets	$	11	$	18	$	11	$	12	$	—	$	6
Noncurrent Regulatory Assets:
Defined benefit plans	$	366	$	376	$	231	$	234	$	135	$	142
Storm costs	26		33		14		18		12		15
Unamortized loss on debt	24		25		15		16		9		9
Interest rate swaps	21		26		21		26		—		—
Terminated interest rate swaps	89		92		52		54		37		38
AROs	260		234		71		61		189		173
Other	7		9		2		2		5		7
Total noncurrent regulatory assets	$	793	$	795	$	406	$	411	$	387	$	384

	LKE				LG&E				KU
	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Current Regulatory Liabilities:
Environmental cost recovery	$	25	$	1	$	14	$	—	$	11	$	1
Fuel adjustment clause	5		3		1		—		4		3
Gas line tracker	2		3		2		3		—		—
TCJA customer refund (c)	33		—		15		—		18		—
Other	6		2		2		—		4		2
Total current regulatory liabilities	$	71	$	9	$	34	$	3	$	37	$	6
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	678	$	677	$	280	$	282	$	398	395
Power purchase agreement - OVEC (d)	64		68		44		47		20		21
Net deferred taxes (e)	1,206		1,185		561		552		645		633
Defined benefit plans	31		27		—		—		31		27
Terminated interest rate swaps	72		74		36		37		36		37
Other	4		5		1		1		3		4
Total noncurrent regulatory liabilities	$	2,055	$	2,036	$	922	$	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 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.

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Financing Activities (Tables)

6 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The following credit facilities were in place at:

	June 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
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2023	£	210	£	150	£	—	£	60	£	148	£	—
Term Loan Facility (b)	Dec. 2018	130		130		—		—		—		—
WPD (South West)
Syndicated Credit Facility	July 2021	245		—		—		245		—		—
WPD (East Midlands)
Syndicated Credit Facility (c)	July 2021	300		99		—		201		180		—
WPD (West Midlands)
Syndicated Credit Facility (d)	July 2021	300		34		—		266		120		—
Uncommitted Credit Facilities		130		—		4		126		—		4
Total U.K. Credit Facilities (e)		£	1,315	£	413	£	4	£	898	£	448	£	4
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2023	$	950	$	—	$	950	$	—	$	—	$	230
Syndicated Credit Facility	Nov. 2018	300		—		49		251		—		—
Bilateral Credit Facility	Mar. 2019	100		—		20		80		—		18
Total PPL Capital Funding Credit Facilities		$	1,350	$	—	$	1,019	$	331	$	—	$	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	$	—	$	183	$	317	$	—	$	199
Term Loan Credit Facility	Oct. 2019	200		200		—		—		100		—
Total LG&E Credit Facilities		$	700	$	200	$	183	$	317	$	100	$	199
KU
Syndicated Credit Facility	Jan. 2023	$	400	$	—	$	133	$	267	$	—	$	45
Letter of Credit Facility	Oct. 2020	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	331	$	267	$	—	$	243

(a) The amounts borrowed at June 30, 2018 and December 31, 2017 were USD-denominated borrowings of $200 million for both periods, which bore interest at 2.81% and 2.17%. The unused capacity reflects the amount borrowed in GBP of £150 million as of the date borrowed.

(b) The amount borrowed at June 30, 2018 was a GBP-denominated borrowing which equated to $173 million and bore interest at 1.75%.

(c) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $132 millionand $244 million and bore interest at 0.90% and 0.89%.

(d) The amounts borrowed at June 30, 2018 and December 31, 2017 were GBP-denominated borrowings which equated to $45 million and $162 million and bore interest at 0.90% and 0.89%.

(e) At June 30, 2018, the unused capacity under the U.K. credit facilities was $1.2 billion.

Schedule of Short-term Debt

The following commercial paper programs were in place at:

	June 30, 2018							December 31, 2017
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	2.42%	$	1,000	$	999	$	1	1.64%	$	230
PPL Electric		650		—		650			—
LG&E	2.33%	350		183		167		1.83%	199
KU	2.34%	350		133		217		1.97%	45
Total		$	2,350	$	1,315	$	1,035		$	474

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Defined Benefits (Tables)

6 Months Ended

Jun. 30, 2018

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule Of Net Periodic Defined Benefit Costs (Credits)

Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE and its subsidiaries, and LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	15		$	21		$	18		$	31		$	32		$	42		$	37
Interest cost	39			42			47			44			78			84			94			87
Expected return on plan assets	(62		)	(58		)	(150		)	(127		)	(124		)	(115		)	(300		)	(252		)
Amortization of:
Prior service cost	3			3			—			—			5			5			—			—
Actuarial loss	19			14			38			36			41			34			77			71
Net periodic defined benefit costs (credits) before special termination benefits	14			16			(44		)	(29		)	31			40			(87		)	(57		)
Special termination benefits (a)	—			(1		)	—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	14		$	15		$	(44	)	$	(29	)	$	31		$	41		$	(87	)	$	(57	)

(a) 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LKE
Service cost	$	5		$	5		$	12		$	12
Interest cost	16			18			32			34
Expected return on plan assets	(25		)	(24		)	(51		)	(46		)
Amortization of:
Prior service cost	2			2			4			4
Actuarial loss (a)	8			4			18			15
Net periodic defined benefit costs (b)	$	6		$	5		$	15		$	19

(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 $6 million for the three and six months ended June 30, 2018 and $5 million for the six months ended June 30, 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			3			6			6
Expected return on plan assets	(6		)	(6		)	(11		)	(11		)
Amortization of:
Prior service cost	2			1			3			2
Actuarial loss (a)	1			1			3			4
Net periodic defined benefit costs (b)	$	1		$	—		$	2		$	2

(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 six months ended June 30, 2018 and 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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						Six Months
	2018			2017			2018			2017
PPL
Service cost	$	3		$	2		$	4		$	4
Interest cost	7			6			10			12
Expected return on plan assets	(9		)	(5		)	(13		)	(11		)
Amortization of prior service cost	1			(1		)	—			(1		)
Net periodic defined benefit costs	$	2		$	2		$	1		$	4
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			2			4			4
Expected return on plan assets	(2		)	(2		)	(4		)	(3		)
Amortization of:
Prior service cost	1			—			1			—
Actuarial gain	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	1		$	1		$	2		$	3

PPL Electric Utilities Corp [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Allocation of Net Periodic Benefit Costs

For the periods ended June 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				Six Months
	2018		2017		2018		2017
PPL Electric	$	3	$	5	$	7	$	13
LG&E	2		2		4		5
KU	1		1		2		5

LG And E And KU Energy LLC [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule Of Net Periodic Defined Benefit Costs (Credits)

Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE and its subsidiaries, and LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	15		$	21		$	18		$	31		$	32		$	42		$	37
Interest cost	39			42			47			44			78			84			94			87
Expected return on plan assets	(62		)	(58		)	(150		)	(127		)	(124		)	(115		)	(300		)	(252		)
Amortization of:
Prior service cost	3			3			—			—			5			5			—			—
Actuarial loss	19			14			38			36			41			34			77			71
Net periodic defined benefit costs (credits) before special termination benefits	14			16			(44		)	(29		)	31			40			(87		)	(57		)
Special termination benefits (a)	—			(1		)	—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	14		$	15		$	(44	)	$	(29	)	$	31		$	41		$	(87	)	$	(57	)

(a) 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LKE
Service cost	$	5		$	5		$	12		$	12
Interest cost	16			18			32			34
Expected return on plan assets	(25		)	(24		)	(51		)	(46		)
Amortization of:
Prior service cost	2			2			4			4
Actuarial loss (a)	8			4			18			15
Net periodic defined benefit costs (b)	$	6		$	5		$	15		$	19

(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 $6 million for the three and six months ended June 30, 2018 and $5 million for the six months ended June 30, 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			3			6			6
Expected return on plan assets	(6		)	(6		)	(11		)	(11		)
Amortization of:
Prior service cost	2			1			3			2
Actuarial loss (a)	1			1			3			4
Net periodic defined benefit costs (b)	$	1		$	—		$	2		$	2

(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 six months ended June 30, 2018 and 2017. This difference is recorded as a regulatory asset.

(b) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $4 million 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						Six Months
	2018			2017			2018			2017
PPL
Service cost	$	3		$	2		$	4		$	4
Interest cost	7			6			10			12
Expected return on plan assets	(9		)	(5		)	(13		)	(11		)
Amortization of prior service cost	1			(1		)	—			(1		)
Net periodic defined benefit costs	$	2		$	2		$	1		$	4
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			2			4			4
Expected return on plan assets	(2		)	(2		)	(4		)	(3		)
Amortization of:
Prior service cost	1			—			1			—
Actuarial gain	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	1		$	1		$	2		$	3

Louisville Gas And Electric Co [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule Of Net Periodic Defined Benefit Costs (Credits)

Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE and its subsidiaries, and LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2018			2017			2018			2017			2018			2017			2018			2017
PPL
Service cost	$	15		$	15		$	21		$	18		$	31		$	32		$	42		$	37
Interest cost	39			42			47			44			78			84			94			87
Expected return on plan assets	(62		)	(58		)	(150		)	(127		)	(124		)	(115		)	(300		)	(252		)
Amortization of:
Prior service cost	3			3			—			—			5			5			—			—
Actuarial loss	19			14			38			36			41			34			77			71
Net periodic defined benefit costs (credits) before special termination benefits	14			16			(44		)	(29		)	31			40			(87		)	(57		)
Special termination benefits (a)	—			(1		)	—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	14		$	15		$	(44	)	$	(29	)	$	31		$	41		$	(87	)	$	(57	)

(a) 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.

	Pension Benefits
	Three Months						Six Months
	2018			2017			2018			2017
LKE
Service cost	$	5		$	5		$	12		$	12
Interest cost	16			18			32			34
Expected return on plan assets	(25		)	(24		)	(51		)	(46		)
Amortization of:
Prior service cost	2			2			4			4
Actuarial loss (a)	8			4			18			15
Net periodic defined benefit costs (b)	$	6		$	5		$	15		$	19

(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 $6 million for the three and six months ended June 30, 2018 and $5 million for the six months ended June 30, 2017. This difference is recorded as a regulatory asset.

Allocation of Net Periodic Benefit Costs

For the periods ended June 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				Six Months
	2018		2017		2018		2017
PPL Electric	$	3	$	5	$	7	$	13
LG&E	2		2		4		5
KU	1		1		2		5

Kentucky Utilities Co [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Allocation of Net Periodic Benefit Costs

For the periods ended June 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				Six Months
	2018		2017		2018		2017
PPL Electric	$	3	$	5	$	7	$	13
LG&E	2		2		4		5
KU	1		1		2		5

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Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Guarantees

The table below details guarantees provided as of June 30, 2018.

	Exposure at June 30, 2018			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2020
WPD guarantee of pension and other obligations of unconsolidated entities	82		(c)
PPL Electric
Guarantee of inventory value	20		(d)	2020
LKE
Indemnification of lease termination and other divestitures	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.

(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 June 30, 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. 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.

(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 $115 million at June 30, 2018, consisting of LG&E's share of $80 million and KU's share of $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 2017 Form 10-K for additional information on the OVEC power purchase contract.

In March 2018, a sponsor with a pro-rata share of certain OVEC obligations of 4.85% filed for bankruptcy under Chapter 11 and is seeking to reject the OVEC power purchase contract, which action OVEC and certain sponsors are contesting. 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.

XML

Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2018

PPL Electric Utilities Corp [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services, PPL EU Services and LKS charged the following amounts for the periods ended June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

LG And E And KU Energy LLC [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services, PPL EU Services and LKS charged the following amounts for the periods ended June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

Louisville Gas And Electric Co [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services, PPL EU Services and LKS charged the following amounts for the periods ended June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

Kentucky Utilities Co [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services, PPL EU Services and LKS charged the following amounts for the periods ended June 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.

	Three Months				Six Months
	2018		2017		2018		2017
PPL Electric from PPL Services	$	15	$	44	$	31	$	95
LKE from PPL Services	7		5		14		11
PPL Electric from PPL EU Services	41		15		76		33
LG&E from LKS	39		38		77		82
KU from LKS	43		47		85		91

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Other Income (Expense) - net (Tables)

6 Months Ended

Jun. 30, 2018

Other Income (Expense) Net [Line Items]

Schedule of Other Nonoperating Income (Expense)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months					Six Months
	2018		2017			2018		2017
Other Income
Economic foreign currency exchange contracts (Note 14)	$	164	$	(113	)	$	52	$	(156	)
Defined benefit plans - non-service credits (Note 9)	66		44			134		82
Interest income	2		—			2		1
AFUDC - equity component	5		4			10		6
Miscellaneous	—		—			1		9
Total Other Income	237		(65		)	199		(58		)
Other Expense
Charitable contributions	1		1			5		5
Miscellaneous	2		2			3		14
Total Other Expense	3		3			8		19
Other Income (Expense) - net	$	234	$	(68	)	$	191	$	(77	)

PPL Electric Utilities Corp [Member]

Other Income (Expense) Net [Line Items]

Schedule of Other Nonoperating Income (Expense)

The details of "Other Income (Expense) - net" for the periods ended June 30, were:

	Three Months				Six Months
	2018		2017		2018		2017
Other Income
AFUDC - equity component	$	5	$	4	$	10	$	6
Defined benefit plans - non-service credits (Note 9)	1		1		3		—
Miscellaneous	1		—		1		—
Total Other Income	7		5		14		6
Other Expense
Charitable contributions	—		—		1		1
Miscellaneous	—		1		—		1
Total Other Expense	—		1		1		2
Other Income (Expense) - net	$	7	$	4	$	13	$	4

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

The assets and liabilities measured at fair value were:

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	852	$	852	$	—	$	—	$	485	$	485	$	—	$	—
Restricted cash and cash equivalents (a)	23		23		—		—		26		26		—		—
Special use funds (a)	65		65		—		—		—		—		—		—
Price risk management assets (b):
Foreign currency contracts	163		—		163		—		163		—		163		—
Cross-currency swaps	100		—		100		—		101		—		101		—
Total price risk management assets	263		—		263		—		264		—		264		—
Total assets	$	1,203	$	940	$	263	$	—	$	775	$	511	$	264	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Foreign currency contracts	53		—		53		—		148		—		148		—
Total price risk management liabilities	$	74	$	—	$	74	$	—	$	174	$	—	$	174	$	—
PPL Electric
Assets
Cash and cash equivalents	$	489	$	489	$	—	$	—	$	49	$	49	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	491	$	491	$	—	$	—	$	51	$	51	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Total assets	$	39	$	39	$	—	$	—	$	30	$	30	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
LG&E
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	19	$	19	$	—	$	—	$	15	$	15	$	—	$	—

	June 30, 2018								December 31, 2017
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Liabilities
Price risk management liabilities:
Interest rate swaps	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
Total price risk management liabilities	$	21	$	—	$	21	$	—	$	26	$	—	$	26	$	—
KU
Assets
Cash and cash equivalents	$	20	$	20	$	—	$	—	$	15	$	15	$	—	$	—
Total assets	$	20	$	20	$	—	$	—	$	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.

Fair Value, by Balance Sheet Grouping

The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below.

	June 30, 2018				December 31, 2017
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	20,420	$	23,448	$	20,195	$	23,783
PPL Electric	3,693		3,950		3,298		3,769
LKE	5,510		5,801		5,159		5,670
LG&E	1,808		1,884		1,709		1,865
KU	2,329		2,480		2,328		2,605

(a) Amounts are net of debt issuance costs.

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Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2018

Derivative Instruments And Hedging Activities [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets.

	June 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
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	$	—	$	—	$	—	$	4	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	5		—		—		—		4		—		—		—
Foreign currency contracts	—		—		73		31		—		—		45		67
Total current	5		—		73		35		4		—		45		71
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		17		—		—		—		22
Cross-currency swaps (b)	95		—		—		—		97		—		—		—
Foreign currency contracts	—		—		90		22		—		—		118		81
Total noncurrent	95		—		90		39		97		—		118		103
Total derivatives	$	100	$	—	$	163	$	74	$	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.

Derivative Instruments, Gain (Loss)

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 June 30, 2018.

							Three Months					Six 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)
	Three Months		Six Months
Cash Flow Hedges:
Interest rate swaps	$	—	$	—		Interest expense	$	(2	)	$	—	$	(4	)	$	—
Cross-currency swaps	23		(1		)	Other income (expense) - net	24			—		12			—
Total	$	23	$	(1	)		$	22		$	—	$	8		$	—
Net Investment Hedges:
Foreign currency contracts	$	12	$	11

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	164		$	52
Interest rate swaps	Interest expense	(2		)	(3		)
	Total	$	162		$	49
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017.

								Three Months					Six 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)
	Three Months			Six Months
Cash Flow Hedges:
Interest rate swaps	$	(2	)	$	(2	)	Interest expense	$	(2	)	$	—	$	(4	)	$	(1	)
Cross-currency swaps	(27		)	(35		)	Interest expense	(1		)	—		—			—
							Other income (expense) - net	(29		)	—		(26		)	—
Total	$	(29	)	$	(37	)		$	(32	)	$	—	$	(30	)	$	(1	)
Net Investment Hedges:
Foreign currency contracts	$	—		$	—

Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Six Months
Foreign currency contracts	Other income (expense) - net	$	(113	)	$	(156	)
Interest rate swaps	Interest expense	(1		)	(3		)
	Total	$	(114	)	$	(159	)
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

Derivative Positions Eligible for Offset with Related Cash Collateral

The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
June 30, 2018
Treasury Derivatives
PPL	$	263	$	43	$	28	$	192	$	74	$	43	$	—	$	31
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

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

At June 30, 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:

	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	17	$	7	$	7
Aggregate fair value of collateral posted on these derivative instruments	—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	17		7		7

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

LG And E And KU Energy LLC [Member]

Derivative Instruments And Hedging Activities [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

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

	June 30, 2018				December 31, 2017
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	4	$	—	$	4
Total current	—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		17		—		22
Total noncurrent	—		17		—		22
Total derivatives	$	—	$	21	$	—	$	26

Derivative Instruments, Gain (Loss)

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

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(1	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

Derivative Positions Eligible for Offset with Related Cash Collateral

The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
June 30, 2018
Treasury Derivatives
PPL	$	263	$	43	$	28	$	192	$	74	$	43	$	—	$	31
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

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

At June 30, 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:

	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	17	$	7	$	7
Aggregate fair value of collateral posted on these derivative instruments	—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	17		7		7

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

Louisville Gas And Electric Co [Member]

Derivative Instruments And Hedging Activities [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

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

	June 30, 2018				December 31, 2017
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	4	$	—	$	4
Total current	—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		17		—		22
Total noncurrent	—		17		—		22
Total derivatives	$	—	$	21	$	—	$	26

Derivative Instruments, Gain (Loss)

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

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	1		$	5

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 June 30, 2017. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(1	)	$	(3	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)	$	1

Derivative Positions Eligible for Offset with Related Cash Collateral

The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
June 30, 2018
Treasury Derivatives
PPL	$	263	$	43	$	28	$	192	$	74	$	43	$	—	$	31
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

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

At June 30, 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:

	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	17	$	7	$	7
Aggregate fair value of collateral posted on these derivative instruments	—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	17		7		7

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

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Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2018

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

LG And E And KU Energy LLC [Member]

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

Louisville Gas And Electric Co [Member]

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

Kentucky Utilities Co [Member]

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2017	$	397		$	356		$	121		$	235
Accretion	10			9			3			6
Effect of foreign exchange rates	(1		)	—			—			—
Changes in estimated timing or cost	1			(7		)	(2		)	(5		)
Obligations settled	(26		)	(26		)	(10		)	(16		)
Balance at June 30, 2018	$	381		$	332		$	112		$	220

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Accumulated Other Comprehensive Income (Loss) (Tables)

6 Months Ended

Jun. 30, 2018

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

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

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives					Defined benefit plans
							Equity investees' AOCI		Prior service costs			Actuarial gain (loss)			Total
PPL
March 31, 2018	$	(973	)	$	(21	)	$	—	$	(7	)	$	(2,278	)	$	(3,279	)
Amounts arising during the period	(250		)	19			—		(1		)	—			(232		)
Reclassifications from AOCI	—			(19		)	—		1			34			16
Net OCI during the period	(250		)	—			—		—			34			(216		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—	$	(7	)	$	(2,244	)	$	(3,495	)

	Foreign currency translation adjustments			Unrealized gains (losses)  on qualifying derivatives						Defined benefit plans
							Equity investees' AOCI			Prior service costs			Actuarial gain (loss)			Total
December 31, 2017	$	(1,089	)	$	(13	)	$	—		$	(7	)	$	(2,313	)	$	(3,422	)
Amounts arising during the period	(134		)	(1		)	—			(1		)	(1		)	(137		)
Reclassifications from AOCI	—			(7		)	—			1			70			64
Net OCI during the period	(134		)	(8		)	—			—			69			(73		)
June 30, 2018	$	(1,223	)	$	(21	)	$	—		$	(7	)	$	(2,244	)	$	(3,495	)
March 31, 2017	$	(1,651	)	$	(14	)	$	(1	)	$	(8	)	$	(2,103	)	$	(3,777	)
Amounts arising during the period	231			(24		)	—			—			(11		)	196
Reclassifications from AOCI	—			25			1			1			31			58
Net OCI during the period	231			1			1			1			20			254
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
December 31, 2016	$	(1,627	)	$	(7	)	$	(1	)	$	(8	)	$	(2,135	)	$	(3,778	)
Amounts arising during the period	207			(30		)	—			—			(11		)	166
Reclassifications from AOCI	—			24			1			1			63			89
Net OCI during the period	207			(6		)	1			1			52			255
June 30, 2017	$	(1,420	)	$	(13	)	$	—		$	(7	)	$	(2,083	)	$	(3,523	)
LKE
March 31, 2018							$	—		$	(9	)	$	(78	)	$	(87	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							—			1			(1		)	—
Net OCI during the period							—			1			—			1
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
December 31, 2017							$	—		$	(9	)	$	(79	)	$	(88	)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			1			2
June 30, 2018							$	—		$	(8	)	$	(78	)	$	(86	)
March 31, 2017							$	—		$	(8	)	$	(60	)	$	(68	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							—			1			1			2
Net OCI during the period							—			1			(10		)	(9		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)
December 31, 2016							$	(1	)	$	(8	)	$	(61	)	$	(70	)
Amounts arising during the period							—			—			(11		)	(11		)
Reclassifications from AOCI							1			1			2			4
Net OCI during the period							1			1			(9		)	(7		)
June 30, 2017							$	—		$	(7	)	$	(70	)	$	(77	)

Reclassification out of Other Comprehensive Income (Loss)

The following table presents the gains (losses) and related income taxes for reclassifications from AOCI for the periods ended June 30.

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2018			2017			2018			2017			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(4	)	$	(5	)	Interest Expense
Cross-currency swaps	24			(29		)	12			(26		)	Other Income (Expense) - net
	—			(1		)	—			—			Interest Expense
Total Pre-tax	22			(32		)	8			(31		)
Income Taxes	(3		)	7			(1		)	7
Total After-tax	19			(25		)	7			(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 (a)	(1		)	(1		)	(1		)	(1		)
Net actuarial loss (a)	(43		)	(40		)	(88		)	(81		)
Total Pre-tax	(44		)	(41		)	(89		)	(82		)
Income Taxes	9			9			18			18
Total After-tax	(35		)	(32		)	(71		)	(64		)
Total reclassifications during the period	$	(16	)	$	(58	)	$	(64	)	$	(89	)

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

LG And E And KU Energy LLC [Member]

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

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

LKE
March 31, 2018	$	—		$	(9	)	$	(78	)	$	(87	)
Amounts arising during the period	—			—			1			1
Reclassifications from AOCI	—			1			(1		)	—
Net OCI during the period	—			1			—			1
June 30, 2018	$	—		$	(8	)	$	(78	)	$	(86	)
December 31, 2017	$	—		$	(9	)	$	(79	)	$	(88	)
Reclassifications from AOCI	—			1			1			2
Net OCI during the period	—			1			1			2
June 30, 2018	$	—		$	(8	)	$	(78	)	$	(86	)
March 31, 2017	$	—		$	(8	)	$	(60	)	$	(68	)
Amounts arising during the period	—			—			(11		)	(11		)
Reclassifications from AOCI	—			1			1			2
Net OCI during the period	—			1			(10		)	(9		)
June 30, 2017	$	—		$	(7	)	$	(70	)	$	(77	)
December 31, 2016	$	(1	)	$	(8	)	$	(61	)	$	(70	)
Amounts arising during the period	—			—			(11		)	(11		)
Reclassifications from AOCI	1			1			2			4
Net OCI during the period	1			1			(9		)	(7		)
June 30, 2017	$	—		$	(7	)	$	(70	)	$	(77	)

XML

Summary of Significant Accounting Policies (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Dec. 31, 2016
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 66	$ 44	$ 134	$ 82
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	852		852		$ 485
Restricted Cash, Current	3		3		3
Restricted Cash, Noncurrent	20		20		23
Cash, Cash Equivalents and Restricted Cash	875	490	875	490	511	$ 367
Income Statement impact of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	6		11
Defined Benefit Plan Net Periodic Benefit (Cost) Credit Non Service, After tax	$ 5		$ 9
Defined Benefit Plan Net Periodic Benefit (Cost) Credit NonService, Per Share	$ 0.01		$ 0.01
Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 66	44	$ 134	82
PPL Electric Utilities Corp [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	1	1	3	0
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	489		489		49
Restricted Cash, Current	2		2		2
Restricted Cash, Noncurrent	0		0		0
Cash, Cash Equivalents and Restricted Cash	491	61	491	61	51	15
PPL Electric Utilities Corp [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	1	1	3	0
LG And E And KU Energy LLC [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	39	19	39	19	30	13
LG And E And KU Energy LLC [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	0	0	2	(2)
Louisville Gas And Electric Co [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	19	7	19	7	15	5
Louisville Gas And Electric Co [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	(2)	0	(1)	(2)
Kentucky Utilities Co [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	20	12	20	12	$ 15	$ 7
Kentucky Utilities Co [Member] | Impact of adoption of ASU 2017-07 [Member]
Summary Of Significant Accounting Policies [Line Items]
Defined Benefit Plan, Net Periodic Benefit (Cost) Credit- Non Service	$ 1	$ 0	$ 2	$ (1)

XML

Segment and Related Information (Details) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) Integer		Jun. 30, 2017 USD ($)		Dec. 31, 2017 USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 1,848	$ 1,725	$ 3,974		$ 3,676
Net Income		515	292	967		695
Balance Sheet Data [Abstract]
Assets		42,830		42,830				$ 41,479
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		517	500	1,156		1,073
Net Income	[1]	75	77	223		156
Balance Sheet Data [Abstract]
Assets		10,983		$ 10,983				10,082
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				2
LG And E And KU Energy LLC [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		743	723	$ 1,615		1,532
Net Income		86	87	228	[2]	190	[2]
Balance Sheet Data [Abstract]
Assets		14,970		$ 14,970				14,802
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		335	324	$ 754		715
Net Income	[1]	50	42	122		96
Balance Sheet Data [Abstract]
Assets		6,649		$ 6,649				6,559
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		414	406	$ 885		843
Net Income	[2]	61	56	148		119
Balance Sheet Data [Abstract]
Assets		8,353		$ 8,353				8,254
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
United Kingdom Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		584	502	$ 1,199		1,070
Net Income		394	148	591		434
Balance Sheet Data [Abstract]
Assets		16,839		16,839				16,813
Segment (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		12,600		12,600				12,500
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		743	723	1,615		1,532
Net Income		77	79	210		174
Balance Sheet Data [Abstract]
Assets		14,636		14,636				14,468
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		517	500	1,156		1,073
Net Income		75	77	223		156
Balance Sheet Data [Abstract]
Assets		10,995		10,995				10,082
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		4	0	4		1
Net Income		(31)	$ (12)	(57)		$ (69)
Balance Sheet Data [Abstract]
Assets		$ 360		$ 360				$ 116

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

XML

Revenue from Contracts with Customers (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) Days	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)
Revenue from Contracts with Customers [Line Items]
Operating Revenues	$ 1,848	$ 1,725	$ 3,974	$ 3,676
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	9		41
Other Revenue	(13)		(28)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,844		3,987
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	3		13
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	38		38		$ 29
Contract with Customer, Liability, Revenue Recognized			18
Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	547		1,131
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	588		1,392
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	296		621
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	155		310
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	114		220
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	31		61
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	12		46
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	101		206
Pennsylvania Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	517	500	$ 1,156	1,073
Number Of Days Due From Invoice Date | Days			21
United Kingdom Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	584	502	$ 1,199	1,070
Number Of Days Due From Invoice Date | Days			14
Kentucky Regulated [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	743	723	$ 1,615	1,532
Number Of Days Due From Invoice Date | Days			22
Corporate and Other [Member]
Revenue from Contracts with Customers [Line Items]
Revenue, Remaining Performance Obligation	70		$ 70
Operating Revenues	4	0	4	1
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability, Revenue Recognized			$ 50
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period			12 months
PPL Electric [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			21
LGE [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
KU [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
PPL Electric Utilities Corp [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	517	500	$ 1,156	1,073
Number Of Days Due From Invoice Date | Days			21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	0		$ (2)
Other Revenue	(2)		6
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	515		1,152
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	3		10
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	14		14		19
Contract with Customer, Liability, Revenue Recognized			8
PPL Electric Utilities Corp [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	300		708
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	89		187
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	12		25
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	13		26
PPL Electric Utilities Corp [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
PPL Electric Utilities Corp [Member] | Distribution [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	414		946
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	101		206
LG And E And KU Energy LLC [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	743	723	1,615	1,532
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	9		39
Other Revenue	(4)		(9)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	748		1,645
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	1		3
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	8		8		8
Contract with Customer, Liability, Revenue Recognized			8
LG And E And KU Energy LLC [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	288		684
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	207		434
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	143		285
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	67		135
LG And E And KU Energy LLC [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	31		61
LG And E And KU Energy LLC [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	12		46
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		$ 0
LG And E And KU Energy LLC [Member] | KU [Member]
Revenue from Contracts with Customers [Line Items]
Number Of Days Due From Invoice Date | Days			22
Louisville Gas And Electric Co [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	335	324	$ 754	715
Number Of Days Due From Invoice Date | Days			22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	6		$ 20
Other Revenue	(2)		(3)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	339		771
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	0		1
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	4		4		4
Contract with Customer, Liability, Revenue Recognized			4
Louisville Gas And Electric Co [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	146		343
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	107		231
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	45		89
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	30		61
Louisville Gas And Electric Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Louisville Gas And Electric Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	11		47
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Kentucky Utilities Co [Member]
Revenue from Contracts with Customers [Line Items]
Operating Revenues	414	$ 406	$ 885	$ 843
Number Of Days Due From Invoice Date | Days			22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	3		$ 19
Other Revenue	(2)		(6)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	415		898
Credit Loss from Contracts with Customers [Abstract]
Provision for Doubtful Accounts	1		2
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	3		3		$ 4
Contract with Customer, Liability, Revenue Recognized			4
Kentucky Utilities Co [Member] | Licensed energy suppliers [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0		0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	142		341
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	100		203
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	98		196
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	37		74
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	31		61
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	7		23
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 0		$ 0

XML

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income (Numerator) [Abstract]
Net Income	$ 515	$ 292	$ 967	$ 695
Less amounts allocated to participating securities	0	0	1	1
Net income available to PPL common shareowners - Basic	515	292	966	694
Net income available to PPL common shareowners - Diluted	$ 515	$ 292	$ 966	$ 694
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	699,006	683,841	696,772	682,370
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	173	2,510	491	2,355
Forward sale agreements	1,797	0	898	0
Weighted-average shares - Diluted EPS (in shares)	700,976	686,351	698,161	684,725
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.74	$ 0.43	$ 1.39	$ 1.02
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.73	$ 0.43	$ 1.38	$ 1.01
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	12	564	488	1,451
Common stock issued under dividend reinvestment plan (in shares)	526	369	1,011	814
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	441	696	336	696
Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	23	0	21	0

XML

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 138	$ 129	$ 257	$ 315
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	10	10	25	23
Valuation allowance adjustments	5	0	12	5
Impact of lower U.K. income tax rates relative to U.S. income tax rates	(6)	(40)	(13)	(88)
U.S. income tax on foreign earnings - net of foreign tax credit	0	(7)	1	(16)
Federal and state tax reserve adjustments	3	0	3	0
Impact of the U.K. Finance Acts	(2)	(6)	(3)	(9)
Depreciation and other items not normalized	(2)	(2)	(4)	(5)
Amortization of excess deferred income taxes	(9)	0	(19)	0
Deferred tax impact of state tax reform	9	0	9	0
Interest benefit on U.K. financing entities	(4)	(4)	(9)	(8)
Stock-based compensation	0	(4)	1	(7)
Other	0	0	(1)	(5)
Total increase (decrease)	4	(53)	2	(110)
Total income taxes	142	76	259	205
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities			(42)	19
LKE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Deferred Income Tax Expense (Benefit)	9
LGE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	16
KU [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	19
LG And E And KU Energy LLC [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	25	49	63	107
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	3	5	11	11
Amortization of excess deferred income taxes	(6)	0	(11)	0
Deferred tax impact of state tax reform	9	0	9	0
Other	0	(1)	(2)	(2)
Total increase (decrease)	6	4	7	9
Total income taxes	31	53	70	116
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities			(69)	7
LG And E And KU Energy LLC [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Deferred Income Tax Expense (Benefit)	9
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	16
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	19
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	22	44	63	88
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	8	9	24	17
Depreciation and other items not normalized	(1)	(2)	(3)	(4)
Amortization of excess deferred income taxes	(3)	0	(8)	0
Stock-based compensation	0	(3)	0	(5)
Other	1	(1)	0	(1)
Total increase (decrease)	5	3	13	7
Total income taxes	27	47	76	95
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities			27	12
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	13	24	33	55
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	2	3	6	6
Amortization of excess deferred income taxes	(3)	0	(5)	0
Other	0	0	(1)	(1)
Total increase (decrease)	(1)	3	0	5
Total income taxes	12	27	33	60
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities			(32)	3
Louisville Gas And Electric Co [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	16
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	16	32	39	67
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	2	3	7	7
Amortization of excess deferred income taxes	(3)	0	(6)	0
Other	(1)	(1)	(2)	(1)
Total increase (decrease)	(2)	2	(1)	6
Total income taxes	14	$ 34	38	73
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities			$ (37)	$ 4
Kentucky Utilities Co [Member] | Kentucky tax reform [Member]
Income Tax Other Numeric [Abstract]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 19

XML

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Regulatory Assets [Line Items]
Current regulatory assets	$ 27	$ 34
Noncurrent regulatory assets	1,530	1,504
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	5
Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	15	15
Act 129 Compliance Rider [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	15	0
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	857	880
Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	3
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	47	33
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	49	54
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	21	26
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	89	92
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	182	173
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	260	234
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	3
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	4
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	7	9
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	16	16
Noncurrent regulatory assets	737	709
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	15	15
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	15	0
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	491	504
PPL Electric Utilities Corp [Member] | Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	3
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	21	0
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	25	29
PPL Electric Utilities Corp [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	182	173
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	0	0
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	18
Noncurrent regulatory assets	793	795
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	5
LG And E And KU Energy LLC [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	366	376
LG And E And KU Energy LLC [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	26	33
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	25
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	21	26
LG And E And KU Energy LLC [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	89	92
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	260	234
LG And E And KU Energy LLC [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	3
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	4
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	7	9
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	12
Noncurrent regulatory assets	406	411
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	5
Louisville Gas And Electric Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	231	234
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	18
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	15	16
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	21	26
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	52	54
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	71	61
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	3
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	4
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	2	2
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
Noncurrent regulatory assets	387	384
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	6
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	135	142
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	12	15
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	9	9
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	37	38
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	189	173
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 5	$ 7

XML

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 137	$ 95
Noncurrent regulatory liabilities	2,747	2,704
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	30	34
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	9
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	25	1
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	20	26
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	9
Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	3
Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	8
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	678	677
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	64	68
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,858	1,853
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	31	27
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	74
TCJA bill credit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	33	0
Noncurrent regulatory liabilities	37	0
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	5
Noncurrent regulatory liabilities	7	5
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	66	86
Noncurrent regulatory liabilities	692	668
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	30	34
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	9
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	20	26
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	9
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	8
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	652	668
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | TCJA bill credit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	37	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	3	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	71	9
Noncurrent regulatory liabilities	2,055	2,036
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	25	1
LG And E And KU Energy LLC [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	3
LG And E And KU Energy LLC [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	3
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	678	677
LG And E And KU Energy LLC [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	64	68
LG And E And KU Energy LLC [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,206	1,185
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	31	27
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	74
LG And E And KU Energy LLC [Member] | TCJA bill credit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	33	0
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	2
Noncurrent regulatory liabilities	4	5
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	34	3
Noncurrent regulatory liabilities	922	919
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	0
Louisville Gas And Electric Co [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	0
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	3
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	280	282
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	44	47
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	561	552
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	36	37
Louisville Gas And Electric Co [Member] | TCJA bill credit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	15	0
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	0
Noncurrent regulatory liabilities	1	1
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	37	6
Noncurrent regulatory liabilities	1,133	1,117
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	1
Kentucky Utilities Co [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	3
Kentucky Utilities Co [Member] | Gas Line Tracker [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	398	395
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	20	21
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	645	633
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	31	27
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	36	37
Kentucky Utilities Co [Member] | TCJA bill credit [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	18	0
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	2
Noncurrent regulatory liabilities	$ 3	$ 4

XML

Utility Rate Regulation - Regulatory Matters (Details) - USD ($) $ in Millions					1 Months Ended	6 Months Ended
	Jun. 14, 2018	Mar. 28, 2018	Mar. 20, 2018	Jan. 10, 2018	Aug. 31, 2016	Jun. 30, 2018	May 17, 2018
Pennsylvania Public Utility Commission [Member] | Remaining [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 35
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	35
PPL Electric [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 72
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Negative Surcharge							0.56%
Amended Negative Surcharge	7.05%
Approved Amount Of Rate Reduction Due To TCJA	$ 72
PPL Electric [Member] | Pennsylvania Public Utility Commission [Member] | Current [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	37
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	37
LKE [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers						$ 22
LKE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA		$ 27
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				$ 104
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				11
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
Suspended Amount Of Rate Reduction Due To TCJA		79
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
Suspended Amount Of Rate Reduction Due To TCJA		20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
Suspended Amount Of Rate Reduction Due To TCJA		59
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Gas Service				62
Advanced Metering Systems Deployment Incremental O&M Cost, Gas Service				3
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				155
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				17
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
Suspended Amount Of Rate Reduction Due To TCJA		108
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
Suspended Amount Of Rate Reduction Due To TCJA		21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		70
Suspended Amount Of Rate Reduction Due To TCJA		87
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		70
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 72
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Negative Surcharge							0.56%
Amended Negative Surcharge	7.05%
Approved Amount Of Rate Reduction Due To TCJA	$ 72
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Current [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	37
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	37
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member] | Remaining [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	35
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA	$ 35
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Suspended Additional Amount Of Rate Reduction Due To TCJA		27
LG And E And KU Energy LLC [Member] | LGE [Member]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Franchise Agreement Term					5 years
Days of Notice to Modify Franchise Fee					60 days
Franchise Fee Cap					3.00%
Franchise Fee If Recovered From Customers					0.00%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				104
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				11
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
Suspended Amount Of Rate Reduction Due To TCJA		79
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
Suspended Amount Of Rate Reduction Due To TCJA		20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
Suspended Amount Of Rate Reduction Due To TCJA		59
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Gas Service				62
Advanced Metering Systems Deployment Incremental O&M Cost, Gas Service				3
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				155
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				17
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
Suspended Amount Of Rate Reduction Due To TCJA		108
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
Suspended Amount Of Rate Reduction Due To TCJA		21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		70
Suspended Amount Of Rate Reduction Due To TCJA		87
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		70
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company And Kentucky Utilities [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers						22
Louisville Gas And Electric Co [Member]
Regulatory Matters - Kentucky Activities - Gas Franchise (Numeric) [Abstract]
Franchise Agreement Term					5 years
Days of Notice to Modify Franchise Fee					60 days
Franchise Fee Cap					3.00%
Franchise Fee If Recovered From Customers					0.00%
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers						22
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				104
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				11
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
Suspended Amount Of Rate Reduction Due To TCJA		79
Suspended Additional Amount Of Rate Reduction Due To TCJA		10
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		69
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
Suspended Amount Of Rate Reduction Due To TCJA		20
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		20
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
Suspended Amount Of Rate Reduction Due To TCJA		59
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		49
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Gas Service				62
Advanced Metering Systems Deployment Incremental O&M Cost, Gas Service				3
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member] | Substantially All Through Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		17
Kentucky Utilities Co [Member]
Regulatory Matters - Federal Matters - FERC Transmission Rate Filing [Abstract]
Transmission Expenses Mitigated For Certain Customers						$ 22
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - CPCN and ECR Filings (Numeric) [Abstract]
Advanced Metering Systems Deployment Estimated Capital Cost, Electric Service				155
Advanced Metering Systems Deployment Incremental O&M Cost, Electric Service				$ 17
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
Suspended Amount Of Rate Reduction Due To TCJA			$ 108
Suspended Additional Amount Of Rate Reduction Due To TCJA		17
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		91
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Existing Rate Mechanism [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
Suspended Amount Of Rate Reduction Due To TCJA			21
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		21
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member] | Bill Credit [Member] | Tax Cuts And Jobs Act [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		70
Suspended Amount Of Rate Reduction Due To TCJA			$ 87
Regulatory Matters - Pennsylvania Activities - TCJA (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA		$ 70

XML

Utility Rate Regulation Utility Rate Regulation (Other) (Detail (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of Accounts Receivable	$ 297	$ 288	$ 673	$ 644
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of Accounts Receivable	$ 297	$ 288	$ 673	$ 644

XML

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2018 GBP (£)	Dec. 31, 2017 USD ($)	Dec. 31, 2017 GBP (£)
UNITED KINGDOM
Line of Credit Facility [Line Items]
Capacity | £		£ 1,315
Borrowed | £		413		£ 448
Letters of Credit and Commercial Paper Issued | £		4		4
Unused Capacity	$ 1,200	898
UNITED KINGDOM | Uncommitted Credit Facilities [Member]
Line of Credit Facility [Line Items]
Capacity | £		130
Borrowed | £		0		0
Letters of Credit and Commercial Paper Issued | £		4		4
Unused Capacity | £		126
WPD PLC [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity | £		210
Borrowed	$ 200	150	$ 200	148
Letters of Credit and Commercial Paper Issued | £		0		£ 0
Unused Capacity | £		£ 60
Interest rate on outstanding borrowing	2.81%	2.81%	2.17%	2.17%
Borrowings | £		£ 150
WPD PLC [Member] | UNITED KINGDOM | Index Linked Term Loan [Member]
Line of Credit Facility [Line Items]
Expiration Date	Dec. 31, 2018
Capacity | £		130
Borrowed	$ 173	130		£ 0
Letters of Credit and Commercial Paper Issued | £		0		0
Unused Capacity | £		£ 0
Interest rate on outstanding borrowing	1.75%	1.75%
WPD South West [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £		£ 245
Borrowed | £		0		0
Letters of Credit and Commercial Paper Issued | £		0		0
Unused Capacity | £		245
WPD East Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £		300
Borrowed	$ 132	99	$ 244	180
Letters of Credit and Commercial Paper Issued | £		0		£ 0
Unused Capacity | £		£ 201
Interest rate on outstanding borrowing	0.90%	0.90%	0.89%	0.89%
WPD West Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jul. 31, 2021
Capacity | £		£ 300
Borrowed	$ 45	34	$ 162	£ 120
Letters of Credit and Commercial Paper Issued | £		0		£ 0
Unused Capacity | £		£ 266
Interest rate on outstanding borrowing	0.90%	0.90%	0.89%	0.89%
PPL Capital Funding [Member] | UNITED STATES
Line of Credit Facility [Line Items]
Capacity	$ 1,350
Borrowed	0		$ 0
Letters of Credit and Commercial Paper Issued	1,019		248
Unused Capacity	$ 331
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 950
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	950		230
Unused Capacity	$ 0
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Nov. 30, 2018
Capacity	$ 300
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	49		0
Unused Capacity	$ 251
PPL Capital Funding [Member] | UNITED STATES | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Mar. 31, 2019
Capacity	$ 100
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	20		18
Unused Capacity	$ 80
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 650
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	1		1
Unused Capacity	$ 649
LKE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2018
Capacity	$ 75
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	0		0
Unused Capacity	75
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
LGE [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	0		0
Unused Capacity	0
KU [Member]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	331		243
Unused Capacity	$ 267
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	133		45
Unused Capacity	$ 267
KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	198		198
Unused Capacity	$ 0
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 650
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	1		1
Unused Capacity	$ 649
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2018
Capacity	$ 75
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	0		0
Unused Capacity	75
LG And E And KU Energy LLC [Member] | LGE [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
LG And E And KU Energy LLC [Member] | LGE [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	0		0
Unused Capacity	0
LG And E And KU Energy LLC [Member] | KU [Member]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	331		243
Unused Capacity	$ 267
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	133		45
Unused Capacity	$ 267
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	198		198
Unused Capacity	0
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	700
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 500
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	183		199
Unused Capacity	$ 317
Louisville Gas And Electric Co [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2019
Capacity	$ 200
Borrowed	200		100
Letters of Credit and Commercial Paper Issued	0		0
Unused Capacity	0
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	598
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	331		243
Unused Capacity	$ 267
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Jan. 31, 2023
Capacity	$ 400
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	133		45
Unused Capacity	$ 267
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 31, 2020
Capacity	$ 198
Borrowed	0		0
Letters of Credit and Commercial Paper Issued	198		$ 198
Unused Capacity	$ 0

XML

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Short-term Debt [Line Items]
Capacity	$ 2,350
Commercial Paper Issuances	1,315	$ 474
Unused Capacity	$ 1,035
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.42%	1.64%
Capacity	$ 1,000
Commercial Paper Issuances	999	$ 230
Unused Capacity	$ 1
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate
Capacity	$ 650
Commercial Paper Issuances	0	$ 0
Unused Capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.33%	1.83%
Capacity	$ 350
Commercial Paper Issuances	183	$ 199
Unused Capacity	$ 167
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	133	$ 45
Unused Capacity	$ 217
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate
Capacity	$ 650
Commercial Paper Issuances	0	$ 0
Unused Capacity	$ 650
LG And E And KU Energy LLC [Member] | LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.33%	1.83%
Capacity	$ 350
Commercial Paper Issuances	183	$ 199
Unused Capacity	$ 167
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	133	$ 45
Unused Capacity	$ 217
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.33%	1.83%
Capacity	$ 350
Commercial Paper Issuances	183	$ 199
Unused Capacity	$ 167
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	2.34%	1.97%
Capacity	$ 350
Commercial Paper Issuances	133	$ 45
Unused Capacity	$ 217

XML

Financing Activities - Long-term Debt (Details) £ in Millions, $ in Millions	1 Months Ended					3 Months Ended
	Jul. 31, 2018 USD ($)	Jun. 30, 2018 USD ($)	May 31, 2018 USD ($)	May 31, 2018 GBP (£)	Mar. 31, 2018 GBP (£)	Mar. 31, 2018 USD ($)	Mar. 31, 2018 GBP (£)	Jun. 30, 2018 GBP (£)	May 31, 2018 GBP (£)
WPD South Wales PLC [Member] | Index Linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £					£ 30		£ 30
Stated interest rate					0.01%		0.01%
Proceeds from debt, net of issuance costs | £							£ 31
Maturity date						Dec. 31, 2036	Dec. 31, 2036
Proceeds from debt, including premium net of debt issuance costs						$ 44
WPD West Midlands [Member] | Index Linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £									£ 30
Stated interest rate			0.01%						0.01%
Proceeds from debt, net of issuance costs | £				£ 31
Maturity date			Dec. 31, 2028	Dec. 31, 2028
Proceeds from debt, including premium net of debt issuance costs			$ 41
PPL Capital Funding [Member] | Senior Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £								£ 250
Stated interest rate		1.90%						1.90%
PPL Electric [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £								£ 400
Stated interest rate		4.15%						4.15%
Proceeds from debt, net of issuance costs		$ 394
Maturity date		Jun. 15, 2048
LGE [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 28
Stated interest rate		2.30%						2.30%
Maturity date					Dec. 31, 2026
Repurchase date of debt instruments					Sep. 01, 2021
LGE [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
LGE [Member] | Senior Debt Obligations [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
KU [Member] | Senior Debt Obligations [Member] | Trimble County Environmental Facilities Revenue Bonds 2007 Series A [Member] | Subsequent Event [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 9
Maturity date	Mar. 01, 2037
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 28
Stated interest rate		2.30%						2.30%
Maturity date					Dec. 31, 2026
Repurchase date of debt instruments					Sep. 01, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
LG And E And KU Energy LLC [Member] | LGE [Member] | Senior Debt Obligations [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
LG And E And KU Energy LLC [Member] | KU [Member] | Senior Debt Obligations [Member] | Trimble County Environmental Facilities Revenue Bonds 2007 Series A [Member] | Subsequent Event [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 9
Maturity date	Mar. 01, 2037
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member] | Note Payable [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate			4.00%						4.00%
Maturity date			May 31, 2028	May 31, 2028
Notes Payable, Noncurrent			$ 250
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 28
Stated interest rate		2.30%						2.30%
Maturity date					Dec. 31, 2026
Repurchase date of debt instruments					Sep. 01, 2021
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 35
Stated interest rate			2.55%						2.55%
Maturity date			Dec. 31, 2027	Dec. 31, 2027
Repurchase date of debt instruments			May 03, 2021	May 03, 2021
Kentucky Utilities Co [Member] | Senior Debt Obligations [Member] | Trimble County Environmental Facilities Revenue Bonds 2007 Series A [Member] | Subsequent Event [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 9
Maturity date	Mar. 01, 2037

XML

Financing Activities - Equity Securities (Details) $ / shares in Units, $ in Millions		1 Months Ended	3 Months Ended	6 Months Ended
		May 31, 2018 counterparties shares	Jun. 30, 2018 USD ($) shares	Jun. 30, 2018 USD ($) $ / shares shares	Jun. 30, 2017 USD ($) shares	Feb. 28, 2018 USD ($)
Equity Programs [Line Items]
Issuance of common stock | $				$ 147	$ 177
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]			5,730,000	5,742,000
Forward Sale Agreement [Member] | Common Stock [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares		55,000,000
Number of Counterparties | counterparties		2
Total Number Of Shares Issued In Forward Sales Agreements And Overallotment Option		63,250,000.00
Sale of Stock, Price Per Share | $ / shares				$ 26.7057
Over-Allotment Option [Member] | Forward Sale Agreement [Member] | Common Stock [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Shares		8,250,000.00
Maximum [Member] | Forward Sale Agreement [Member] | Common Stock [Member]
Equity Programs [Line Items]
Forward Contract Indexed to Issuer's Equity, Settlement Date		Nov. 30, 2019
At The Market Stock Offering Program [Member]
Equity Programs [Line Items]
Common Stock Aggregate Sales Price | $						$ 1,000
Maximum Percentage Paid To Selling Agents				2.00%
Common stock shares issued			1,200,000	4,200,000
Issuance of common stock | $			$ 34	$ 119

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

XML

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Distributions (Numeric) [Abstract]
Dividend payable date of quarterly common stock dividend	Jul. 02, 2018
Current quarterly common stock dividend (in dollars per share)	$ 0.410	$ 0.41	$ 0.395	$ 0.82	$ 0.79
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.64

XML

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Collective Bargaining Agreement Term			5 years
Pension Plan [Member] | U.S.
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	$ 15	$ 15	$ 31	$ 32
Interest cost	39	42	78	84
Expected return on plan assets	(62)	(58)	(124)	(115)
Amortization of: [Abstract]
Prior service cost	3	3	5	5
Actuarial loss	19	14	41	34
Net periodic defined benefit costs (credits) before special termination benefits	14	16	31	40
Special termination benefits	0	(1)	0	1
Net periodic defined benefit costs (credits)	14	15	31	41
Pension Plan [Member] | U.K.
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	21	18	42	37
Interest cost	47	44	94	87
Expected return on plan assets	(150)	(127)	(300)	(252)
Amortization of: [Abstract]
Prior service cost	0	0	0	0
Actuarial loss	38	36	77	71
Net periodic defined benefit costs (credits) before special termination benefits	(44)	(29)	(87)	(57)
Special termination benefits	0	0	0	0
Net periodic defined benefit costs (credits)	(44)	(29)	(87)	(57)
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	3	2	4	4
Interest cost	7	6	10	12
Expected return on plan assets	(9)	(5)	(13)	(11)
Amortization of: [Abstract]
Prior service cost	1	(1)	0	(1)
Net periodic defined benefit costs (credits)	2	2	1	4
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	3	5	7	13
LG And E And KU Energy LLC [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	5	5	12	12
Interest cost	16	18	32	34
Expected return on plan assets	(25)	(24)	(51)	(46)
Amortization of: [Abstract]
Prior service cost	2	2	4	4
Actuarial loss	$ 8	4	$ 18	$ 15
Regulatory Asset Amortization Period	15 years		15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	$ 2		$ 6	$ 5
Net periodic defined benefit costs (credits)	6	5	15	19
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. | Qualified Plan [Member]
Amortization of: [Abstract]
Settlements			4
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	2	2
Interest cost	2	2	4	4
Expected return on plan assets	(2)	(2)	(4)	(3)
Amortization of: [Abstract]
Prior service cost	1	0	1	0
Actuarial loss	(1)	0	(1)	0
Net periodic defined benefit costs (credits)	1	1	2	3
Louisville Gas And Electric Co [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	2	2	4	5
Louisville Gas And Electric Co [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	1	1
Interest cost	3	3	6	6
Expected return on plan assets	(6)	(6)	(11)	(11)
Amortization of: [Abstract]
Prior service cost	2	1	3	2
Actuarial loss	1	1	$ 3	$ 4
Regulatory Asset Amortization Period			15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			$ 1	$ 1
Net periodic defined benefit costs (credits)	1	0	2	2
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. | Qualified Plan [Member]
Amortization of: [Abstract]
Settlements			$ 4
Kentucky Utilities Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Collective Bargaining Agreement Term			3 years
Kentucky Utilities Co [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors	$ 1	$ 1	$ 2	$ 5

XML

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details)	6 Months Ended
	Jun. 30, 2018 claim resident coal-fired_unit mi
LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident	6
Number of miles within plant that would include a class of residents	4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim	1
Generating units retired at the Cane Run plant | coal-fired_unit	3
LGE [Member] | Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	1
LGE [Member] | Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	3
LG And E And KU Energy LLC [Member] | LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident	6
Number of miles within plant that would include a class of residents	4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim	1
Generating units retired at the Cane Run plant | coal-fired_unit	3
LG And E And KU Energy LLC [Member] | LGE [Member] | Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	1
LG And E And KU Energy LLC [Member] | LGE [Member] | Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	3
Louisville Gas And Electric Co [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident	6
Number of miles within plant that would include a class of residents	4
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim	1
Generating units retired at the Cane Run plant | coal-fired_unit	3
Louisville Gas And Electric Co [Member] | Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	1
Louisville Gas And Electric Co [Member] | Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents	3

XML

Commitments and Contingencies - Environmental Matters and Other (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018 USD ($) employees	Dec. 31, 2017 USD ($)
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	5 years
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $	$ 11	$ 10
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $	$ 11	$ 10
LG And E And KU Energy LLC [Member] | KU [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees | employees	68
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees | employees	68

XML

Commitments and Contingencies - Guarantees and Other Assurances (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018 USD ($) Integer	Dec. 31, 2017 USD ($)
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$ 6	$ 17
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage	$ 225
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications Related To WPD Midlands Acquisition [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	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.
PPL Guarantee [Member] | Indemnification Guarantee [Member] | WPD Indemnifications For Entities In Liquidation and Sales Of Assets [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 10
Expiration date	2020
Minimum Period In Years That Indemnifications Generally Expire | Integer	2
Maximum Period In Years That Indemnifications Generally Expire | Integer	7
PPL Guarantee [Member] | Financial Guarantee [Member] | WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 82
PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 20
Expiration date	2020
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 200
Expiration date	2021
Term of guarantee (in years)	12
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 115
PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 20
Expiration date	2020
LG And E And KU Energy LLC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees		$ 11
LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 200
Expiration date	2021
Term of guarantee (in years)	12
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG And E And KU Energy LLC [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 115
Louisville Gas And Electric Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 80
Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent proportionate share of OVEC's outstanding debt	$ 35

XML

Related Party Transactions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended		12 Months Ended
	May 31, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		$ 15	$ 44	$ 31	$ 95
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		41	15	76	33
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity		650		650
Notes receivable from affiliate		0		0		$ 0
Intercompany Note Affiliate Maximum Borrowing Capacity Increase		250		250
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates		99		99		225
Long-term debt to affiliate		650		650		400
Interest Expense with Affiliate		6	4	11	8
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant		7	5	14	11
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity		300		300
Notes payable to affiliates		99		$ 99		$ 225
Intercompany borrowings demand note rate on outstanding borrowing				3.50%		2.87%
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity		300		$ 300
Notes Receivable, Related Parties, Noncurrent		0		$ 0		$ 0
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Debt instrument term (in years)				10 years
Long-term debt to affiliate		$ 400		$ 400
Interest rate on ten-year note		3.50%		3.50%
Interest Expense with Affiliate		$ 3	3	$ 7	7
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Interest Expense with Affiliate		2		2
LG And E And KU Energy LLC [Member] | Note Payable [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Stated interest rate	4.00%
Maturity date	May 31, 2028
Notes Payable, Noncurrent	$ 250
Louisville Gas And Electric Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates		39	38	77	82
Kentucky Utilities Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates		$ 43	$ 47	$ 85	$ 91

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Other Income (Expense)- net Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Other Income
Economic foreign currency exchange contracts	$ 164	$ (113)	$ 52	$ (156)
Defined benefit plans - non-service credits	66	44	134	82
Interest Income	2	0	2	1
AFUDC - equity component	5	4	10	6
Miscellaneous	0	0	1	9
Total Other Income	237	(65)	199	(58)
Other Expense
Charitable Contributions	1	1	5	5
Miscellaneous	2	2	3	14
Total Other Expense	3	3	8	19
Other Income (Expense) - net	234	(68)	191	(77)
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	1	1	3	0
AFUDC - equity component	5	4	10	6
Miscellaneous	1	0	1	0
Total Other Income	7	5	14	6
Other Expense
Charitable Contributions	0	0	1	1
Miscellaneous	0	1	0	1
Total Other Expense	0	1	1	2
Other Income (Expense) - net	$ 7	$ 4	$ 13	$ 4

XML

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents	$ 852	$ 485
Restricted cash and cash equivalents	23	26
Special use funds	65	0
Price risk management assets:
Foreign currency contracts	163	163
Cross-currency swaps	100	101
Total price risk management assets	263	264
Total assets	1,203	775
Price risk management liabilities:
Interest rate swaps	21	26
Foreign currency contracts	53	148
Total price risk management liabilities	74	174
Level 1 [Member]
Assets
Cash and cash equivalents	852	485
Restricted cash and cash equivalents	23	26
Special use funds	65	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total assets	940	511
Price risk management liabilities:
Interest rate swaps	0	0
Foreign currency contracts	0	0
Total price risk management liabilities	0	0
Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Special use funds	0	0
Price risk management assets:
Foreign currency contracts	163	163
Cross-currency swaps	100	101
Total price risk management assets	263	264
Total assets	263	264
Price risk management liabilities:
Interest rate swaps	21	26
Foreign currency contracts	53	148
Total price risk management liabilities	74	174
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Special use funds	0	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Foreign currency contracts	0	0
Total price risk management liabilities	0	0
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	489	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	491	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	489	49
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	491	51
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
PPL Electric Utilities Corp [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
LG And E And KU Energy LLC [Member]
Assets
Cash and cash equivalents	39	30
Price risk management assets:
Total assets	39	30
Price risk management liabilities:
Interest rate swaps	21	26
Total price risk management liabilities	21	26
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	39	30
Price risk management assets:
Total assets	39	30
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
LG And E And KU Energy LLC [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	21	26
Total price risk management liabilities	21	26
LG And E And KU Energy LLC [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	19	15
Price risk management assets:
Total assets	19	15
Price risk management liabilities:
Interest rate swaps	21	26
Total price risk management liabilities	21	26
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	19	15
Price risk management assets:
Total assets	19	15
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	21	26
Total price risk management liabilities	21	26
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	20	15
Price risk management assets:
Total assets	20	15
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	20	15
Price risk management assets:
Total assets	20	15
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total assets	$ 0	$ 0

XML

Fair Value Measurements - Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 20,420	$ 20,195
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	23,448	23,783
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,693	3,298
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,950	3,769
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	5,510	5,159
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	5,801	5,670
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,808	1,709
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,884	1,865
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	2,329	2,328
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 2,480	$ 2,605

XML

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 28	$ 20
Cash collateral posted under master netting arrangements	0	0
LG And E And KU Energy LLC [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash collateral posted under master netting arrangements	0	0
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash collateral posted under master netting arrangements	0	0
Kentucky Utilities Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash collateral posted under master netting arrangements	$ 0	$ 0

XML

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) $ in Millions, £ in Billions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)	Jun. 30, 2018 GBP (£)
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	$ 702		$ 702
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Earliest maturity date of cross-currency cash flow hedge contracts			2021
Latest maturity date of cross-currency cash flow hedge contracts			2028
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	0	$ 0	$ 0	$ 0
Cash Flow Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
No or insignificant after-tax gains (losses) previously recorded in AOCI reclassified to earnings related to interest rate cash flow hedge contracts			For the three and six months ended June 30, 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.
No or insignificant unrealized after-tax gains (losses) on interest rate cash flow hedge contracts expected to be reclassified into earnings during next 12 months			insignificant
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	0	$ 0	$ 0	$ 0
Net Investment Hedges [Member] | Combined Foreign Currency Contracts And Intercompany Loans [Member]
Foreign Currency Risk - Net Investment Hedges (Numeric) [Abstract]
Net after tax gains (losses) on net investment hedges recognized in the foreign currency translation adjustment component of AOCI			$ 30		$ 22
Economic Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Minimum Termination Date Net Investment Hedges Classified As Economic Activity			Jul. 31, 2018
Maximum Termination Date Net Investment Hedges Classified As Economic Activity			Oct. 31, 2020
Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity	2,800		$ 2,800			£ 2.0
LGE [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2033
LG And E And KU Energy LLC [Member] | LGE [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2033
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	$ 147		$ 147
Interest Rate Risk - Economic Activity (Numeric) [Abstract]
Year of expiration of the maximum maturity date of interest rate economic activity contracts			2033

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Derivative Instruments and Hedging Activities - Fair Values (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 100	$ 101
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	4
Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	4
Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	95	97
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	95	97
Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	163	163
Liability value	74	174
Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	73	45
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	73	45
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	90	118
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	90	118
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	35	71
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	31	67
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	39	103
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	22
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	22	81
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	21	26
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	22
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	22
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	21	26
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	4
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	22
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 17	$ 22

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Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	$ 22	$ (32)	$ 8	$ (30)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	(1)
Cash Flow Hedges [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	23	(29)	(1)	(37)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	0	(2)	0	(2)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	(2)	(2)	(4)	(4)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	(1)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	23	(27)	(1)	(35)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)		(1)		0
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)		0		0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	24	(29)	12	(26)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	0	0
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI (Effective Portion)	12	0	11	0
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	162	(114)	49	(159)
Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	164	(113)	52	(156)
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	1	(1)	5	1
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(2)	(1)	(3)	(3)
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	1	(1)	5	1
LG And E And KU Energy LLC [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(2)	(1)	(3)	(3)
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	1	(1)	5	1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ (2)	$ (1)	$ (3)	$ (3)

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Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$ 17
Aggregate fair value of collateral posted on these derivative instruments	0
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	17
Treasury Derivatives [Member]
Assets [Abstract]
Gross	263	$ 264
Derivative instruments - eligible for offset	43	107
Cash collateral received - eligible for offset	28	20
Net	192	137
Liabilities [Abstract]
Gross	74	174
Derivative instruments - eligible for offset	43	107
Cash collateral pledged - eligible for offset	0	0
Net	31	67
LG And E And KU Energy LLC [Member]
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	7
Aggregate fair value of collateral posted on these derivative instruments	0
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	7
LG And E And KU Energy LLC [Member] | Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross	21	26
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	21	26
Louisville Gas And Electric Co [Member]
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	7
Aggregate fair value of collateral posted on these derivative instruments	0
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	7
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross	21	26
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 21	$ 26

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Asset Retirement Obligations (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 397
Accretion	10
Effect of foreign exchange rates	(1)
Changes in estimated timing or cost	1
Obligations settled	(26)
Balance at End of Period	381
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	356
Accretion	9
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(7)
Obligations settled	(26)
Balance at End of Period	332
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	121
Accretion	3
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(2)
Obligations settled	(10)
Balance at End of Period	112
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	235
Accretion	6
Effect of foreign exchange rates	0
Changes in estimated timing or cost	(5)
Obligations settled	(16)
Balance at End of Period	$ 220

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Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (3,279)	$ (3,777)	$ (3,422)	$ (3,778)
Amounts arising during the period	(232)	196	(137)	166
Reclassifications from accumulated other comprehensive income	16	58	64	89
Net other comprehensive income during the period	(216)	254	(73)	255
Balance at end of period	(3,495)	(3,523)	(3,495)	(3,523)
Foreign currency translation adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(973)	(1,651)	(1,089)	(1,627)
Amounts arising during the period	(250)	231	(134)	207
Reclassifications from accumulated other comprehensive income	0	0	0	0
Net other comprehensive income during the period	(250)	231	(134)	207
Balance at end of period	(1,223)	(1,420)	(1,223)	(1,420)
Unrealized gains (losses) on qualifying derivatives
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(21)	(14)	(13)	(7)
Amounts arising during the period	19	(24)	(1)	(30)
Reclassifications from accumulated other comprehensive income	(19)	25	(7)	24
Net other comprehensive income during the period	0	1	(8)	(6)
Balance at end of period	(21)	(13)	(21)	(13)
Equity investees' AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	(1)	0	(1)
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	0	1	0	1
Net other comprehensive income during the period	0	1	0	1
Balance at end of period	0	0	0	0
Defined benefit plans Prior service costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(7)	(8)	(7)	(8)
Amounts arising during the period	(1)	0	(1)	0
Reclassifications from accumulated other comprehensive income	1	1	1	1
Net other comprehensive income during the period	0	1	0	1
Balance at end of period	(7)	(7)	(7)	(7)
Defined benefit plans Actuarial gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(2,278)	(2,103)	(2,313)	(2,135)
Amounts arising during the period	0	(11)	(1)	(11)
Reclassifications from accumulated other comprehensive income	34	31	70	63
Net other comprehensive income during the period	34	20	69	52
Balance at end of period	(2,244)	(2,083)	(2,244)	(2,083)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(87)	(68)	(88)	(70)
Amounts arising during the period	1	(11)		(11)
Reclassifications from accumulated other comprehensive income	0	2	2	4
Net other comprehensive income during the period	1	(9)	2	(7)
Balance at end of period	(86)	(77)	(86)	(77)
LG And E And KU Energy LLC [Member] | Equity investees' AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	0	0	(1)
Amounts arising during the period	0	0		0
Reclassifications from accumulated other comprehensive income	0	0	0	1
Net other comprehensive income during the period	0	0	0	1
Balance at end of period	0	0	0	0
LG And E And KU Energy LLC [Member] | Defined benefit plans Prior service costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(9)	(8)	(9)	(8)
Amounts arising during the period	0	0		0
Reclassifications from accumulated other comprehensive income	1	1	1	1
Net other comprehensive income during the period	1	1	1	1
Balance at end of period	(8)	(7)	(8)	(7)
LG And E And KU Energy LLC [Member] | Defined benefit plans Actuarial gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(78)	(60)	(79)	(61)
Amounts arising during the period	1	(11)		(11)
Reclassifications from accumulated other comprehensive income	(1)	1	1	2
Net other comprehensive income during the period	0	(10)	1	(9)
Balance at end of period	$ (78)	$ (70)	$ (78)	$ (70)

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Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	$ 234	$ (68)	$ 191	$ (77)
Interest Expense	(235)	(222)	(474)	(439)
Income Taxes	(142)	(76)	(259)	(205)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(16)	(58)	(64)	(89)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	22	(32)	8	(31)
Income Taxes	(3)	7	(1)	7
Total After-tax	19	(25)	7	(24)
Qualifying Derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	(2)	(2)	(4)	(5)
Qualifying Derivatives [Member] | Cross Currency Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	24	(29)	12	(26)
Interest Expense	0	(1)	0	0
Equity Investees Accumulated Other Comprehensive Income [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	0	(1)	0	(1)
Total Pre-tax	0	(1)	0	(1)
Income Taxes	0	0	0	0
Total After-tax	0	(1)	0	(1)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(44)	(41)	(89)	(82)
Income Taxes	9	9	18	18
Total After-tax	(35)	(32)	(71)	(64)
Defined Benefit Plans [Member] | Prior Service Costs [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(1)	(1)	(1)	(1)
Defined Benefit Plans [Member] | Net Actuarial Loss [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	$ (43)	$ (40)	$ (88)	$ (81)

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New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) $ in Millions	Jun. 30, 2018 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Impact of Adoption of ASU 2018-02	$ 50
LG And E And KU Energy LLC [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Estimated Impact of Adoption of ASU 2018-02	$ 18