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, 2017
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, 685,855,683 shares outstanding at July 27, 2017.
PPL Electric Utilities Corporation	Common stock, no par value, 66,368,056 shares outstanding and all held by PPL Corporation at July 27, 2017.
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 27, 2017.
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 27, 2017.

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, 2017

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 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		34
		4.   Earnings Per Share		34
		5.   Income Taxes		36
		6.   Utility Rate Regulation		37
		7.   Financing Activities		40
		8.   Defined Benefits		43
		9. Commitments and Contingencies		45
		10. Related Party Transactions		53
		11. Other Income (Expense) - net		54
		12. Fair Value Measurements		54
		13. Derivative Instruments and Hedging Activities		56
		14. Goodwill and Other Intangible Assets		64
		15. Asset Retirement Obligations		64
		16. Accumulated Other Comprehensive Income (Loss)		65
		17. New Accounting Guidance Pending Adoption		66
	Item 2.  Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		69
			Introduction	69
			Business Strategy	71
			Financial and Operational Developments	72
		Results of Operations		73
			PPL Corporation and Subsidiaries - Statement of Income Analysis, Segment Earnings and Margins	74
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis, Earnings and Margins	86
			LG&E and KU Energy LLC and Subsidiaries - Statement of Income Analysis, Earnings and Margins	89
			Louisville Gas and Electric Company - Statement of Income Analysis, Earnings and Margins	91
			Kentucky Utilities Company - Statement of Income Analysis, Earnings and Margins	94
		Financial Condition		96
			Liquidity and Capital Resources	96
			Risk Management	102
			Foreign Currency Translation	104
			Related Party Transactions	104
			Acquisitions, Development and Divestitures	104
			Environmental Matters	104
		New Accounting Guidance		105
		Application of Critical Accounting Policies		105
	Item 3.  Quantitative and Qualitative Disclosures About Market Risk			106
	Item 4.  Controls and Procedures			106
PART II.  OTHER INFORMATION
	Item 1. Legal Proceedings			106
	Item 1A. Risk Factors			106
	Item 4. Mine Safety Disclosures			106
	Item 6. Exhibits			106
SIGNATURES				109
COMPUTATIONS OF RATIO OF EARNINGS TO FIXED CHARGES
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

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GLOSSARY OF TERMS AND ABBREVIATIONS

PPL Corporation and its subsidiaries

KU - Kentucky Utilities Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky.

LG&E - Louisville Gas and Electric Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas in Kentucky.

LKE - LG&E and KU Energy LLC, a subsidiary of PPL and the parent of LG&E, KU and other subsidiaries.

LKS - LG&E and KU Services Company, a subsidiary of LKE that provides administrative, management, and support services primarily to LKE and its subsidiaries.

PPL - PPL Corporation, the parent holding company of PPL Electric, PPL Energy Funding, PPL Capital Funding, LKE and other subsidiaries.

PPL Capital Funding - PPL Capital Funding, Inc., a financing subsidiary of PPL that provides financing for the operations of PPL and certain subsidiaries. Debt issued by PPL Capital Funding is guaranteed as to payment by PPL.

PPL Electric - PPL Electric Utilities Corporation, a public utility subsidiary of PPL engaged in the regulated transmission and distribution of electricity in its Pennsylvania service area and that provides electricity supply to its retail customers in this area as a PLR.

PPL Energy Funding - PPL Energy Funding Corporation, a subsidiary of PPL and the parent holding company of PPL Global and other subsidiaries.

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

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

PPL Services - PPL Services Corporation, a subsidiary of PPL that provides administrative, management and support services to PPL and its subsidiaries.

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

WPD - refers to PPL WPD Limited and its subsidiaries.

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

WPD plc - Western Power Distribution plc, a direct 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-utility generating plants in western Kentucky until July 2009.

Other terms and abbreviations

£ - British pound sterling.

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

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

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.

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.

AOCI - accumulated other comprehensive income or loss.

ARO - asset retirement obligation.

ATM Program - At-the-Market stock offering program.

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

CCR(s) - Coal Combustion Residual(s). 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.

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.

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

DNO - Distribution Network Operator in the U.K.

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

ii

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.

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.

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.

LIBOR - London Interbank Offered Rate.

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).

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

MW - megawatt, one thousand kilowatts.

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

NERC - North American Electric Reliability Corporation.

NGCC - Natural gas-fired combined-cycle generating plant.

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.

iii

OCI - other comprehensive income or loss.

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

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

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 are based on a percentage of annual total expenditures that have a long-term benefit to WPD (similar to capital projects for the U.S. regulated businesses that are generally included in rate base).

RCRA - Resource Conservation and Recovery Act of 1976.

Registrant(s) - refers to the Registrants named on the cover of this Report (each a "Registrant" and collectively, the "Registrants").

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

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

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

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

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

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

Sarbanes-Oxley - Sarbanes-Oxley Act of 2002, which sets requirements for management's assessment of internal controls for financial reporting. It also requires an independent auditor to make its own assessment.

Scrubber - an air pollution control device that can remove particulates and/or gases (primarily sulfur dioxide) from exhaust gases.

iv

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.

Superfund - federal environmental statute that addresses remediation of contaminated sites; states also have similar statutes.

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

U.K. 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.

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

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Forward-looking Information

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

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

• changes in U.S. or U.K. tax laws or regulations;

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

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

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

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

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

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

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

• the March 29, 2017 notification by the U.K. to the European Council of the European Union of 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 unrecorded commitments and liabilities, if any, of the Registrants and their subsidiaries;

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

• changes in securities and credit ratings;

• 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 recover fuel costs and environmental expenditures in a timely manner at LG&E and KU, and natural gas supply costs at LG&E;

• fuel supply for LG&E and KU;

• 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.

1

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.

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,
	2017			2016		2017			2016
Operating Revenues	$	1,725		$	1,785	$	3,676		$	3,796
Operating Expenses
Operation
Fuel	183			183		374			380
Energy purchases	136			147		351			380
Other operation and maintenance	388			425		820			875
Depreciation	246			231		488			460
Taxes, other than income	70			74		145			153
Total Operating Expenses	1,023			1,060		2,178			2,248
Operating Income	702			725		1,498			1,548
Other Income (Expense) - net	(112		)	174		(159		)	235
Interest Expense	222			224		439			448
Income Before Income Taxes	368			675		900			1,335
Income Taxes	76			192		205			371
Net Income	$	292		$	483	$	695		$	964
Earnings Per Share of Common Stock:
Net Income Available to PPL Common Shareowners:
Basic	$	0.43		$	0.71	$	1.02		$	1.42
Diluted	$	0.43		$	0.71	$	1.01		$	1.41
Dividends Declared Per Share of Common Stock	$	0.3950		$	0.38	$	0.79		$	0.76
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	683,841			677,145		682,370			676,293
Diluted	686,351			680,729		684,725			679,773

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,
	2017			2016			2017			2016
Net income	$	292		$	483		$	695		$	964
Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax of $0, $0, ($1), ($2)	231			268			207			(196		)
Qualifying derivatives, net of tax of $5, $22, $7, $7	(24		)	(85		)	(30		)	(5		)
Defined benefit plans:
Net actuarial gain (loss), net of tax of $7, ($1), $7, ($1)	(11		)	2			(11		)	2
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax of ($7), ($21), ($7), ($2)	25			85			24			7
Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0, $0	1			(1		)	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), ($8), ($18), ($17)	31			32			63			63
Total other comprehensive income (loss)	254			302			255			(129		)
Comprehensive income	$	546		$	785		$	950		$	835

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,
	2017			2016
Cash Flows from Operating Activities
Net income	$	695		$	964
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	488			460
Amortization	45			37
Defined benefit plans - expense (income)	(45		)	(24		)
Deferred income taxes and investment tax credits	201			320
Unrealized (gains) losses on derivatives, and other hedging activities	135			(192		)
Stock-based compensation expense	22			18
Other	(5		)	(11		)
Change in current assets and current liabilities
Accounts receivable	26			16
Accounts payable	(92		)	(39		)
Unbilled revenues	70			(2		)
Fuel, materials and supplies	42			21
Prepayments	(66		)	(66		)
Counterparty collateral	8			76
Taxes payable	(27		)	22
Accrued interest	(77		)	(85		)
Other current liabilities	(52		)	(47		)
Other	(14		)	(21		)
Other operating activities
Defined benefit plans - funding	(552		)	(224		)
Other assets	(1		)	2
Other liabilities	(11		)	(55		)
Net cash provided by operating activities	790			1,170
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(1,373		)	(1,346		)
Expenditures for intangible assets	(15		)	(14		)
Other investing activities	6			13
Net cash used in investing activities	(1,382		)	(1,347		)
Cash Flows from Financing Activities
Issuance of long-term debt	594			1,020
Retirement of long-term debt	(60		)	(684		)
Settlement of cross-currency swaps	—			46
Issuance of common stock	177			76
Payment of common stock dividends	(529		)	(513		)
Net increase (decrease) in short-term debt	554			(66		)
Other financing activities	(25		)	(31		)
Net cash provided by (used in) financing activities	711			(152		)
Effect of Exchange Rates on Cash and Cash Equivalents	7			(15		)
Net Increase (Decrease) in Cash and Cash Equivalents	126			(344		)
Cash and Cash Equivalents at Beginning of Period	341			836
Cash and Cash Equivalents at End of Period	$	467		$	492
Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	284		$	283
Accrued expenditures for intangible assets at June 30,	$	56		$	94

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, 2017		December 31, 2016
Assets
Current Assets
Cash and cash equivalents	$	467	$	341
Accounts receivable (less reserve: 2017, $53; 2016, $54)
Customer	628		666
Other	85		46
Unbilled revenues	416		480
Fuel, materials and supplies	316		356
Prepayments	131		63
Price risk management assets	69		63
Other current assets	54		52
Total Current Assets	2,166		2,067
Property, Plant and Equipment
Regulated utility plant	36,173		34,674
Less:  accumulated depreciation - regulated utility plant	6,446		6,013
Regulated utility plant, net	29,727		28,661
Non-regulated property, plant and equipment	424		413
Less:  accumulated depreciation - non-regulated property, plant and equipment	147		134
Non-regulated property, plant and equipment, net	277		279
Construction work in progress	1,229		1,134
Property, Plant and Equipment, net	31,233		30,074
Other Noncurrent Assets
Regulatory assets	1,906		1,918
Goodwill	3,139		3,060
Other intangibles	656		700
Pension benefit asset	467		9
Price risk management assets	245		336
Other noncurrent assets	152		151
Total Other Noncurrent Assets	6,565		6,174
Total Assets	$	39,964	$	38,315

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, 2017			December 31, 2016
Liabilities and Equity
Current Liabilities
Short-term debt	$	1,497		$	923
Long-term debt due within one year	671			518
Accounts payable	752			820
Taxes	77			101
Interest	196			270
Dividends	271			259
Customer deposits	289			276
Regulatory liabilities	71			101
Other current liabilities	526			569
Total Current Liabilities	4,350			3,837
Long-term Debt	18,397			17,808
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	4,130			3,889
Investment tax credits	131			132
Accrued pension obligations	787			1,001
Asset retirement obligations	343			428
Regulatory liabilities	902			899
Other deferred credits and noncurrent liabilities	434			422
Total Deferred Credits and Other Noncurrent Liabilities	6,727			6,771
Commitments and Contingent Liabilities (Notes 6 and 9)
Equity
Common stock - $0.01 par value (a)	7			7
Additional paid-in capital	10,023			9,841
Earnings reinvested	3,983			3,829
Accumulated other comprehensive loss	(3,523		)	(3,778		)
Total Equity	10,490			9,899
Total Liabilities and Equity	$	39,964		$	38,315

(a) 1,560,000 shares authorized; 685,473 and 679,731 shares issued and outstanding at June 30, 2017 and December 31, 2016.

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, 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
December 31, 2015	673,857	$	7	$	9,687		$	2,953		$	(2,728	)	$	9,919
Common stock issued	3,692			109									109
Stock-based compensation				(30		)							(30		)
Net income							964						964
Dividends and dividend equivalents							(515		)				(515		)
Other comprehensive income (loss)										(129		)	(129		)
Adoption of stock-based compensation guidance cumulative effect adjustment							7						7
June 30, 2016	677,549	$	7	$	9,766		$	3,409		$	(2,857	)	$	10,325

(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

THIS PAGE INTENTIONALLY LEFT BLANK.

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,
	2017		2016		2017		2016
Operating Revenues	$	500	$	495	$	1,073	$	1,080
Operating Expenses
Operation
Energy purchases	107		118		253		285
Other operation and maintenance	138		137		302		287
Depreciation	76		62		151		121
Taxes, other than income	23		24		52		53
Total Operating Expenses	344		341		758		746
Operating Income	156		154		315		334
Other Income (Expense) - net	3		5		4		8
Interest Income from Affiliate	1		—		1		—
Interest Expense	36		32		69		65
Income Before Income Taxes	124		127		251		277
Income Taxes	47		48		95		104
Net Income (a)	$	77	$	79	$	156	$	173

(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,
	2017			2016
Cash Flows from Operating Activities
Net income	$	156		$	173
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	151			121
Amortization	15			15
Defined benefit plans - expense	7			7
Deferred income taxes and investment tax credits	84			107
Other	(4		)	(10		)
Change in current assets and current liabilities
Accounts receivable	13			(6		)
Accounts payable	(59		)	(26		)
Unbilled revenues	17			3
Prepayments	(52		)	3
Regulatory assets and liabilities	(12		)	(40		)
Taxes payable	(4		)	(16		)
Other	(6		)	(6		)
Other operating activities
Defined benefit plans - funding	(24		)	—
Other assets	(4		)	11
Other liabilities	1			(8		)
Net cash provided by operating activities	279			328
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(550		)	(424		)
Expenditures for intangible assets	(5		)	(2		)
Net increase in notes receivable from affiliate	(270		)	—
Other investing activities	1			(1		)
Net cash used in investing activities	(824		)	(427		)
Cash Flows from Financing Activities
Issuance of long-term debt	470			224
Retirement of long-term debt	—			(224		)
Contributions from parent	575			200
Payment of common stock dividends to parent	(154		)	(117		)
Net increase (decrease) in short-term debt	(295		)	6
Other financing activities	(5		)	(2		)
Net cash provided by financing activities	591			87
Net Increase (Decrease) in Cash and Cash Equivalents	46			(12		)
Cash and Cash Equivalents at Beginning of Period	13			47
Cash and Cash Equivalents at End of Period	$	59		$	35
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	157		$	130

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, 2017		December 31, 2016
Assets
Current Assets
Cash and cash equivalents	$	59	$	13
Accounts receivable (less reserve: 2017, $26; 2016, $28)
Customer	267		272
Other	12		21
Accounts receivable from affiliates	1		—
Notes receivable from affiliate	270		—
Unbilled revenues	97		114
Materials and supplies	29		32
Prepayments	61		9
Regulatory assets	14		19
Other current assets	6		8
Total Current Assets	816		488
Property, Plant and Equipment
Regulated utility plant	10,235		9,654
Less: accumulated depreciation - regulated utility plant	2,814		2,714
Regulated utility plant, net	7,421		6,940
Construction work in progress	593		641
Property, Plant and Equipment, net	8,014		7,581
Other Noncurrent Assets
Regulatory assets	1,076		1,094
Intangibles	254		251
Other noncurrent assets	15		12
Total Other Noncurrent Assets	1,345		1,357
Total Assets	$	10,175	$	9,426

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, 2017		December 31, 2016
Liabilities and Equity
Current Liabilities
Short-term debt	$	—	$	295
Long-term debt due within one year	224		224
Accounts payable	353		367
Accounts payable to affiliates	29		42
Taxes	8		12
Interest	37		34
Regulatory liabilities	57		83
Other current liabilities	88		101
Total Current Liabilities	796		1,158
Long-term Debt	3,074		2,607
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,990		1,899
Accrued pension obligations	257		281
Other deferred credits and noncurrent liabilities	90		90
Total Deferred Credits and Other Noncurrent Liabilities	2,337		2,270
Commitments and Contingent Liabilities (Notes 6 and 9)
Equity
Common stock - no par value (a)	364		364
Additional paid-in capital	2,729		2,154
Earnings reinvested	875		873
Total Equity	3,968		3,391
Total Liabilities and Equity	$	10,175	$	9,426

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

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, 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
December 31, 2015	66,368	$	364	$	1,934	$	821		$	3,119
Net income						173			173
Capital contributions from PPL				200					200
Dividends declared on common stock						(116		)	(116		)
June 30, 2016	66,368	$	364	$	2,134	$	878		$	3,376

(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,
	2017			2016			2017			2016
Operating Revenues	$	723		$	721		$	1,532		$	1,547
Operating Expenses
Operation
Fuel	183			182			374			380
Energy purchases	29			28			98			94
Other operation and maintenance	192			204			399			406
Depreciation	105			100			210			199
Taxes, other than income	16			15			32			30
Total Operating Expenses	525			529			1,113			1,109
Operating Income	198			192			419			438
Other Income (Expense) - net	(4		)	(5		)	(6		)	(6		)
Interest Expense	50			48			99			97
Interest Expense with Affiliate	4			4			8			8
Income Before Income Taxes	140			135			306			327
Income Taxes	53			51			116			123
Net Income	$	87		$	84		$	190		$	204

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,
	2017			2016			2017			2016
Net income	$	87		$	84		$	190		$	204
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 $7, ($1), $7, ($1)	(11		)	1			(11		)	1
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax of $0, $0, $0, $0	—			(1		)	1			(1		)
Defined benefit plans:
Prior service costs, net of tax of $0, $0, $0, $0	1			1			1			1
Net actuarial loss, net of tax of ($1), ($1), ($2), ($1)	1			1			2			2
Total other comprehensive income (loss)	(9		)	2			(7		)	3
Comprehensive income	$	78		$	86		$	183		$	207

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,
	2017			2016
Cash Flows from Operating Activities
Net income	$	190		$	204
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	210			199
Amortization	14			15
Defined benefit plans - expense	12			13
Deferred income taxes and investment tax credits	91			121
Other	—			(1		)
Change in current assets and current liabilities
Accounts receivable	13			9
Accounts payable	(28		)	28
Unbilled revenues	23			(14		)
Fuel, materials and supplies	41			20
Taxes payable	3			(13		)
Other	(21		)	(23		)
Other operating activities
Defined benefit plans - funding	(29		)	(45		)
Expenditures for asset retirement obligations	(12		)	(8		)
Other assets	(2		)	1
Other liabilities	6			—
Net cash provided by operating activities	511			506
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(355		)	(439		)
Net cash used in investing activities	(355		)	(439		)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate	(4		)	123
Issuance of long-term debt	60			—
Retirement of long-term debt	(60		)	—
Net increase (decrease) in short-term debt	73			(126		)
Debt issuance and credit facility costs	(1		)	(1		)
Distributions to member	(218		)	(114		)
Contributions from member	—			37
Net cash used in financing activities	(150		)	(81		)
Net Increase (Decrease) in Cash and Cash Equivalents	6			(14		)
Cash and Cash Equivalents at Beginning of Period	13			30
Cash and Cash Equivalents at End of Period	$	19		$	16
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	83		$	105

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, 2017		December 31, 2016
Assets
Current Assets
Cash and cash equivalents	$	19	$	13
Accounts receivable (less reserve: 2017, $25; 2016, $24)
Customer	221		235
Other	40		17
Unbilled revenues	147		170
Fuel, materials and supplies	257		297
Prepayments	32		24
Regulatory assets	23		20
Other current assets	9		4
Total Current Assets	748		780
Property, Plant and Equipment
Regulated utility plant	12,852		12,746
Less: accumulated depreciation - regulated utility plant	1,630		1,465
Regulated utility plant, net	11,222		11,281
Construction work in progress	411		317
Property, Plant and Equipment, net	11,633		11,598
Other Noncurrent Assets
Regulatory assets	830		824
Goodwill	996		996
Other intangibles	90		95
Other noncurrent assets	80		78
Total Other Noncurrent Assets	1,996		1,993
Total Assets	$	14,377	$	14,371

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, 2017		December 31, 2016
Liabilities and Equity
Current Liabilities
Short-term debt	$	258	$	185
Long-term debt due within one year	98		194
Notes payable with affiliate	159		163
Accounts payable	225		251
Accounts payable to affiliates	6		6
Customer deposits	57		56
Taxes	42		39
Price risk management liabilities	5		4
Regulatory liabilities	14		18
Interest	31		32
Asset retirement obligations	73		60
Other current liabilities	115		119
Total Current Liabilities	1,083		1,127
Long-term Debt
Long-term debt	4,569		4,471
Long-term debt to affiliate	400		400
Total Long-term Debt	4,969		4,871
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,823		1,735
Investment tax credits	131		132
Accrued pension obligations	344		350
Asset retirement obligations	292		373
Regulatory liabilities	902		899
Price risk management liabilities	25		27
Other deferred credits and noncurrent liabilities	176		190
Total Deferred Credits and Other Noncurrent Liabilities	3,693		3,706
Commitments and Contingent Liabilities (Notes 6 and 9)
Member's Equity	4,632		4,667
Total Liabilities and Equity	$	14,377	$	14,371

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, 2016	$	4,667
Net income	190
Distributions to member	(218		)
Other comprehensive income	(7		)
June 30, 2017	$	4,632
December 31, 2015	$	4,517
Net income	204
Contributions from member	37
Distributions to member	(114		)
Other comprehensive income	3
June 30, 2016	$	4,647

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,
	2017		2016			2017			2016
Operating Revenues
Retail and wholesale	$	320	$	317		$	694		$	692
Electric revenue from affiliate	4		6			21			17
Total Operating Revenues	324		323			715			709
Operating Expenses
Operation
Fuel	69		69			149			147
Energy purchases	25		23			89			85
Energy purchases from affiliate	3		3			5			5
Other operation and maintenance	86		92			173			179
Depreciation	45		42			89			83
Taxes, other than income	9		7			17			15
Total Operating Expenses	237		236			522			514
Operating Income	87		87			193			195
Other Income (Expense) - net	1		(5		)	(1		)	(5		)
Interest Expense	19		18			36			35
Income Before Income Taxes	69		64			156			155
Income Taxes	27		24			60			59
Net Income (a)	$	42	$	40		$	96		$	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,
	2017			2016
Cash Flows from Operating Activities
Net income	$	96		$	96
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	89			83
Amortization	7			6
Defined benefit plans - expense	3			4
Deferred income taxes and investment tax credits	57			62
Change in current assets and current liabilities
Accounts receivable	9			2
Accounts receivable from affiliates	11			(7		)
Accounts payable	(17		)	20
Accounts payable to affiliates	(3		)	8
Unbilled revenues	14			(1		)
Fuel, materials and supplies	33			29
Taxes payable	(23		)	—
Other	(3		)	(6		)
Other operating activities
Defined benefit plans - funding	(3		)	(16		)
Expenditures for asset retirement obligations	(7		)	(6		)
Other assets	—			(4		)
Other liabilities	1			3
Net cash provided by operating activities	264			273
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(177		)	(237		)
Net cash used in investing activities	(177		)	(237		)
Cash Flows from Financing Activities
Issuance of long-term debt	60			—
Retirement of long-term debt	(60		)	—
Net increase (decrease) in short-term debt	38			(32		)
Debt issuance and credit facility costs	(1		)	(1		)
Payment of common stock dividends to parent	(122		)	(61		)
Contributions from parent	—			47
Net cash used in financing activities	(85		)	(47		)
Net Increase (Decrease) in Cash and Cash Equivalents	2			(11		)
Cash and Cash Equivalents at Beginning of Period	5			19
Cash and Cash Equivalents at End of Period	$	7		$	8
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	40		$	69

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, 2017		December 31, 2016
Assets
Current Assets
Cash and cash equivalents	$	7	$	5
Accounts receivable (less reserve: 2017, $1; 2016, $2)
Customer	101		109
Other	11		11
Accounts receivable from affiliates	17		28
Unbilled revenues	61		75
Fuel, materials and supplies	110		143
Prepayments	15		12
Regulatory assets	11		9
Other current assets	3		1
Total Current Assets	336		393
Property, Plant and Equipment
Regulated utility plant	5,440		5,357
Less: accumulated depreciation - regulated utility plant	566		498
Regulated utility plant, net	4,874		4,859
Construction work in progress	174		133
Property, Plant and Equipment, net	5,048		4,992
Other Noncurrent Assets
Regulatory assets	449		450
Goodwill	389		389
Other intangibles	55		59
Other noncurrent assets	17		17
Total Other Noncurrent Assets	910		915
Total Assets	$	6,294	$	6,300

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, 2017		December 31, 2016
Liabilities and Equity
Current Liabilities
Short-term debt	$	207	$	169
Long-term debt due within one year	98		194
Accounts payable	116		148
Accounts payable to affiliates	23		26
Customer deposits	27		27
Taxes	17		40
Price risk management liabilities	5		4
Regulatory liabilities	4		5
Interest	10		11
Asset retirement obligations	29		41
Other current liabilities	40		36
Total Current Liabilities	576		701
Long-term Debt	1,521		1,423
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,033		974
Investment tax credits	36		36
Accrued pension obligations	49		53
Asset retirement obligations	103		104
Regulatory liabilities	418		419
Price risk management liabilities	25		27
Other deferred credits and noncurrent liabilities	83		87
Total Deferred Credits and Other Noncurrent Liabilities	1,747		1,700
Commitments and Contingent Liabilities (Notes 6 and 9)
Stockholder's Equity
Common stock - no par value (a)	424		424
Additional paid-in capital	1,682		1,682
Earnings reinvested	344		370
Total Equity	2,450		2,476
Total Liabilities and Equity	$	6,294	$	6,300

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

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, 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
December 31, 2015	21,294	$	424	$	1,611	$	295		$	2,330
Net income						96			96
Capital contributions from LKE				47					47
Cash dividends declared on common stock						(61		)	(61		)
June 30, 2016	21,294	$	424	$	1,658	$	330		$	2,412

(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

THIS PAGE INTENTIONALLY LEFT BLANK.

27

CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended June 30,					Six Months Ended June 30,
	2017			2016		2017			2016
Operating Revenues
Retail and wholesale	$	403		$	404	$	838		$	855
Electric revenue from affiliate	3			3		5			5
Total Operating Revenues	406			407		843			860
Operating Expenses
Operation
Fuel	114			113		225			233
Energy purchases	4			5		9			9
Energy purchases from affiliate	4			6		21			17
Other operation and maintenance	100			107		209			213
Depreciation	61			58		121			116
Taxes, other than income	7			8		15			15
Total Operating Expenses	290			297		600			603
Operating Income	116			110		243			257
Other Income (Expense) - net	(2		)	1		(3		)	(1		)
Interest Expense	24			23		48			47
Income Before Income Taxes	90			88		192			209
Income Taxes	34			34		73			80
Net Income (a)	$	56		$	54	$	119		$	129

(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,
	2017			2016
Cash Flows from Operating Activities
Net income	$	119		$	129
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	121			116
Amortization	6			7
Defined benefit plans - expense	2			3
Deferred income taxes and investment tax credits	70			77
Other	—			(1		)
Change in current assets and current liabilities
Accounts receivable	5			11
Accounts receivable from affiliates	—			1
Accounts payable	(1		)	11
Accounts payable to affiliates	(15		)	12
Unbilled revenues	9			(13		)
Fuel, materials and supplies	8			(9		)
Taxes payable	(29		)	(3		)
Other	(13		)	(11		)
Other operating activities
Defined benefit plans - funding	(21		)	(13		)
Expenditures for asset retirement obligations	(5		)	(2		)
Other assets	(3		)	(3		)
Other liabilities	4			(1		)
Net cash provided by operating activities	257			311
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(177		)	(201		)
Net cash used in investing activities	(177		)	(201		)
Cash Flows from Financing Activities
Net increase (decrease) in short-term debt	35			(19		)
Debt issuance and credit facility costs	—			(1		)
Payment of common stock dividends to parent	(110		)	(113		)
Contributions from parent	—			20
Net cash used in financing activities	(75		)	(113		)
Net Increase (Decrease) in Cash and Cash Equivalents	5			(3		)
Cash and Cash Equivalents at Beginning of Period	7			11
Cash and Cash Equivalents at End of Period	$	12		$	8
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at June 30,	$	43		$	36

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, 2017		December 31, 2016
Assets
Current Assets
Cash and cash equivalents	$	12	$	7
Accounts receivable (less reserve: 2017, $2; 2016, $2)
Customer	120		126
Other	27		5
Unbilled revenues	86		95
Fuel, materials and supplies	147		154
Prepayments	15		12
Regulatory assets	12		11
Other current assets	6		3
Total Current Assets	425		413
Property, Plant and Equipment
Regulated utility plant	7,404		7,382
Less: accumulated depreciation - regulated utility plant	1,062		965
Regulated utility plant, net	6,342		6,417
Construction work in progress	236		181
Property, Plant and Equipment, net	6,578		6,598
Other Noncurrent Assets
Regulatory assets	381		374
Goodwill	607		607
Other intangibles	35		36
Other noncurrent assets	60		57
Total Other Noncurrent Assets	1,083		1,074
Total Assets	$	8,086	$	8,085

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, 2017		December 31, 2016
Liabilities and Equity
Current Liabilities
Short-term debt	$	51	$	16
Accounts payable	94		78
Accounts payable to affiliates	43		56
Customer deposits	30		29
Taxes	16		45
Regulatory liabilities	10		13
Interest	16		16
Asset retirement obligations	44		19
Other current liabilities	32		36
Total Current Liabilities	336		308
Long-term Debt	2,327		2,327
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,242		1,170
Investment tax credits	95		96
Accrued pension obligations	38		62
Asset retirement obligations	189		269
Regulatory liabilities	484		480
Other deferred credits and noncurrent liabilities	42		50
Total Deferred Credits and Other Noncurrent Liabilities	2,090		2,127
Commitments and Contingent Liabilities (Notes 6 and 9)
Stockholder's Equity
Common stock - no par value (a)	308		308
Additional paid-in capital	2,616		2,616
Accumulated other comprehensive loss	—		(1		)
Earnings reinvested	409		400
Total Equity	3,333		3,323
Total Liabilities and Equity	$	8,086	$	8,085

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

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, 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									1			1
June 30, 2017	37,818	$	308	$	2,616	$	409		$	—		$	3,333
December 31, 2015	37,818	$	308	$	2,596	$	383		$	—		$	3,287
Capital contributions from LKE				20								20
Net income						129						129
Cash dividends declared on common stock						(113		)				(113		)
Other comprehensive income (loss)									(1		)	(1		)
June 30, 2016	37,818	$	308	$	2,616	$	399		$	(1	)	$	3,322

(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, 2016 is derived from that Registrant's 2016 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2016 Form 10-K. The results of operations for the three and six months ended June 30, 2017 are not necessarily indicative of the results to be expected for the full year ending December 31, 2017 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 2016 Form 10-K and should be read in conjunction with those disclosures.

Accounts Receivable(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, 2017, PPL Electric purchased $288 million and $644 million of accounts receivable from alternative energy suppliers. During the three and six months ended June 30, 2016, PPL Electric purchased $297 million and $679 million of accounts receivable from alternative electricity suppliers.

33

3. Segment and Related Information

(PPL)

See Note 2 in PPL's 2016 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
	2017			2016			2017			2016
Income Statement Data
Revenues from external customers
U.K. Regulated	$	502		$	563		$	1,070		$	1,158
Kentucky Regulated	723			721			1,532			1,547
Pennsylvania Regulated	500			495			1,073			1,080
Corporate and Other	—			6			1			11
Total	$	1,725		$	1,785		$	3,676		$	3,796
Net Income
U.K. Regulated (a)	$	148		$	345		$	434		$	634
Kentucky Regulated	79			76			174			188
Pennsylvania Regulated	77			78			156			172
Corporate and Other	(12		)	(16		)	(69		)	(30		)
Total	$	292		$	483		$	695		$	964

(a) Includes unrealized gains and losses from hedging foreign-currency related economic activity. See Note 13 for additional information.

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

	June 30, 2017			December 31, 2016
Balance Sheet Data
Assets
U.K. Regulated (a)	$	15,798		$	14,537
Kentucky Regulated	14,043			14,037
Pennsylvania Regulated	10,175			9,426
Corporate and Other (b)	(52		)	315
Total	$	39,964		$	38,315

(a) Includes $11.5 billion and $10.8 billion of net PP&E as of June 30, 2017 and December 31, 2016. 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 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. 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.

34

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
	2017		2016		2017		2016
Income (Numerator)
Net income	$	292	$	483	$	695	$	964
Less amounts allocated to participating securities	—		1		1		3
Net income available to PPL common shareowners - Basic and Diluted	$	292	$	482	$	694	$	961
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	683,841		677,145		682,370		676,293
Add incremental non-participating securities:
Share-based payment awards	2,510		3,584		2,355		3,480
Weighted-average shares - Diluted EPS	686,351		680,729		684,725		679,773
Basic EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.02	$	1.42
Diluted EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.01	$	1.41

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
	2017	2016	2017	2016
Stock-based compensation plans (a)	564	795	1,451	2,920
DRIP	369	370	814	772

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

See Note 7 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
	2017	2016	2017	2016
Stock options	696	696	696	696
Performance units	—	78	—	39

35

5. Income Taxes

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

(PPL)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	129		$	236		$	315		$	467
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			9			23			22
Valuation allowance adjustments	—			3			5			9
Impact of lower U.K. income tax rates	(40		)	(45		)	(88		)	(99		)
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(7		)	—			(16		)	(2		)
Impact of the U.K. Finance Acts	(6		)	(2		)	(9		)	(2		)
Depreciation not normalized	(2		)	(3		)	(5		)	(4		)
Interest benefit on U.K. financing entities	(4		)	(4		)	(8		)	(9		)
Stock-based compensation	(4		)	(3		)	(7		)	(11		)
Other	—			1			(5		)	—
Total increase (decrease)	(53		)	(44		)	(110		)	(96		)
Total income taxes	$	76		$	192		$	205		$	371

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

(PPL Electric)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	44		$	44		$	88		$	97
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	9			8			17			18
Depreciation not normalized	(2		)	(2		)	(4		)	(3		)
Stock-based compensation	(3		)	(2		)	(5		)	(7		)
Other	(1		)	—			(1		)	(1		)
Total increase (decrease)	3			4			7			7
Total income taxes	$	47		$	48		$	95		$	104

(LKE)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	49		$	47		$	107		$	114
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5			5			11			12
Other	(1		)	(1		)	(2		)	(3		)
Total increase (decrease)	4			4			9			9
Total income taxes	$	53		$	51		$	116		$	123

36

(LG&E)
	Three Months				Six Months
	2017		2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	24	$	22	$	55		$	54
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3		2		6			6
Other	—		—		(1		)	(1		)
Total increase (decrease)	3		2		5			5
Total income taxes	$	27	$	24	$	60		$	59

(KU)
	Three Months					Six Months
	2017			2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	32		$	31	$	67		$	73
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3			3		7			7
Other	(1		)	—		(1		)	—
Total increase (decrease)	2			3		6			7
Total income taxes	$	34		$	34	$	73		$	80

6. Utility Rate Regulation

(All Registrants)

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

	PPL				PPL Electric
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	—	$	—
Generation formula rate	10		11		—		—
Transmission service charge	—		7		—		7
Gas supply clause	7		3		—		—
Smart meter rider	10		6		10		6
Storm costs	3		5		3		5
Other	1		1		1		1
Total current regulatory assets (a)	$	37	$	39	$	14	$	19
Noncurrent Regulatory Assets:
Defined benefit plans	$	920	$	947	$	537	$	549
Taxes recoverable through future rates	345		340		345		340
Storm costs	40		58		—		10
Unamortized loss on debt	57		61		32		36
Interest rate swaps	124		129		—		—
Accumulated cost of removal of utility plant	162		159		162		159
AROs	245		211		—		—
Other	13		13		—		—
Total noncurrent regulatory assets	$	1,906	$	1,918	$	1,076	$	1,094

37

	PPL				PPL Electric
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Generation supply charge	$	19	$	23	$	19	$	23
Transmission service charge	6		—		6		—
Universal service rider	14		14		14		14
Transmission formula rate	3		15		3		15
Fuel adjustment clause	13		11		—		—
Act 129 compliance rider	11		17		11		17
Storm damage expense	4		13		4		13
Other	1		8		—		1
Total current regulatory liabilities	$	71	$	101	$	57	$	83
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	—	$	—
Power purchase agreement - OVEC (b)	72		75		—		—
Net deferred tax assets	21		23		—		—
Defined benefit plans	27		23		—		—
Interest rate swaps	76		78		—		—
Other	3		—		—		—
Total noncurrent regulatory liabilities	$	902	$	899	$	—	$	—

	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	4	$	6	$	2	$	—
Generation formula rate	10		11		—		—		10		11
Gas supply clause	7		3		7		3		—		—
Total current regulatory assets	$	23	$	20	$	11	$	9	$	12	$	11
Noncurrent Regulatory Assets:
Defined benefit plans	$	383	$	398	$	238	$	246	$	145	$	152
Storm costs	40		48		22		26		18		22
Unamortized loss on debt	25		25		16		16		9		9
Interest rate swaps	124		129		85		88		39		41
AROs	245		211		84		70		161		141
Plant retirement costs	3		4		—		—		3		4
Other	10		9		4		4		6		5
Total noncurrent regulatory assets	$	830	$	824	$	449	$	450	$	381	$	374

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	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Demand side management	$	—	$	3	$	—	$	2	$	—	$	1
Fuel adjustment clause	13		11		4		2		9		9
Other	1		4		—		1		1		3
Total current regulatory liabilities	$	14	$	18	$	4	$	5	$	10	$	13
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	308	$	305	$	395	$	395
Power purchase agreement - OVEC (b)	72		75		50		52		22		23
Net deferred tax assets	21		23		21		23		—		—
Defined benefit plans	27		23		—		—		27		23
Interest rate swaps	76		78		38		39		38		39
Other	3		—		1		—		2		—
Total noncurrent regulatory liabilities	$	902	$	899	$	418	$	419	$	484	$	480

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

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

Regulatory Matters

Kentucky Activities

(PPL, LKE, LG&E and KU)

Rate Case Proceedings

In November 2016, LG&E and KU filed requests with the KPSC for increases in annual base electricity and gas rates. LG&E's and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program.

On April 19, 2017 and May 1, 2017, LG&E and KU, along with all intervening parties to the proceeding, filed with the KPSC, stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things, the proposed stipulations provided for increases in annual revenue requirements associated with KU base electricity rates of $55 million, LG&E base electricity rates of $59 millionand LG&E base gas rates of $8 million, reflecting a return on equity of 9.75%, the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates.

On June 22, 2017, the KPSC issued orders approving, with certain modifications, the proposed stipulations filed in April and May 2017. On June 29, 2017, the KPSC issued further orders correcting certain revenue requirement and rate calculations and making other technical corrections to the June 22, 2017 orders. The combined KPSC orders modified the stipulations to provide for increases in annual revenue requirements associated with KU base electricity rates of $52 million, LG&E base electricity rates of $57 million and LG&E base gas rates of $7 million, and incorporate an authorized return on equity of 9.7%. Consistent with the stipulations, the orders approved LG&E's and KU's request for implementing a Distribution Automation program and their withdrawal of a request for a CPCN for the Advanced Metering System program. The orders also approved new depreciation rates for LG&E and KU that will result in higher depreciation of approximately $15 million ($4 million for LG&E and $11 million for KU) in 2017, exclusive of net additions to PP&E. The orders result in a base electricity rate increase of3.2% at KU and base electricity and gas rate increases of 5.2% and 2.1% at LG&E. The new base rates and all elements of the orders became effective July 1, 2017.On June 23, 2017, the KPSC also issued orders establishing an authorized return on equity of 9.7%for all of LG&E's and KU's existing approved ECR plans and projects, replacing the prior authorized return on equity levels of 9.8%for CCR projects and 10%for all other ECR approved projects, effective with bills issued in August 2017. The impact of the new authorized return for ECR projects is not expected to be significant in 2017.

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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 customers, the franchise fee will revert to zero. In August 2016, LG&E filed an application in a KPSC proceeding to review and rule upon the recoverability of the franchise fee.

In August 2016, Louisville/Jefferson County submitted a motion to dismiss the proceeding filed by LG&E and, in November 2016, filed an amended complaint against LG&E relating to these issues. LG&E submitted KPSC filings to respond to, request dismissal of and consolidate certain claims or aspects of the proceedings. In January 2017, the KPSC issued an order denying Louisville/Jefferson County's motion to dismiss, consolidating the matter with LG&E's filed application and establishing a procedural schedule for the case. Louisville/Jefferson County and LG&E continue to file certain procedural motions, testimony and discovery with the KPSC. Until the KPSC issues a final order in this proceeding, LG&E cannot predict the ultimate outcome of this matter but does not anticipate that it will have a material effect on its financial condition or results of operation. LG&E continues to provide gas service to customers in this franchise area at existing rates, but without collecting or remitting a franchise fee.

7. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, 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. The following credit facilities were in place at: 

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2022	£	210	£	155	£	—	£	56	£	160	£	—
Term Loan Facility (b)	Dec. 2017	230		230		—		—		—		—
WPD (South West)
Syndicated Credit Facility (c)	July 2021	245		80		—		165		110		—
WPD (East Midlands)
Syndicated Credit Facility (d)	July 2021	300		116		—		184		9		—
WPD (West Midlands)
Syndicated Credit Facility	July 2021	300		—		—		300		—		—
Uncommitted Credit Facilities (e)		90		50		4		36		60		4
Total U.K. Credit Facilities (f)		£	1,375	£	631	£	4	£	741	£	339	£	4

40

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2022	$	950	$	—	$	424	$	526	$	—	$	20
Syndicated Credit Facility	Nov. 2018	300		—		—		300		—		—
Bilateral Credit Facility	Mar. 2018	150		—		17		133		—		17
Total PPL Capital Funding Credit Facilities		$	1,400	$	—	$	441	$	959	$	—	$	37
PPL Electric
Syndicated Credit Facility	Jan. 2022	$	650	$	—	$	1	$	649	$	—	$	296
LKE
Syndicated Credit Facility	Oct. 2018	$	75	$	—	$	—	$	75	$	—	$	—
LG&E
Syndicated Credit Facility	Jan. 2022	$	500	$	—	$	207	$	293	$	—	$	169
KU
Syndicated Credit Facility	Jan. 2022	$	400	$	—	$	51	$	349	$	—	$	16
Letter of Credit Facility	Oct. 2017	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	249	$	349	$	—	$	214

(a) The amounts borrowed at June 30, 2017 and December 31, 2016 were USD-denominated borrowings of $200 million for both periods, which bore interest at 1.87% and 1.43%. The unused capacity reflects the amount borrowed in GBP of £154 million as of the date borrowed.

(b) The amount borrowed at June 30, 2017 was a GBP-denominated borrowing which equated to $297 million and bore interest at 1.50%.

(c) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $103 million and $137 million and bore interest at 0.65% and 0.66%.

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

(e) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $65 million and $75 million and bore interest at 1.07% and 1.26%.

(f) At June 30, 2017, the unused capacity under the U.K. credit facilities was $956 million.

(PPL, LKE and KU)

In August 2017, the expiration date for the KU letter of credit facility was extended to October 2020.

(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: 

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	June 30, 2017							December 31, 2016
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	1.46%	$	1,000	$	424	$	576	1.10%	$	20
PPL Electric		650		—		650		1.05%	295
LG&E	1.35%	350		207		143		0.94%	169
KU	1.40%	350		51		299		0.87%	16
Total		$	2,350	$	682	$	1,668		$	500

(PPL Electric and LKE)

See Note 10 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

In March 2017, WPD (South Wales) issued £50 million of 0.01% Index-linked Senior Notes due 2029. WPD (South Wales) received proceeds of £53 million, which equated to $64 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes.

(PPL and PPL Electric)

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

(PPL, LKE and LG&E)

In June 2017, the County of Trimble, Kentucky issued $60 million of Environmental Facilities Revenue Refunding Bonds, 2017 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were issued bearing interest at a rate of 3.75% through their maturity and are subject to an optional redemption on or after June 1, 2027. The proceeds of the bonds were used to redeem $60 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued by the County of Trimble, Kentucky on behalf of LG&E.

In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25% through their mandatory purchase date of June 3, 2019.

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

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

(PPL)

ATM Program

In February 2015, PPL entered into two separate equity distribution agreements, pursuant to which PPL may sell, from time to time, up to an aggregate of $500 million of its common stock. For the periods ended June 30, PPL issued the following:

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	Three Months				Six Months
	2017		2016		2017		2016
Number of shares (in thousands)	2,113		—		3,477		—
Average share price	$	39.15	$	—	$	38.17	$	—
Net Proceeds	$	82	$	—	$	132	$	—

Distributions

In May 2017, PPL declared a quarterly common stock dividend, payable July 3, 2017, of 39.5 cents per share (equivalent to $1.58 per annum). Future dividends, declared at the discretion of the Board of Directors, will depend upon future earnings, cash flows, financial and legal requirements and other factors.

8. Defined Benefits

(PPL, LKE and LG&E)

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

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2017			2016			2017			2016			2017			2016			2017			2016
PPL
Service cost	$	15		$	16		$	18		$	18		$	32		$	33		$	37		$	36
Interest cost	42			44			44			62			84			87			87			124
Expected return on plan assets	(58		)	(58		)	(127		)	(132		)	(115		)	(114		)	(252		)	(265		)
Amortization of:
Prior service cost	3			3			—			—			5			4			—			—
Actuarial loss	14			10			36			36			34			25			71			73
Net periodic defined benefit costs (credits) before special termination benefits	16			15			(29		)	(16		)	40			35			(57		)	(32		)
Special termination benefits (a)	(1		)	—			—			—			1			—			—			—
Net periodic defined benefit costs (credits)	$	15		$	15		$	(29	)	$	(16	)	$	41		$	35		$	(57	)	$	(32	)

(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
	2017			2016			2017			2016
LKE
Service cost	$	5		$	6		$	12		$	12
Interest cost	18			18			34			35
Expected return on plan assets	(24		)	(24		)	(46		)	(45		)
Amortization of:
Prior service cost	2			3			4			4
Actuarial loss	4			5			15			10
Net periodic defined benefit costs	$	5		$	8		$	19		$	16

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	Pension Benefits
	Three Months						Six Months
	2017			2016			2017			2016
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			4			$	6		$	7
Expected return on plan assets	(6		)	(5		)	(11		)	(10		)
Amortization of:
Prior service cost	1			1			2			2
Actuarial loss	1			1			4			3
Net periodic defined benefit costs	$	—		$	2		$	2		$	3

	Other Postretirement Benefits
	Three Months						Six Months
	2017			2016			2017			2016
PPL
Service cost	$	2		$	2		$	4		$	4
Interest cost	6			7			12			13
Expected return on plan assets	(5		)	(6		)	(11		)	(11		)
Amortization of prior service cost	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	2		$	3		$	4		$	6
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			3			4			5
Expected return on plan assets	(2		)	(1		)	(3		)	(3		)
Amortization of prior service cost	—			—			—			1
Net periodic defined benefit costs	$	1		$	3		$	3		$	5

(PPL Electric, LG&E and KU)

In addition to the specific plans 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. 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
	2017		2016		2017		2016
PPL Electric	$	5	$	5	$	13	$	11
LG&E	2		3		5		5
KU	1		3		5		6

Expected Cash Flows - U.K. Pension Plans

(PPL)

For the six months ended June 30, 2017, WPD contributed $485 million to its U.K. pension plans. These accelerated contributions fund all 2017 required contributions and a portion of 2018 required contributions. WPD does not expect to make additional contributions in 2017.

44

9. Commitments and Contingencies

Legal Matters

(All Registrants)

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

WKE Indemnification(PPL and LKE)

See footnote (e) to the table in "Guarantees and Other Assurances" below for information on an LKE indemnity relating to its former WKE lease, including related legal proceedings.

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 and RCRA. In addition, these plaintiffs assert common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In response to a motion to dismiss filed by PPL and LG&E, in July 2014, the court dismissed the plaintiffs' RCRA claims and all but one Clean Air Act claim, but declined to dismiss the common law tort claims. In November 2016, 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 under the Clean Air Act, and directed the parties to submit briefs regarding whether the court should continue to exercise supplemental jurisdiction regarding the remaining state law-only claims. On April 13, 2017, the District Court issued an order declining to exercise supplemental jurisdiction and dismissing the case in its entirety, subject to certain federal appeals or state court re-filing rights of the parties. On June 16, 2017, the plaintiffs filed a class action complaint in Jefferson Circuit Court, Kentucky, against LG&E regarding the 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.PPL, LKE and LG&E cannot predict the outcome of this matter. LG&E retired one coal-fired unit at the Cane Run plant in March 2015 and the remaining two coal-fired units at the plant in June 2015.

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 seek injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act violations, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also seek assessment of civil penalties and an award of litigation costs and attorney fees. PPL, LKE and KU cannot predict the outcome of this matter or the potential impact on the operations of the E.W. Brown plant, including increased capital or operating costs, if any.  

45

(PPL, LKE, LG&E and KU)

Trimble County Water Discharge Permit

In May 2010, the Kentucky Waterways Alliance and other environmental groups filed a petition with the Kentucky Energy and Environment Cabinet (KEEC) challenging the Kentucky Pollutant Discharge Elimination System permit issued in April 2010, which covers water discharges from the Trimble County plant. In November 2010, the KEEC issued a final order upholding the permit, which was subsequently appealed by the environmental groups. In September 2013, the Franklin Circuit Court reversed the KEEC order upholding the permit and remanded the permit to the agency for further proceedings. LG&E and the KEEC appealed the order to the Kentucky Court of Appeals. In July 2015, the Court of Appeals upheld the lower court ruling. LG&E and the KEEC moved for discretionary review by the Kentucky Supreme Court. In February 2016, the Kentucky Supreme Court issued an order granting discretionary review and oral arguments were held in September 2016. On April 27, 2017, the Kentucky Supreme Court issued an order reversing the decision of the appellate court and upholding the permit issued to LG&E by the KEEC. PPL, LKE, LG&E and KU are unable to predict the outcome of this matter or the potential impact on the operations of the Trimble County plant, including increased capital or operating costs, if any, but do not expect such costs to be material.

Trimble County Landfill

Various state and federal permits and regulatory approvals are required in order to construct a landfill at the Trimble County plant to be used for disposal of CCRs. In October 2016, the Kentucky Division of Water issued a water quality certification and in February 2017, the Kentucky Division of Waste Management issued a “special waste” landfill permit. In March 2017, the Sierra Club and a resident adjacent to the plant filed administrative challenges to the landfill permit before the KEEC. In June 2017, the U.S. Army Corps of Engineers issued a dredge and fill permit, the final approval required for construction of the landfill. PPL, LKE, LG&E and KU believe that all permits and regulatory approvals issued for the project comply with applicable state and federal laws, but cannot predict the outcome of legal challenges or the potential impact, if any, on plant operations, or future capital or operating costs. However, PPL, LKE, LG&E and KU believe that additional costs, if any, resulting from such legal challenges would be subject to cost recovery.

Regulatory Issues(All Registrants)

See Note 6 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

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

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

PPL Electric, LG&E and KU monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity (including RFC or SERC) determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC.

In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any.

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,

46

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)

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 plants. The Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six criteria pollutants to protect public health and welfare. These concentration levels are known as NAAQS. The six criteria pollutants are carbon monoxide, lead, nitrogen dioxide, ozone, particulate matter and sulfur dioxide.

Federal environmental regulations of these criteria pollutants require states to adopt implementation plans, known as state implementation plans, for certain pollutants, 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.

National Ambient Air Quality Standards (NAAQS)

Under the Clean Air Act, the EPA is required to reassess the NAAQS for certain air pollutants on a five-year schedule. In 2008, the EPA revised the NAAQS for ozone and proposed to further strengthen the standard in November 2014. The EPA released a new ozone standard on October 1, 2015. The states and the EPA will determine attainment with the new ozone standard through review of relevant ambient air monitoring data, with attainment or nonattainment designations scheduled no later than October 2018. States are also obligated to address interstate transport issues associated with new 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. States that are not in the ozone transport region, including Kentucky, worked together to evaluate the need for further nitrogen oxide reductions from fossil-fueled plants with SCRs. Based on regulatory developments to date, PPL, LKE, LG&E and KU do not anticipate requirements for nitrogen oxide reductions beyond those currently required under the Cross State Air Pollution Rule.

In 2010, the EPA finalized revised NAAQS for sulfur dioxide and required states to identify areas that meet those standards and areas that are in "non-attainment". In July 2013, the EPA finalized non-attainment designations for parts of the country, including part of Jefferson County in Kentucky. Attainment must be achieved by 2018. Based on regulatory developments to date, PPL, LKE, LG&E and KU expect that certain previously required compliance measures, such as upgraded or new sulfur

47

dioxide Scrubbers and additional sulfur dioxide limits at certain plants and the retirement of coal-fired generating units at LG&E's Cane Run plant and KU's Green River plant, are sufficient to achieve compliance with the new sulfur dioxide and ozone 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 Clean Power Plan described below, 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, in March 2017, the President issued an Executive Order (the March 2017 Executive Order) directing the EPA to review proposed and final rules relating to GHG reductions for consistency with certain policy directives and suspend, revise, or rescind those rules as appropriate. The March 2017 Executive Order also directs rescission of specified guidance, directives, and prior Presidential actions regarding climate change. PPL, LKE, LG&E and KU cannot predict the outcome of such regulatory actions or the impact, if any, on plant operations, rate treatment or future capital or operating needs.

The U.K. has enacted binding carbon reduction requirements that are applicable to WPD. Under the U.K. law, WPD must purchase carbon allowances to offset emissions associated with WPD's operations. The cost of these allowances is 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

As further described below, the EPA finalized rules imposing GHG emission standards for both new and existing power plants. The EPA has also issued a proposed federal implementation plan that would apply to any states that fail to submit an acceptable state implementation plan under these rules.

The future of these rules is uncertain. The EPA's authority to promulgate these regulations under Section 111 of the Clean Air Act has been challenged in the D.C. Circuit Court by several states and industry groups. In February 2016, the U.S. Supreme Court stayed the rule for existing plants (the Clean Power Plan) pending the D.C. Circuit Court's review and subsequent review by the U.S. Supreme Court if a writ of certiorari is filed and granted. In addition, the President's March 2017 Executive Order requires the EPA to review the rules for new plants and existing power plants and suspend, revise or rescind them as appropriate.

The EPA's rule for new power plants imposes separate emission standards for coal and natural gas units based on the application of different technologies. The coal standard is based on the application of partial carbon capture and sequestration technology, but because this technology is not presently commercially viable, the rule effectively precludes the construction of new coal-fired plants. The standard for NGCC power plants is the same as what the EPA proposed in 2012 and is not continuously achievable. The preclusion of new coal-fired plants and the compliance difficulties posed for new natural gas-fired plants could have a significant industry-wide impact.

The EPA's rule for existing power plants, referred to as the Clean Power Plan, was published in the Federal Register in October 2015. The Clean Power Plan contains state-specific rate-based and mass-based reduction goals and guidelines for the development, submission and implementation of state implementation plans to achieve the state goals. State-specific goals were calculated from 2012 data by applying the EPA's broad interpretation and definition of the BSER, resulting in the most stringent targets to be met in 2030, with interim targets to be met beginning in 2022. The EPA believes it has offered some flexibility to the states as to how their compliance plans can be crafted, including the option to use a rate-based approach (limit emissions per megawatt hour) or a mass-based approach (limit total tons of emissions per year), and the option to demonstrate compliance

48

through emissions trading and multi-state collaborations. Under the rate-based approach, Kentucky would need to make a 41% reduction from its 2012 emissions rate and under a mass-based approach it would need to make a 36% reduction. These reductions are significantly greater than initially proposed and present significant challenges to the state. If the Clean Power Plan is ultimately upheld and Kentucky fails to develop an approvable implementation plan by the applicable deadline, the EPA may impose a federal implementation plan that could be more stringent than what the state plan might provide. Depending on the provisions of the Kentucky implementation plan, LG&E and KU may need to modify their current portfolio of generating assets during the next decade and/or participate in an allowance trading program.

LG&E and KU are monitoring developments at the state and federal level. Various states, industry groups and individual companies including LKE have filed petitions for reconsideration with the EPA and petitions for review with the D.C. Circuit Court challenging the Clean Power Plan. In February 2016, the U.S. Supreme Court stayed the rule pending the D.C. Circuit Court's review. The EPA has commenced review of the Clean Power Plan and related actions, as directed by the President's March 2017 Executive Order. In April 2017, in response to a motion filed by the EPA, the D.C. Circuit temporarily held the litigation in abeyance in light of the EPA's ongoing review of the Clean Power Plan. PPL, LKE, LG&E and KU cannot predict the outcome of the pending litigation, any changes in regulations, interpretations, or litigation positions that may be implemented by the U.S. presidential administration or the potential impact, if any, on plant operations, or future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, would be subject to cost recovery.

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

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. 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)

Coal Combustion Residuals (CCRs)

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

Recently enacted federal legislation has authorized the EPA to approve equally protective state programs that would operate in lieu of the CCR Rule. In January 2017, Kentucky issued a state rule, effective May 2017, aimed at reflecting the requirements of the federal rule. In May 2017, a resident adjacent to LG&E's and KU's Trimble County plant filed a lawsuit in state court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. PPL, LKE, LG&E and KU cannot predict the outcome of the litigation, but anticipate continued operation under the former program in the event that the new rule is struck down.

49

LG&E and KU have received KPSC approval for a compliance plan providing for construction of additional landfill capacity at the E.W. Brown station, closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with federal CCR rule requirements, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law requirements. See Note 6 in the Registrants' 2016 Form 10-K for additional information.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs during 2015, 2016 and 2017. See Note 15 below and Note 19 in the Registrants' 2016 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.

Effluent Limitations Guidelines (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 June 2017, the EPA published in the Federal Register a rule that would postpone applicable compliance dates until the agency completes reconsideration of the rule. 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 at this time, although certain preliminary estimates are included in current capital forecasts for applicable periods. 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. A range of reasonably possible costs cannot currently be estimated. Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant.

(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

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ANPRM rulemaking is to occur in two phases. Only the second part of the rule, currently scheduled for November 2017, is applicable to PPL operations. This part of the rule relates to the use of PCBs in electrical equipment and natural gas pipelines, as well as continued use of PCB-contaminated porous surfaces. Although the first rulemaking will not directly affect the Registrants' operations, it may indicate certain approaches or principles to occur in the later rulemaking which may affect Registrants' facilities in the United States, including phase-out of some or all equipment containing PCBs. Should such a phase-out be required, the costs, which are subject to rate recovery, could be significant.

Superfund and Other Remediation

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

PPL Electric, LG&E and KU are investigating, responding to agency inquiries, remediating, or have completed the remediation of, several sites that were not addressed under a regulatory program such as Superfund, but for which PPL Electric, LG&E and KU may be liable for remediation. 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 on such additional sites and are therefore unable to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

At June 30, 2017 and December 31, 2016, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites noted 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 for compliance 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 applicable to certain of the costs or other obligations related to these matters but the amount of insurance coverage or reimbursement cannot be estimated or assured.

Other

Labor Union Agreements

(PPL and PPL Electric)

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

51

(LKE and KU)

In August 2017, KU and the United Steelworkers of America ratified a three-year labor agreement through August 2020. The agreement covers approximately 53 employees. The terms of the new labor agreement are not expected to have a significant impact on the financial results of LKE or 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, 2017. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote except for "WPD guarantee of pension and other obligations of unconsolidated entities" and "Indemnification of lease termination and other divestitures." The total recorded liability at June 30, 2017 and December 31, 2016 was $22 million for PPL and $17 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, 2017			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2019
WPD guarantee of pension and other obligations of unconsolidated entities	92		(c)
PPL Electric
Guarantee of inventory value	15		(d)	2018
LKE
Indemnification of lease termination and other divestitures	301		(e)	2021 - 2023
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.

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(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, 2017, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.

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

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

(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 $120 million at June 30, 2017, consisting of LG&E's share of $83 million and KU's share of $37 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LKE's, LG&E's and KU's 2016 Form 10-K for additional information on the OVEC power purchase contract. In connection with recent credit market related developments at OVEC or certain of its sponsors, such parties, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs and accelerated maturities of OVEC's existing short and long-term debt. The ultimate outcome of these matters, including any potential impact on LG&E's and KU's obligations relating to OVEC debt under the power purchase contract cannot be predicted.

The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is remote.

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

10. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other, as applicable, with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. 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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81%.

(LKE)

LKE maintains a $225 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, 2017 and December 31, 2016, $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12%.

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

Other(PPL Electric, LG&E and KU)

See Note 8 for discussions regarding intercompany allocations associated with defined benefits.

11. Other Income (Expense) - net

(PPL)

"Other Income (Expense) - net" for the three and six months ended June 30, 2017 and 2016 consisted primarily of gains (losses) on foreign currency contracts to economically hedge PPL's translation risk related to its GBP denominated earnings in the U.K. See Note 13 for additional information on these derivatives.

12. 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, 2017 and 2016, there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's 2016 Form 10-K for information on the levels in the fair value hierarchy.

Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

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	June 30, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	467	$	467	$	—	$	—	$	341	$	341	$	—	$	—
Restricted cash and cash equivalents (a)	25		25		—		—		26		26		—		—
Price risk management assets (b):
Foreign currency contracts	156		—		156		—		211		—		211		—
Cross-currency swaps	158		—		158		—		188		—		188		—
Total price risk management assets	314		—		314		—		399		—		399		—
Total assets	$	806	$	492	$	314	$	—	$	766	$	367	$	399	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	31	$	—	$	31	$	—	$	31	$	—	$	31	$	—
Foreign currency contracts	104		—		104		—		27		—		27		—
Total price risk management liabilities	$	135	$	—	$	135	$	—	$	58	$	—	$	58	$	—
PPL Electric
Assets
Cash and cash equivalents	$	59	$	59	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	61	$	61	$	—	$	—	$	15	$	15	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	13	$	13	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	21	$	21	$	—	$	—	$	16	$	16	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
LG&E
Assets
Cash and cash equivalents	$	7	$	7	$	—	$	—	$	5	$	5	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	9	$	9	$	—	$	—	$	8	$	8	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—

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	June 30, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—
Total assets	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—

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

(b) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

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

Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps

(PPL, LKE, LG&E and KU)

To manage interest rate risk, PPL, LKE, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency risk, PPL uses foreign currency contracts such as forwards, options and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3.

Financial Instruments Not Recorded at Fair Value(All Registrants)

The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. The fair values were estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporate the credit risk of the Registrants. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.

	June 30, 2017				December 31, 2016
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	19,068	$	22,791	$	18,326	$	21,355
PPL Electric	3,298		3,705		2,831		3,148
LKE	5,067		5,535		5,065		5,439
LG&E	1,619		1,749		1,617		1,710
KU	2,327		2,572		2,327		2,514

(a) Amounts are net of debt issuance costs.

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

13. 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

56

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 the 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 mechanisms in place.

Foreign currency risk

• PPL is exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates.

Commodity price risk

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

• PPL Electric is exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to commodity price risk by entering into full-requirement supply agreements to serve its PLR customers. These supply agreements transfer the commodity price risk associated with the PLR obligation to the energy suppliers.

• LG&E's and KU's rates include certain mechanisms for fuel and fuel-related expenses. 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 period, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 2016 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.

57

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 mechanisms 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 LG&E, KU or PPL Electric defaults on its obligation, those entities 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, thus 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

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 $27 million obligation to return cash collateral under master netting arrangements at June 30, 2017 and a $19 million obligation to return cash collateral under master netting arrangements at December 31, 2016.

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

PPL, LKE and LG&E posted $2 million of cash collateral under master netting arrangements at June 30, 2017 and $3 million of cash collateral under master netting arrangements at December 31, 2016.

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. Various financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolio, adjust the duration of the debt portfolio 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.

58

Cash Flow Hedges

(PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. At June 30, 2017, PPL held an aggregate notional value in interest rate swap contracts of £145 million (approximately $187 million based on spot rates) that mature in 2027 to hedge the interest payments of anticipated WPD debt issuances. These swaps require a mandatory early redemption on or before November 30, 2017.

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

At June 30, 2017, PPL held an aggregate notional value in cross-currency interest rate swap contracts of $802 million that range in maturity from 2017 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, 2017 and 2016, 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, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2016, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At June 30, 2017, 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, 2017, 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 such contracts outstanding at June 30, 2017.

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

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Economic Activity

PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings. At June 30, 2017, the total exposure hedged by PPL was approximately £2.8 billion (approximately $3.7 billion based on contracted rates). These contracts had termination dates ranging from July 2017 through December 2019.

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 and KU's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at June 30, 2017 and December 31, 2016.

See Notes 1 and 17 in each Registrant's 2016 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, 2017								December 31, 2016
	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)	$	—	$	1	$	—	$	5	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	28		—		—		—		32		—		—		—
Foreign currency contracts	—		—		41		60		—		—		31		21
Total current	28		1		41		65		32		—		31		25
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		25		—		—		—		27
Cross-currency swaps (b)	130		—		—		—		156		—		—		—
Foreign currency contracts	—		—		115		44		—		—		180		6
Total noncurrent	130		—		115		69		156		—		180		33
Total derivatives	$	158	$	1	$	156	$	134	$	188	$	—	$	211	$	58

(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, 2017.

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								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

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, 2016.

								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	$	(3	)	$	(21	)	Interest expense	$	(2	)	$	—	$	(3	)	$	—
Cross-currency swaps	(104		)	9			Interest expense	(1		)	—		—			—
							Other income (expense) - net	(103		)	—		(6		)	—
Total	$	(107	)	$	(12	)		$	(106	)	$	—	$	(9	)	$	—
Net Investment Hedges:
Foreign currency contracts	$	1		$	4

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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	$	171		$	231
Interest rate swaps	Interest expense	(2		)	(4		)
	Total	$	169		$	227
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	$	(3	)	$	(9	)

(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, 2017				December 31, 2016
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4
Total current	—		5		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		25		—		27
Total noncurrent	—		25		—		27
Total derivatives	$	—	$	30	$	—	$	31

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets 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

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, 2016. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(4	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(3	)	$	(9	)

62

(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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

Credit Risk-Related Contingent Features

Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LKE, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.

Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LKE's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.

(PPL, LKE and LG&E)

At June 30, 2017, 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:

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	PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	23	$	12	$	12
Aggregate fair value of collateral posted on these derivative instruments	2		2		2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	21		10		10

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

14. Goodwill and Other Intangible Assets

(PPL)

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

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

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

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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, 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	)
March 31, 2016	$	(984	)	$	(5	)	$	—		$	(6	)	$	(2,164	)	$	(3,159	)
Amounts arising during the period	268			(85		)	—			—			2			185
Reclassifications from AOCI	—			85			(1		)	1			32			117
Net OCI during the period	268			—			(1		)	1			34			302
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
December 31, 2015	$	(520	)	$	(7	)	$	—		$	(6	)	$	(2,195	)	$	(2,728	)
Amounts arising during the period	(196		)	(5		)	—			—			2			(199		)
Reclassifications from AOCI	—			7			(1		)	1			63			70
Net OCI during the period	(196		)	2			(1		)	1			65			(129		)
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
LKE
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	)
March 31, 2016							$	—		$	(10	)	$	(35	)	$	(45	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							(1		)	1			1			1
Net OCI during the period							(1		)	1			2			2
June 30, 2016							$	(1	)	$	(9	)	$	(33	)	$	(43	)

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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, 2015			$	—		$	(10	)	$	(36	)	$	(46	)
Amounts arising during the period			—			—			1			1
Reclassifications from AOCI			(1		)	1			2			2
Net OCI during the period			(1		)	1			3			3
June 30, 2016			$	(1	)	$	(9	)	$	(33	)	$	(43	)

(PPL)

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

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2017			2016			2017			2016			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(5	)	$	(3	)	Interest Expense
Cross-currency swaps	(29		)	(103		)	(26		)	(6		)	Other Income (Expense) - net
	(1		)	(1		)	—			—			Interest Expense
Total Pre-tax	(32		)	(106		)	(31		)	(9		)
Income Taxes	7			21			7			2
Total After-tax	(25		)	(85		)	(24		)	(7		)
Equity investees' AOCI	(1		)	1			(1		)	1			Other Income (Expense) - net
Total Pre-tax	(1		)	1			(1		)	1
Income Taxes	—			—			—			—
Total After-tax	(1		)	1			(1		)	1
Defined benefit plans
Prior service costs	(1		)	(1		)	(1		)	(1		)
Net actuarial loss	(40		)	(40		)	(81		)	(80		)
Total Pre-tax	(41		)	(41		)	(82		)	(81		)
Income Taxes	9			8			18			17
Total After-tax	(32		)	(33		)	(64		)	(64		)
Total reclassifications during the period	$	(58	)	$	(117	)	$	(89	)	$	(70	)

17. New Accounting Guidance Pending Adoption

(All Registrants)

Accounting for Revenue from Contracts with Customers

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

For public business entities, this guidance can be applied using either a full retrospective or modified retrospective transition method, beginning in annual reporting periods after December 15, 2017 and interim periods within those years. The Registrants will adopt this guidance effective January 1, 2018.

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The Registrants have performed an assessment of a significant portion of their revenue under this new guidance to determine its effect on their current revenue recognition policies, and at this time they do not believe it will have a material impact. However, the Registrants will continue to monitor the development of industry specific application guidance which could have an impact on their assessments. The Registrants are currently assessing the disclosure requirements included in the standard, which will result in increased information being provided to enable the users of the financial statements to understand the nature, amount, timing and uncertainty of revenue arising from contracts with customers. The Registrants will determine the transition method they will apply after the industry specific application guidance is final and the implications of using either the full retrospective or modified retrospective transition methods are known.

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 lines.

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 companies for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. The new standard must be adopted using a modified retrospective transition, and provides for certain practical expedients. Transition will require application of the new guidance at the beginning of the earliest comparative period presented.

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

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 in annual reporting periods beginning after December 15, 2018, including interim periods within those years.

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

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

In March 2017, the FASB issued accounting guidance that changes the income statement presentation of net periodic benefit cost. This new guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during the period. The other components of net periodic benefits will be presented separately from the line items that include the service cost and outside of any subtotal of operating income. Only the service cost component is eligible for capitalization.

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

The Registrants are currently assessing the impact of adopting this guidance and will adopt this guidance effective January 1, 2018.

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(PPL, LKE, LG&E and KU)

Simplifying the Test for Goodwill Impairment

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

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

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

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

Results of Operations

(All Registrants)

This "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by PPL, PPL Electric, LKE, LG&E and KU. Information contained herein relating to any individual Registrant is filed by such Registrant solely on its own behalf, and no Registrant makes any representation as to information relating to any other Registrant. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for individual Registrants when significant.

The following should be read in conjunction with the Registrants' Condensed Consolidated Financial Statements and the accompanying Notes and with the Registrants' 2016 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, 2017 with the same periods in 2016. For PPL, "Results of Operations" also includes "Segment Earnings" and "Margins" which provide a detailed analysis of earnings by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Margins" and provide explanations of the non-GAAP financial measures and a reconciliation of the non-GAAP financial measures to the most comparable GAAP measure. The "2017 Outlook" discussion identifies key factors expected to impact 2017 earnings. For PPL Electric, LKE, LG&E and KU, a summary of earnings and margins is also provided.

• "Financial Condition - Liquidity and Capital Resources" provides an analysis of the Registrants' liquidity positions and credit profiles. This section also includes a discussion of 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 distribution and sale of natural gas in Kentucky		KU* ●Engages in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky
U.K. Regulated Segment		Kentucky Regulated Segment			Pennsylvania Regulated Segment

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

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

(PPL Electric)

PPL Electric, headquartered in Allentown, Pennsylvania, is a direct wholly owned subsidiary of PPL and a regulated public utility that is an electricity transmission and distribution service provider in eastern and central Pennsylvania. PPL Electric is subject to regulation as a public utility by the PUC, and certain of its transmission activities are subject to the jurisdiction of the FERC under the Federal Power Act. PPL Electric delivers electricity in its Pennsylvania service area and provides electricity supply to retail customers in that area as a PLR under the Customer Choice Act.

(LKE)

LKE, headquartered in Louisville, Kentucky, is a wholly owned subsidiary of PPL and a holding company that owns regulated utility operations through its subsidiaries, LG&E and KU, which constitute substantially all of LKE's assets. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain separate corporate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name and in Tennessee under the KU name.

(LG&E)

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

(KU)

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

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

Business Strategy

(All Registrants)

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

PPL's businesses of WPD, PPL Electric, LG&E and KU plan 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 and RAV, as applicable, driven by planned significant capital expenditures to maintain existing assets and improve system reliability and, for LKE, LG&E and KU, to comply with federal and state environmental regulations related to coal-fired electricity generation facilities. Additionally, significant transmission rate base growth is expected through at least 2020 at PPL Electric.

For the U.S. businesses, our strategy is to recover capital project costs efficiently through various rate-making mechanisms, including periodic base rate case proceedings using forward test years, annual FERC formula rate mechanisms and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, the KPSC has adopted a series of regulatory mechanisms (ECR, DSM, GLT, fuel adjustment clause, gas supply clause and recovery on construction work-in-progress) that reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs. In addition, the KPSC requires a utility to obtain a CPCN prior to constructing a facility, unless the construction is an ordinary extension of existing facilities in the usual course of business or does not involve sufficient capital outlay to materially affect the utility's financial condition. Although such KPSC proceedings do not directly address cost recovery issues, the KPSC, in awarding a CPCN, concludes that the public convenience and necessity require the construction of the facility on the basis that the facility is the lowest reasonable cost alternative to address the need. In Pennsylvania, the FERC transmission formula rate, DSIC mechanism, Smart Meter Rider and other recovery mechanisms are in place to reduce regulatory lag and provide for timely recovery of and a return on, as appropriate, prudently incurred costs.

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

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

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Financial and Operational Developments

U.S. Tax Reform (All Registrants)

Tax reform has been discussed as a high priority of the U.S. presidential administration. Significant uncertainty exists as to the ultimate changes that may be made, the timing of those changes and the related impact to the Registrants' financial condition or results of operations. The Registrants are working with industry groups and carefully monitoring related developments in an effort both to have input to the legislative process where possible and plan effectively to respond to any forthcoming changes in a manner that will optimize value for ratepayers and shareowners.

U.K. Membership in European Union (PPL)

On March 29, 2017, the U.K. formally notified the European Council of the European Union (EU) of its intent to withdraw from the EU, thereby commencing the two-year negotiation period to establish the terms of that withdrawal under Article 50 of the Lisbon Treaty. Article 50 specifies that if a member state decides to withdraw from the EU, it must notify the European Council of its intention to leave the EU, negotiate the terms of withdrawal and establish the legal grounds for its future relationship with the EU. Article 50 provides two years from the date of the Article 50 notification to conclude negotiations. Failure to complete negotiations within two years, unless negotiations are extended, would result in the treaties governing the EU no longer being applicable to the U.K. with there being no agreement in place governing the U.K.'s relationship with the EU. Under the terms of Article 50, negotiations can only be extended beyond two years if all of the 27 remaining EU states agree to an extension. Any withdrawal agreement will need to be approved by both the European Council and the European 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 August 2, 2017, PPL's foreign exchange exposure related to budgeted earnings is 98% hedged for the remainder of 2017 at an average rate of $1.18 per GBP, 99% hedged for 2018 and 2019 at an average rate of $1.37 and $1.35 per GBP and 7% hedged for 2020 at an average rate of $1.48 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.

(PPL)

In July 2017, Ofgem published an open letter commencing its RIIO-2 framework review, which covers all U.K. gas and electricity, transmission and distribution price controls. The purpose of this framework review is to build on lessons learned from the current price controls and to develop a framework that will be adaptable to meeting the needs of an evolving U.K. energy sector.

The letter sets out the context for the development of the next price controls, RIIO-2, and seeks views from stakeholders on the RIIO-2 framework. Responses to the open letter will be used to guide the full RIIO-2 framework consultation which is expected to be published in the first quarter of 2018. The promulgation of sector specific price controls will begin with the gas and electricity transmission networks, with electricity distribution price control work scheduled to begin in 2020, at which time Ofgem plans to publish its RIIO-ED2 strategy consultation document.

The current electricity distribution price control, RIIO-ED1, continues through March 31, 2023 and will not be impacted by this RIIO-2 consultation process. 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. 

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(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 9 to the Financial Statements for a discussion of the other significant environmental matters.

Rate Case Proceedings

(PPL, LKE, LG&E and KU)

In November 2016, LG&E and KU filed requests with the KPSC for increases in annual base electricity and gas rates. LG&E's and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program.

On April 19, 2017 and May 1, 2017, LG&E and KU, along with all intervening parties to the proceeding, filed with the KPSC, stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things, the proposed stipulations provided for increases in annual revenue requirements associated with KU base electricity rates of $55 million, LG&E base electricity rates of $59 millionand LG&E base gas rates of $8 million, reflecting a return on equity of 9.75%, the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates.

On June 22, 2017, the KPSC issued orders approving, with certain modifications, the proposed stipulations filed in April and May 2017. On June 29, 2017, the KPSC issued further orders correcting certain revenue requirement and rate calculations and making other technical corrections to the June 22, 2017 orders. The combined KPSC orders modified the stipulations to provide for increases in annual revenue requirements associated with KU base electricity rates of $52 million, LG&E base electricity rates of $57 million and LG&E base gas rates of $7 million, and incorporate an authorized return on equity of 9.7%. Consistent with the stipulations, the orders approved LG&E's and KU's request for implementing a Distribution Automation program and their withdrawal of a request for a CPCN for the Advanced Metering System program. The orders also approved new depreciation rates for LG&E and KU that will result in higher depreciation of approximately $15 million ($4 million for LG&E and $11 million for KU) in 2017, exclusive of net additions to PP&E. The orders result in a base electricity rate increase of3.2% at KU and base electricity and gas rate increases of 5.2% and 2.1% at LG&E. The new base rates and all elements of the orders became effective July 1, 2017.On June 23, 2017, the KPSC also issued orders establishing an authorized return on equity of 9.7%for all of LG&E's and KU's existing approved ECR plans and projects, replacing the prior authorized return on equity levels of 9.8%for CCR projects and 10%for all other ECR approved projects, effective with bills issued in August 2017. The impact of the new authorized return for ECR projects is not expected to be significant in 2017.

(PPL, LKE and KU)

In October 2016, KU filed a request with the FERC to modify its formula rates to provide for the recovery of CCR impoundment closure costs from its departing municipal customers. In December 2016, the FERC accepted the revised rate schedules providing recovery of the costs effective December 31, 2016, subject to refund, and established limited hearing and settlement judge procedures relating to determining the applicable amortization period. In March 2017, the parties reached a settlement in principle regarding a suitable amortization period. In June 2017, a FERC judge issued an order implementing the settlement's rates on an interim basis, effective July 1, 2017, pending final review by the FERC.

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, 2017 with the same periods in 2016. The "Segment Earnings" and "Margins" discussions for PPL provide a review of results by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Margins," and provide explanations of the non-GAAP financial measures and a reconciliation of those measures to the most comparable GAAP measure. The "2017 Outlook" discussion identifies key factors expected to impact 2017 earnings.

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Tables analyzing changes in amounts between periods within "Statement of Income Analysis," "Segment Earnings" and "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 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, 2017 with the same periods in 2016. The "Earnings" discussion provides a summary of earnings. The "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.

PPL: Statement of Income Analysis, Segment Earnings and Margins

Statement of Income Analysis

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

	Three Months								Six Months
	2017			2016		$ Change			2017			2016		$ Change
Operating Revenues	$	1,725		$	1,785	$	(60	)	$	3,676		$	3,796	$	(120	)
Operating Expenses
Operation
Fuel	183			183		—			374			380		(6		)
Energy purchases	136			147		(11		)	351			380		(29		)
Other operation and maintenance	388			425		(37		)	820			875		(55		)
Depreciation	246			231		15			488			460		28
Taxes, other than income	70			74		(4		)	145			153		(8		)
Total Operating Expenses	1,023			1,060		(37		)	2,178			2,248		(70		)
Other Income (Expense) - net	(112		)	174		(286		)	(159		)	235		(394		)
Interest Expense	222			224		(2		)	439			448		(9		)
Income Taxes	76			192		(116		)	205			371		(166		)
Net Income	$	292		$	483	$	(191	)	$	695		$	964	$	(269	)

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Operating Revenues

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

	Three Months			Six Months
Domestic:
PPL Electric Distribution price (a)	$	19		$	31
PPL Electric Distribution volume	(7		)	(10		)
PPL Electric PLR Revenue (b)	(10		)	(31		)
PPL Electric Transmission Formula Rate	4			5
LKE Volumes	(8		)	(45		)
LKE Fuel and other energy prices (c)	7			18
LKE DSM	3			8
Other	(7		)	(8		)
Total Domestic	1			(32		)
U.K.:
Price	20			78
Volume	(20		)	(11		)
Foreign currency exchange rates	(69		)	(165		)
Other	8			10
Total U.K.	(61		)	(88		)
Total	$	(60	)	$	(120	)

(a) Distribution rider prices resulted in increases of $13 million and $24 million for the three and six months ended June 30, 2017.

(b) Decreases primarily due to lower energy purchase prices at PPL Electric.

(c) Increases due to higher recoveries of fuel and energy purchases primarily as a result of higher commodity costs at LKE.

Energy Purchases

Energy purchases decreased $11 million and $29 million for the three and six months ended June 30, 2017 compared with 2016, primarily due to lower PLR prices at PPL Electric.

Other Operation and Maintenance

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

	Three Months			Six Months
Domestic:
LKE plant operations and maintenance	$	(3	)	$	(3	)
LKE timing and scope of generation maintenance outages	(6		)	(5		)
PPL Electric Act 129	3			8
PPL Electric vegetation management	(3		)	(3		)
PPL Electric bad debts	(3		)	(6		)
Other	(4		)	8
U.K.:
Network maintenance	(2		)	(9		)
Foreign currency exchange rates	(6		)	(15		)
Pension (a)	(18		)	(35		)
Other	5			5
Total	$	(37	)	$	(55	)

(a) The decreases were primarily due to increases in expected returns on higher asset balances and lower interest costs due to a lower discount rate.

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Depreciation

Depreciation increased $15 million and $28 million for the three and six months ended June 30, 2017 compared with 2016, primarily due to additional assets placed into service, net of retirements, partially offset by the impact of foreign currency exchange rates at WPD.

Other Income (Expense) - net

Other income (expense) - net decreased $286 million and $394 million for the three and six months ended June 30, 2017 compared with 2016, primarily due to changes in realized and unrealized gains (losses) on foreign currency contracts to economically hedge GBP denominated earnings from WPD.

Interest Expense

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

	Three Months			Six Months
Long-term debt interest expense	$	9		$	13
Short-term debt interest expense	3			4
Foreign currency exchange rates	(12		)	(27		)
Other	(2		)	1
Total	$	(2	)	$	(9	)

Income Taxes 

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

	Three Months			Six Months
Change in pre-tax income at current period tax rates	$	(101	)	$	(140	)
Valuation allowances adjustments	(3		)	(4		)
Impact of U.K. Finance Acts	(4		)	(7		)
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(7		)	(14		)
Stock-based compensation	(1		)	4
Other	—			(5		)
Total	$	(116	)	$	(166	)

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

Segment Earnings

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

	Three Months									Six Months
	2017			2016			$ Change			2017			2016			$ Change
U.K. Regulated	$	148		$	345		$	(197	)	$	434		$	634		$	(200	)
Kentucky Regulated	79			76			3			174			188			(14		)
Pennsylvania Regulated	77			78			(1		)	156			172			(16		)
Corporate and Other (a)	(12		)	(16		)	4			(69		)	(30		)	(39		)
Net Income	$	292		$	483		$	(191	)	$	695		$	964		$	(269	)

(a) Primarily represents financing and certain other costs incurred at the corporate level that have not been allocated or assigned to the segments, which are presented to reconcile segment information to PPL's consolidated results. The changes in 2017 compared with 2016 are primarily due to the utilization of an estimated annual effective tax rate, which required the tax benefits realized in the first quarter of 2017 to be recognized over the annual period. This impact is expected to reverse through the remainder of the year.

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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 13 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
	2017			2016			$ Change			2017			2016			$ Change
U.K. Regulated	$	212		$	241		$	(29	)	$	519		$	506		$	13
Kentucky Regulated	79			76			3			175			188			(13		)
Pennsylvania Regulated	77			78			(1		)	156			172			(16		)
Corporate and Other	(12		)	(15		)	3			(69		)	(28		)	(41		)
Earnings from Ongoing Operations	$	356		$	380		$	(24	)	$	781		$	838		$	(57	)

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 62% of PPL's Net Income for the six months ended June 30, 2017 and 40% of PPL's assets at June 30, 2017.

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
	2017			2016		$ Change			2017			2016		$ Change
Operating revenues	$	502		$	563	$	(61	)	$	1,070		$	1,158	$	(88	)
Other operation and maintenance	62			85		(23		)	126			182		(56		)
Depreciation	57			60		(3		)	112			120		(8		)
Taxes, other than income	30			35		(5		)	61			70		(9		)
Total operating expenses	149			180		(31		)	299			372		(73		)
Other Income (Expense) - net	(113		)	172		(285		)	(156		)	233		(389		)
Interest Expense	97			104		(7		)	191			210		(19		)
Income Taxes	(5		)	106		(111		)	(10		)	175		(185		)
Net Income	148			345		(197		)	434			634		(200		)
Less: Special Items	(64		)	104		(168		)	(85		)	128		(213		)
Earnings from Ongoing Operations	$	212		$	241	$	(29	)	$	519		$	506	$	13

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
		2017			2016		2017			2016
Foreign currency economic hedges, net of tax of $34, ($56), $46, ($69) (a)	Other Income (Expense) - net	$	(64	)	$	104	$	(85	)	$	128
Total Special Items		$	(64	)	$	104	$	(85	)	$	128

(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. 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.
Gross margins	$	—		$	70
Other operation and maintenance	21			44
Depreciation	(4		)	(8		)
Interest expense	(6		)	(8		)
Other	—			(2		)
Income taxes	10			5
U.S.
Interest expense and other	2			—
Income taxes	(3		)	31
Foreign currency exchange, after-tax	(49		)	(119		)
Earnings from Ongoing Operations	(29		)	13
Special items, after-tax	(168		)	(213		)
Net Income	$	(197	)	$	(200	)

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U.K.

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

• Lower other operation and maintenance expense for the three month period primarily due to $18 million from lower pension expense due to an increase in expected returns on higher asset balances and lower interest costs due to a lower discount rate.

• Lower other operation and maintenance expense for the six month period primarily due to $35 million from lower pension expense due to an increase in expected returns on higher asset balances and lower interest costs due to a lower discount rate and $9 million from lower network maintenance expense.

• Higher interest expense for the three month period primarily due to $7 million higher interest expense on indexed linked bonds.

• Lower income taxes for the three month period primarily due to decreases of $6 million from 2016 expense related to the finalization of U.K. tax returns and $4 million related to tax rate changes to deferred taxes.

• Lower income taxes for the six month period primarily due to decreases of $10 million primarily related to accelerated tax deductions, $6 million from 2016 expense related to the finalization of U.K. tax returns and $6 million related to tax rate changes to deferred taxes, partially offset by an increase of $19 million from higher pre-tax income.

U.S.

• Lower income taxes for the six month period primarily due to the tax benefit on accelerated pension contributions made in the first quarter of 2017.

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 25% of PPL's Net Income for the six months endedJune 30, 2017 and 35% of PPL's assets at June 30, 2017.

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

	Three Months									Six Months
	2017			2016			$ Change			2017			2016			$ Change
Operating revenues	$	723		$	721		$	2		$	1,532		$	1,547		$	(15	)
Fuel	183			182			1			374			380			(6		)
Energy purchases	29			28			1			98			94			4
Other operation and maintenance	192			204			(12		)	399			406			(7		)
Depreciation	105			100			5			210			199			11
Taxes, other than income	16			15			1			32			30			2
Total operating expenses	525			529			(4		)	1,113			1,109			4
Other Income (Expense) - net	(4		)	(5		)	1			(6		)	(6		)	—
Interest Expense	66			64			2			131			129			2
Income Taxes	49			47			2			108			115			(7		)
Net Income	79			76			3			174			188			(14		)
Less: Special Items	—			—			—			(1		)	—			(1		)
Earnings from Ongoing Operations	$	79		$	76		$	3		$	175		$	188		$	(13	)

The following after-tax gain (loss), which management considers a special item, impacted the Kentucky Regulated segment's results and is excluded from Earnings from Ongoing Operations during the periods ended June 30.

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	Income Statement Line Item	Three Months				Six Months
		2017		2016		2017			2016
Adjustment to investment, net of tax of $0, $0, $0, $0 (a)	Other Income (Expense) - net	$	—	$	—	$	(1	)	$	—
Total Special Items		$	—	$	—	$	(1	)	$	—

(a) KU recorded a write-off of an equity method investment.

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

	Three Months			Six Months
Kentucky Gross Margins	$	(5	)	$	(23	)
Other operation and maintenance	12			10
Depreciation	(2		)	(5		)
Taxes, other than income	1			(1		)
Other Income (Expense) - net	1			1
Interest Expense	(2		)	(2		)
Income Taxes	(2		)	7
Earnings from Ongoing Operations	3			(13		)
Special items, after-tax	—			(1		)
Net Income	$	3		$	(14	)

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

• Lower other operation and maintenance expense for the three month period primarily due to lower costs related to the timing and scope of generation maintenance outages of $6 million and lower plant operations and maintenance of $4 million.

• Lower other operation and maintenance expense for the six month period primarily due to lower costs related to the timing and scope of generation maintenance outages of $5 million and lower plant operations and maintenance of $4 million.

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 22% of PPL's Net Income for the six months endedJune 30, 2017 and 25% of PPL's assets at June 30, 2017.

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

	Three Months							Six Months
	2017		2016		$ Change			2017		2016		$ Change
Operating revenues	$	500	$	495	$	5		$	1,073	$	1,080	$	(7	)
Energy purchases	107		118		(11		)	253		285		(32		)
Other operation and maintenance	139		138		1			303		288		15
Depreciation	76		62		14			151		121		30
Taxes, other than income	23		24		(1		)	52		53		(1		)
Total operating expenses	345		342		3			759		747		12
Other Income (Expense) - net	5		5		—			6		8		(2		)
Interest Expense	36		32		4			69		65		4
Income Taxes	47		48		(1		)	95		104		(9		)
Net Income	77		78		(1		)	156		172		(16		)
Less: Special Items (a)	—		—		—			—		—		—
Earnings from Ongoing Operations	$	77	$	78	$	(1	)	$	156	$	172	$	(16	)

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

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

	Three Months			Six Months
Pennsylvania Gross Margins	$	7		$	8
Other operation and maintenance	2			(8		)
Depreciation	(9		)	(21		)
Taxes, other than income	2			2
Other Income (Expense) - net	—			(2		)
Interest Expense	(4		)	(4		)
Income Taxes	1			9
Net Income	$	(1	)	$	(16	)

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

• Lower other operation and maintenance expense for the three month period primarily due to $3 million of lower bad debt expense, $3 million of lower vegetation management expenses and $3 million of lower payroll related expenses, partially offset by $9 million of higher corporate service costs allocated to PPL Electric.

• Higher other operation and maintenance expense for the six month period primarily due to $17 million of higher corporate service costs allocated to PPL Electric, partially offset by $6 million of lower bad debt expense and $3 million of lower vegetation management expenses.

• Higher depreciation expense for the three and six month periods primarily due to transmission and distribution additions placed into service related to the ongoing efforts to improve reliability and replace aging infrastructure, net of retirements.

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.

	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

	2016 Three Months
	U.K. Regulated		KY Regulated		PA Regulated		Corporate and Other			Total
Net Income	$	345	$	76	$	78	$	(16	)	$	483
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($56)	104		—		—		—			104
Spinoff of the Supply segment, net of tax of $0	—		—		—		(1		)	(1		)
Total Special Items	104		—		—		(1		)	103
Earnings from Ongoing Operations	$	241	$	76	$	78	$	(15	)	$	380

81

	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

	2016 Six Months
	U.K. Regulated		KY Regulated		PA Regulated		Corporate and Other			Total
Net Income	$	634	$	188	$	172	$	(30	)	$	964
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($69)	128		—		—		—			128
Spinoff of the Supply segment, net of tax of $1	—		—		—		(2		)	(2		)
Total Special Items	128		—		—		(2		)	126
Earnings from Ongoing Operations	$	506	$	188	$	172	$	(28	)	$	838

Margins

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

• "U.K. Gross Margins" is a single financial performance measure of the electricity distribution operations of the U.K. Regulated segment. In calculating this measure, direct costs such as connection charges from National Grid, which owns and manages the electricity transmission network in England and Wales, and Ofgem license fees (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues, as they are costs passed through to customers. As a result, this measure represents the net revenues from the delivery of electricity across WPD's distribution network in the U.K. and directly related activities.

• "Kentucky 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 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 and Universal Service program costs), "Depreciation" (which is primarily related to the 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.

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Changes in Margins

The following table shows 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
	2017		2016		$ Change			2017		2016		$ Change
U.K. Regulated
U.K. Gross Margins	$	469	$	534	$	(65	)	$	1,005	$	1,090	$	(85	)
Impact of changes in foreign currency exchange rates					(65		)					(155		)
U.K. Gross Margins excluding impact of foreign currency exchange rates					$	—						$	70
Kentucky Regulated
Kentucky Gross Margins
LG&E	$	207	$	209	$	(2	)	$	433	$	437	$	(4	)
KU	259		262		(3		)	540		559		(19		)
Total Kentucky Gross Margins	$	466	$	471	$	(5	)	$	973	$	996	$	(23	)
Pennsylvania Regulated
Pennsylvania Gross Margins
Distribution	$	219	$	216	$	3		$	477	$	474	$	3
Transmission	115		111		4			223		218		5
Total Pennsylvania Gross Margins	$	334	$	327	$	7		$	700	$	692	$	8

U.K. Gross Margins

U.K. Gross Margins, excluding the impact of changes in foreign currency exchange rates, were flat for the three months ended June 30, 2017 compared with 2016 primarily due to $27 million from the April 1, 2016 price increase offset by $20 million of lower volumes and $7 million from the April 1, 2017 price decrease, which includes lower true-up mechanisms partially offset by higher base demand revenue.

U.K. Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased for the six months ended June 30, 2017 compared with 2016 primarily due to $85 million from the April 1, 2016 price increase partially offset by $11 million of lower volumes and $7 million from the April 1, 2017 price decrease, which includes lower true-up mechanisms partially offset by higher base demand revenue and the recovery of prior customer rebates.

Kentucky Gross Margins

Kentucky Gross Margins decreased for the three months ended June 30, 2017 compared with 2016 primarily due to $5 million of lower electricity sales volumes due to milder weather in the second quarter of 2017 ($1 million at LG&E and $4 million at KU).

Kentucky Gross Margins decreased for the six months endedJune 30, 2017 compared with 2016 primarily due to $27 million of lower electricity sales volumes due to milder weather in 2017 ($6 million at LG&E and $21 million at KU).

Pennsylvania Gross Margins

Pennsylvania Gross Margins increased for the three months ended June 30, 2017 compared with 2016 primarily due to an increase of $11 million primarily from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability, partially offset by a $7 million decrease as a result of a lower PJM zonal peak load billing factor which affected transmission revenue in the second quarter of 2017.

Pennsylvania Gross Margins increased for the six months ended June 30, 2017 compared with 2016 primarily due to an increase of $22 million primarily from returns on additional transmission capital investments focused on replacing aging

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infrastructure and improving reliability, partially offset by a $17 million decrease as a result of a lower PJM zonal peak load billing factor which affected transmission revenue in the first five months of 2017.

Reconciliation of 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.

	2017 Three Months
	U.K. Gross Margins			Kentucky Gross Margins		PA 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		309			388
Depreciation	—			16		5		225			246
Taxes, other than income	—			3		23		44			70
Total Operating Expenses	22			257		166		578			1,023
Total	$	469		$	466	$	334	$	(567	)	$	702

	2016 Three Months
	U.K. Gross Margins			Kentucky Gross Margins		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	553	(c)	$	721	$	495	$	16		$	1,785
Operating Expenses
Fuel	—			182		—		1			183
Energy purchases	—			28		118		1			147
Other operation and maintenance	19			26		28		352			425
Depreciation	—			13		—		218			231
Taxes, other than income	—			1		22		51			74
Total Operating Expenses	19			250		168		623			1,060
Total	$	534		$	471	$	327	$	(607	)	$	725

	2017 Six Months
	U.K. Gross Margins			Kentucky Gross Margins		PA 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		663			820
Depreciation	—			32		9		447			488
Taxes, other than income	—			3		51		91			145
Total Operating Expenses	45			559		373		1,201			2,178
Total	$	1,005		$	973	$	700	$	(1,180	)	$	1,498

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	2016 Six Months
	U.K. Gross Margins			Kentucky Gross Margins		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,137	(c)	$	1,547	$	1,080	$	32		$	3,796
Operating Expenses
Fuel	—			380		—		—			380
Energy purchases	—			94		285		1			380
Other operation and maintenance	47			49		53		726			875
Depreciation	—			26		—		434			460
Taxes, other than income	—			2		50		101			153
Total Operating Expenses	47			551		388		1,262			2,248
Total	$	1,090		$	996	$	692	$	(1,230	)	$	1,548

(a) Represents amounts excluded from 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, 2017 and $10 million and $21 million for the three and six months ended June 30, 2016.

2017 Outlook

(PPL)

The following projections and factors underlying these projections (on an after-tax basis) are provided for PPL's segments and the Corporate and Other category and the related Registrants.

(PPL's U.K. Regulated Segment)

Lower net income is projected in 2017 compared with 2016 primarily driven by a lower assumed GBP exchange rate in 2017, lower true-up mechanisms, lower incentive revenues, higher interest expense and higher depreciation expense, partially offset by lower operation and maintenance expense, including pension expense, and higher base revenue from the April 1, 2017 price reset.

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

Lower net income is projected in 2017 compared with 2016 primarily driven by lower electricity sales volumes due to unfavorable weather in 2017 and higher depreciation expense, partially offset by electricity and gas base rate increases.

(PPL's Pennsylvania Regulated Segment and PPL Electric)

Relatively flat net income is projected in 2017 compared with 2016 primarily driven by higher transmission earnings and lower operation and maintenance expense, offset by higher depreciation expense and higher interest expense.

(PPL's Corporate and Other Category)

Relatively flat costs are projected in 2017 compared with 2016.

(All Registrants)

Earnings in future periods are subject to various risks and uncertainties. See "Forward-Looking Information," the rest of this Item 2, Notes 6 and 9 to the Financial Statements and "Item 1A. Risk Factors" in this Form 10-Q (as applicable) and "Item 1. Business" and "Item 1A. Risk Factors" in the Registrants' 2016 Form 10-K for a discussion of the risks, uncertainties and factors that may impact future earnings.

85

PPL Electric: Statement of Income Analysis, Earnings and Margins

Statement of Income Analysis

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

	Three Months							Six Months
	2017		2016		$ Change			2017		2016		$ Change
Operating Revenues	$	500	$	495	$	5		$	1,073	$	1,080	$	(7	)
Operating Expenses
Operation
Energy purchases	107		118		(11		)	253		285		(32		)
Other operation and maintenance	138		137		1			302		287		15
Depreciation	76		62		14			151		121		30
Taxes, other than income	23		24		(1		)	52		53		(1		)
Total Operating Expenses	344		341		3			758		746		12
Other Income (Expense) - net	3		5		(2		)	4		8		(4		)
Interest Income from Affiliate	1		—		1			1		—		1
Interest Expense	36		32		4			69		65		4
Income Taxes	47		48		(1		)	95		104		(9		)
Net Income	$	77	$	79	$	(2	)	$	156	$	173	$	(17	)

Operating Revenues

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

	Three Months			Six Months
Distribution Price (a)	$	19		$	31
Distribution volume	(7		)	(10		)
PLR (b)	(10		)	(31		)
Transmission Formula Rate	4			5
Other	(1		)	(2		)
Total	$	5		$	(7	)

(a) Distribution rider prices resulted in increases of $13 million and $24 million for the three and six months ended June 30, 2017.

(b) Decrease primarily due to lower energy prices as described below.

Energy Purchases

Energy purchases decreased $11 million for the three months endedJune 30, 2017 compared with 2016 primarily due to lower PLR prices of $9 million and lower PLR volumes of $1 million.

Energy purchases decreased $32 million for the six months endedJune 30, 2017 compared with 2016 primarily due to lower PLR prices of $32 million, partially offset by higher PLR volumes of $3 million.

Other Operation and Maintenance

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

86

	Three Months			Six Months
Corporate service costs	$	9		$	17
Vegetation management	(3		)	(3		)
Payroll-related costs	(3		)	(1		)
Act 129	3			8
Bad debts	(3		)	(6		)
Other	(2		)	—
Total	$	1		$	15

Depreciation

Depreciation increased $14 million and $30 million for the three and six months ended June 30, 2017 compared with 2016, 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.

Interest Expense

Interest expense increased $4 million for the three and six months ended June 30, 2017, compared with 2016, primarily due to the May 2017 issuance of $475 million of 3.950% First Mortgage Bonds due 2047.

Income Taxes

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

	Three Months			Six Months
Change in pre-tax income at current period tax rates	$	—		$	(10	)
Stock-based compensation	(1		)	2
Other	—			(1		)
Total	$	(1	)	$	(9	)

Earnings

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2017		2016		2017		2016
Net Income	$	77	$	79	$	156	$	173
Special items, gains (losses), after-tax (a)	—		—		—		—

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

Earnings decreased for the three month period in 2017 compared with 2016 as higher transmission margins from additional capital investments were offset by the impact of a lower PJM zonal peak load billing factor and higher depreciation expense.

Earnings decreased for the six month period in 2017 compared with 2016 primarily due to higher depreciation expense, primarily due to transmission and distribution additions placed into service related to the ongoing efforts to improve reliability and replace aging infrastructure, net of retirements, and higher other operation and maintenance expense, primarily due to higher corporate service costs. Higher transmission margins from additional capital investments were partially offset by the impact of a lower PJM zonal peak load billing factor.

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

87

	Three Months			Six Months
Pennsylvania Gross Margins	$	7		$	8
Other operation and maintenance	2			(8		)
Depreciation	(9		)	(21		)
Taxes, other than income	2			2
Other Income (Expense) - net	(1		)	(3		)
Interest Expense	(4		)	(4		)
Income Taxes	1			9
Net Income	$	(2	)	$	(17	)

Margins

"Pennsylvania 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 - Margins" for information on why management believes this measure is useful and for explanations of the underlying drivers of the changes between periods.

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. 

	2017 Three Months							2016 Three Months
	PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	500	$	—		$	500	$	495	$	—		$	495
Operating Expenses
Energy purchases	107		—			107		118		—			118
Other operation and maintenance	31		107			138		28		109			137
Depreciation	5		71			76		—		62			62
Taxes, other than income	23		—			23		22		2			24
Total Operating Expenses	166		178			344		168		173			341
Total	$	334	$	(178	)	$	156	$	327	$	(173	)	$	154
	2017 Six Months							2016 Six Months
	PA Gross Margins		Other (a)			Operating Income (b)		PA Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,073	$	—		$	1,073	$	1,080	$	—		$	1,080
Operating Expenses
Energy purchases	253		—			253		285		—			285
Other operation and maintenance	60		242			302		53		234			287
Depreciation	9		142			151		—		121			121
Taxes, other than income	51		1			52		50		3			53
Total Operating Expenses	373		385			758		388		358			746
Total	$	700	$	(385	)	$	315	$	692	$	(358	)	$	334

(a) Represents amounts excluded from Margins.

(b) As reported on the Statements of Income.

88

LKE: Statement of Income Analysis, Earnings and Margins

Statement of Income Analysis

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

	Three Months									Six Months
	2017			2016			$ Change			2017			2016			$ Change
Operating Revenues	$	723		$	721		$	2		$	1,532		$	1,547		$	(15	)
Operating Expenses
Operation
Fuel	183			182			1			374			380			(6		)
Energy purchases	29			28			1			98			94			4
Other operation and maintenance	192			204			(12		)	399			406			(7		)
Depreciation	105			100			5			210			199			11
Taxes, other than income	16			15			1			32			30			2
Total Operating Expenses	525			529			(4		)	1,113			1,109			4
Other Income (Expense) - net	(4		)	(5		)	1			(6		)	(6		)	—
Interest Expense	50			48			2			99			97			2
Interest Expense with Affiliate	4			4			—			8			8			—
Income Taxes	53			51			2			116			123			(7		)
Net Income	$	87		$	84		$	3		$	190		$	204		$	(14	)

Operating Revenues

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

	Three Months			Six Months
Volumes	$	(8	)	$	(45	)
Fuel and other energy prices (a)	7			18
DSM	3			8
Other	—			4
Total	$	2		$	(15	)

(a) Increases due to higher recoveries of fuel and energy purchases due to higher commodity costs.

Other Operation and Maintenance

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

	Three Months			Six Months
Plant operations and maintenance	$	(3	)	$	(3	)
Timing and scope of generation maintenance outages	(6		)	(5		)
Storm costs	(1		)	—
Other	(2		)	1
Total	$	(12	)	$	(7	)

89

Earnings

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2017		2016		2017			2016
Net Income	$	87	$	84	$	190		$	204
Special items, gains (losses), after-tax	—		—		(1		)	—

Earnings increased for the three month period in 2017 compared with 2016 primarily due to lower other operation and maintenance expense.

Earnings decreased for the six month period in 2017 compared with 2016 primarily due to lower electricity sales volumes driven by milder weather in 2017.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Margins and an item that management considers special on separate lines and not in their respective Statement of Income line items.  

	Three Months			Six Months
Margins	$	(5	)	$	(23	)
Other operation and maintenance	12			10
Depreciation	(2		)	(5		)
Taxes, other than income	1			(1		)
Other Income (Expense) - net	1			1
Interest Expense	(2		)	(2		)
Income Taxes	(2		)	7
Special items, gains (losses), after-tax (a)	—			(1		)
Net Income	$	3		$	(14	)

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

Margins

"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 - 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 Margins are referred to as "Kentucky 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.

	2017 Three Months							2016 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	723	$	—		$	723	$	721	$	—		$	721
Operating Expenses
Fuel	183		—			183		182		—			182
Energy purchases	29		—			29		28		—			28
Other operation and maintenance	26		166			192		26		178			204
Depreciation	16		89			105		13		87			100
Taxes, other than income	3		13			16		1		14			15
Total Operating Expenses	257		268			525		250		279			529
Total	$	466	$	(268	)	$	198	$	471	$	(279	)	$	192

90

	2017 Six Months							2016 Six Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,532	$	—		$	1,532	$	1,547	$	—		$	1,547
Operating Expenses
Fuel	374		—			374		380		—			380
Energy purchases	98		—			98		94		—			94
Other operation and maintenance	52		347			399		49		357			406
Depreciation	32		178			210		26		173			199
Taxes, other than income	3		29			32		2		28			30
Total Operating Expenses	559		554			1,113		551		558			1,109
Total	$	973	$	(554	)	$	419	$	996	$	(558	)	$	438

(a) Represents amounts excluded from Margins.

(b) As reported on the Statements of Income.

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

Statement of Income Analysis

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

	Three Months								Six Months
	2017		2016			$ Change			2017			2016			$ Change
Operating Revenues
Retail and wholesale	$	320	$	317		$	3		$	694		$	692		$	2
Electric revenue from affiliate	4		6			(2		)	21			17			4
Total Operating Revenues	324		323			1			715			709			6
Operating Expenses
Operation
Fuel	69		69			—			149			147			2
Energy purchases	25		23			2			89			85			4
Energy purchases from affiliate	3		3			—			5			5			—
Other operation and maintenance	86		92			(6		)	173			179			(6		)
Depreciation	45		42			3			89			83			6
Taxes, other than income	9		7			2			17			15			2
Total Operating Expenses	237		236			1			522			514			8
Other Income (Expense) - net	1		(5		)	6			(1		)	(5		)	4
Interest Expense	19		18			1			36			35			1
Income Taxes	27		24			3			60			59			1
Net Income	$	42	$	40		$	2		$	96		$	96		$	—

91

Operating Revenues

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

	Three Months			Six Months
Volumes	$	(5	)	$	(10	)
Fuel and other energy prices (a)	4			8
DSM	1			4
Other	1			4
Total	$	1		$	6

(a) Increases due to higher recoveries of fuel and energy purchases due to higher commodity costs.

Other Operation and Maintenance

The decrease in other operation and maintenance for the periods ended June 30, 2017 compared with 2016 was due to:

	Three Months			Six Months
Plant operations and maintenance	$	(1	)	$	(1	)
Timing and scope of generation maintenance outages	(1		)	(1		)
Storm costs	(1		)	(1		)
Other	(3		)	(3		)
Total	$	(6	)	$	(6	)

Depreciation

Depreciation increased $3 million and $6 million for the three and six months ended June 30, 2017 compared with 2016 primarily due to additions to PP&E, net of retirements.

Income Taxes

Income taxes increased $3 million and $1 million for the three and six months ended June 30, 2017 compared with 2016 primarily due to higher pre-tax income.

Earnings

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2017		2016		2017		2016
Net Income	$	42	$	40	$	96	$	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 month period in 2017 compared with 2016 primarily due to lower other operation and maintenance expense.

Earnings remained flat for the six month period in 2017 compared with 2016 primarily due to lower other operation and maintenance expense, offset by lower sales volumes driven by milder weather in 2017 and higher depreciation expense.

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

92

	Three Months			Six Months
Margins	$	(2	)	$	(4	)
Other operation and maintenance	5			6
Depreciation	(2		)	(2		)
Taxes, other than income	(1		)	(2		)
Other Income (Expense) - net	6			4
Interest Expense	(1		)	(1		)
Income Taxes	(3		)	(1		)
Net Income	$	2		$	—

Margins

"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 - 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 Margins are included in "Kentucky 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.

	2017 Three Months							2016 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	324	$	—		$	324	$	323	$	—		$	323
Operating Expenses
Fuel	69		—			69		69		—			69
Energy purchases, including affiliate	28		—			28		26		—			26
Other operation and maintenance	10		76			86		11		81			92
Depreciation	8		37			45		7		35			42
Taxes, other than income	2		7			9		1		6			7
Total Operating Expenses	117		120			237		114		122			236
Total	$	207	$	(120	)	$	87	$	209	$	(122	)	$	87
	2017 Six Months							2016 Six Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	715	$	—		$	715	$	709	$	—		$	709
Operating Expenses
Fuel	149		—			149		147		—			147
Energy purchases, including affiliate	94		—			94		90		—			90
Other operation and maintenance	20		153			173		20		159			179
Depreciation	17		72			89		13		70			83
Taxes, other than income	2		15			17		2		13			15
Total Operating Expenses	282		240			522		272		242			514
Total	$	433	$	(240	)	$	193	$	437	$	(242	)	$	195

(a) Represents amounts excluded from Margins.

(b) As reported on the Statements of Income.

93

KU: Statement of Income Analysis, Earnings and Margins

Statement of Income Analysis

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

	Three Months								Six Months
	2017			2016		$ Change			2017			2016			$ Change
Operating Revenues
Retail and wholesale	$	403		$	404	$	(1	)	$	838		$	855		$	(17	)
Electric revenue from affiliate	3			3		—			5			5			—
Total Operating Revenues	406			407		(1		)	843			860			(17		)
Operating Expenses
Operation
Fuel	114			113		1			225			233			(8		)
Energy purchases	4			5		(1		)	9			9			—
Energy purchases from affiliate	4			6		(2		)	21			17			4
Other operation and maintenance	100			107		(7		)	209			213			(4		)
Depreciation	61			58		3			121			116			5
Taxes, other than income	7			8		(1		)	15			15			—
Total Operating Expenses	290			297		(7		)	600			603			(3		)
Other Income (Expense) - net	(2		)	1		(3		)	(3		)	(1		)	(2		)
Interest Expense	24			23		1			48			47			1
Income Taxes	34			34		—			73			80			(7		)
Net Income	$	56		$	54	$	2		$	119		$	129		$	(10	)

Operating Revenue

The increase (decrease) in operating revenue for the periods ended June 30, 2017 compared with 2016 was due to:

	Three Months			Six Months
Volumes	$	(6	)	$	(30	)
Fuel and other energy prices (a)	2			8
DSM	2			4
Other	1			1
Total	$	(1	)	$	(17	)

(a) Increases due to higher recoveries of fuel due to higher commodity costs.

Fuel

Fuel decreased $8 million for the six months endedJune 30, 2017 compared with 2016 primarily due to a $17 million decrease in volumes driven by milder weather in the first quarter of 2017, partially offset by a $9 million increase in fuel prices.

94

Other Operation and Maintenance

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

	Three Months			Six Months
Plant operations and maintenance	$	(2	)	$	(1	)
Timing and scope of generation maintenance outages	(4		)	(4		)
Other	(1		)	1
Total	$	(7	)	$	(4	)

Earnings

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2017		2016		2017			2016
Net Income	$	56	$	54	$	119		$	129
Special items, gains (losses), after-tax	—		—		(1		)	—

Earnings increased for the three month period in 2017 compared with 2016 primarily due to lower other operation and maintenance expense.

Earnings decreased for the six month period in 2017 compared with 2016 primarily due to lower sales volumes driven by milder weather in 2017, partially offset by lower other operation and maintenance expense.

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

	Three Months			Six Months
Margins	$	(3	)	$	(19	)
Other operation and maintenance	8			7
Depreciation	(1		)	(3		)
Taxes, other than income	2			1
Other Income (Expense) - net	(3		)	(1		)
Interest Expense	(1		)	(1		)
Income Taxes	—			7
Special items, gains (losses), after-tax (a)	—			(1		)
Net Income	$	2		$	(10	)

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

Margins

"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 - 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 Margins are included in "Kentucky 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.

95

	2017 Three Months							2016 Three Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	406	$	—		$	406	$	407	$	—		$	407
Operating Expenses
Fuel	114		—			114		113		—			113
Energy purchases, including affiliate	8		—			8		11		—			11
Other operation and maintenance	16		84			100		15		92			107
Depreciation	8		53			61		6		52			58
Taxes, other than income	1		6			7		—		8			8
Total Operating Expenses	147		143			290		145		152			297
Total	$	259	$	(143	)	$	116	$	262	$	(152	)	$	110
	2017 Six Months							2016 Six Months
	Margins		Other (a)			Operating Income (b)		Margins		Other (a)			Operating Income (b)
Operating Revenues	$	843	$	—		$	843	$	860	$	—		$	860
Operating Expenses
Fuel	225		—			225		233		—			233
Energy purchases, including affiliate	30		—			30		26		—			26
Other operation and maintenance	32		177			209		29		184			213
Depreciation	15		106			121		13		103			116
Taxes, other than income	1		14			15		—		15			15
Total Operating Expenses	303		297			600		301		302			603
Total	$	540	$	(297	)	$	243	$	559	$	(302	)	$	257

(a) Represents amounts excluded from Margins.

(b) As reported on the Statements of Income.

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, 2017
Cash and cash equivalents	$	467	$	59	$	19	$	7	$	12
Notes receivable from affiliate			270		—		—		—
Short-term debt	1,497		—		258		207		51
Notes payable with affiliate			—		159		—		—
December 31, 2016
Cash and cash equivalents	$	341	$	13	$	13	$	5	$	7
Short-term debt	923		295		185		169		16
Notes payable with affiliate			—		163		—		—

(a) At June 30, 2017, $92 million of cash and cash equivalents were denominated in GBP. If these amounts would be remitted as dividends, PPL would not anticipate a material incremental U.S. tax cost. Historically, dividends paid by foreign subsidiaries have been limited to distributions of the current year's earnings. See Note 5 to the Financial Statements in PPL's 2016 Form 10-K for additional information on undistributed earnings of WPD.

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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
2017
Operating activities	$	790		$	279		$	511		$	264		$	257
Investing activities	(1,382		)	(824		)	(355		)	(177		)	(177		)
Financing activities	711			591			(150		)	(85		)	(75		)
2016
Operating activities	$	1,170		$	328		$	506		$	273		$	311
Investing activities	(1,347		)	(427		)	(439		)	(237		)	(201		)
Financing activities	(152		)	87			(81		)	(47		)	(113		)
Change  - Cash Provided (Used)
Operating activities	$	(380	)	$	(49	)	$	5		$	(9	)	$	(54	)
Investing activities	(35		)	(397		)	84			60			24
Financing activities	863			504			(69		)	(38		)	38

Operating Activities

The components of the change in cash provided by (used in) operating activities for the six months ended June 30, 2017 compared with 2016 were as follows.

	PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Net income	$	(269	)	$	(17	)	$	(14	)	$	—		$	(10	)
Non-cash components	233			13			(20		)	1			(3		)
Working capital	(57		)	(15		)	24			(24		)	(35		)
Defined benefit plan funding	(328		)	(24		)	16			13			(8		)
Other operating activities	41			(6		)	(1		)	1			2
Total	$	(380	)	$	(49	)	$	5		$	(9	)	$	(54	)

(PPL)

PPL's cash provided by operating activities in 2017 decreased $380 million compared with 2016.

• The $233 million increase in non-cash components was primarily due to an increase in unrealized losses on derivatives partially offset by a decrease in deferred income tax expense.

• The $57 million decrease in cash from changes in working capital was primarily due to a decrease in counterparty collateral, a decrease in accounts payable (primarily due to timing of payments) and a decrease in taxes payable (primarily due to an increase in current income tax benefit in 2017) partially offset by a decrease in unbilled revenue (primarily due to a decrease in volumes due to less favorable weather in 2017 compared to 2016) and a decrease in fuel, materials and supplies (primarily due to a decrease in fuel purchases due to less favorable weather in 2017 compared to 2016).

• Defined benefit plan funding was $328 million higher in 2017. The increase was primarily due to the acceleration of WPD's contributions to its U.K. pension plans. See Note 8 to the Financial Statements for additional information.

(PPL Electric)

PPL Electric's cash provided by operating activities in 2017 decreased $49 million compared with 2016.

• The $15 million decrease in cash from changes in working capital was primarily due to an increase in prepayments (primarily due to higher tax payments) and a decrease in accounts payable (primarily due to timing of payments) partially offset by a net decrease in current regulatory assets and regulatory liabilities (due to the timing of rate recovery mechanisms) and decreases in accounts receivable from customers and unbilled revenues, primarily due to unfavorable weather in 2017.

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• Defined benefit plan funding was $24 million higher in 2017.

(LKE)

LKE's cash provided by operating activities in 2017increased$5 million compared with 2016.

• The increase in cash from changes in working capital was primarily driven by decreases in accounts receivable from customers and unbilled revenues due to less favorable weather in 2017 compared to 2016, an increase in taxes payable due to timing of payments, and a decrease in fuel purchases due to less favorable weather in 2017 compared to 2016, partially offset by a decrease in accounts payable due to the timing of fuel purchases and payments.

(LG&E)

LG&E's cash provided by operating activities in 2017decreased$9 million compared with 2016.

• The decrease in cash from changes in working capital was primarily driven by decreases in taxes payable due to timing of payments, accounts payable due to timing of fuel purchases and payments and accounts payable to affiliates due to timing of intercompany settlements associated with operational expenses and inventory, partially offset by decreases in accounts receivable from customers and unbilled revenues due to less favorable weather in 2017 compared to 2016 and accounts receivable from affiliates due to timing of intercompany settlements associated with inventory and energy sales to KU.

(KU)

KU's cash provided by operating activities in 2017decreased$54 million compared with 2016.

• The decrease in cash from changes in working capital was primarily driven by decreases in accounts payable due to the timing of fuel purchases and payments, taxes payable due to timing of payments and accounts payable to affiliates due to the timing of intercompany settlements associated with operational expenses and inventory, partially offset by a decrease in accounts receivable from customers and unbilled revenues due to less favorable weather in 2017 compared to 2016.

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, 2017 compared with 2016 was as follows. 

	PPL			PPL Electric			LKE		LG&E		KU
Decrease (Increase)	$	(27	)	$	(126	)	$	84	$	60	$	24

For PPL, the increase in expenditures was due to higher project expenditures at PPL Electric partially offset by lower project expenditures at WPD, LG&E and KU. The increase in expenditures for PPL Electric was primarily due to the Act 129 Smart Meter program and various enhancement reliability projects. The decrease in expenditures for WPD was primarily due to a decrease in foreign currency exchange rates partially offset by an increase in expenditures to enhance system reliability. The decrease in expenditures for LG&E was primarily due to reduced spending for environmental air projects at LG&E's Mill Creek plant. The decrease in expenditures for KU was primarily due to reduced spending for environmental air 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, 2017 compared with 2016 were as follows.

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	PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	198		$	470		$	—		$	—		$	—
Settlement of cross-currency swaps	(46		)	—			—			—			—
Stock issuances/redemptions, net	101			—			—			—			—
Dividends	(16		)	(37		)	—			(61		)	3
Capital contributions/distributions, net	—			375			(141		)	(47		)	(20		)
Change in short-term debt, net	620			(301		)	199			70			54
Notes payable with affiliate	—			—			(127		)	—			—
Other financing activities	6			(3		)	—			—			1
Total	$	863		$	504		$	(69	)	$	(38	)	$	38

See Note 7 to the Financial Statements in this Form 10-Q for information on 2017 short and long-term debt activity, equity transactions and PPL dividends. See the Registrants' 2016 Form 10-K for information on 2016 activity.

Credit Facilities

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. Amounts borrowed under these credit facilities are reflected in "Short-term debt" on the Balance Sheets. At June 30, 2017, the total committed borrowing capacity and the use of that capacity under these credit facilities was as follows:

External

	Committed Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity
PPL Capital Funding Credit Facilities	$	1,400	$	—	$	441	$	959
PPL Electric Credit Facility	650		—		1		649
LKE Credit Facility	75		—		—		75
LG&E Credit Facility	500		—		207		293
KU Credit Facilities	598		—		249		349
Total LKE	1,173		—		456		717
Total U.S. Credit Facilities (a)	$	3,223	$	—	$	898	$	2,325
Total U.K. Credit Facilities (b)	£	1,285	£	581	£	—	£	705

(a) The commitments under the U.S. credit facilities are provided by a diverse bank group, with no one bank and its affiliates providing an aggregate commitment of more than the following percentages of the total committed capacity: PPL - 10%, PPL Electric - 7%, LKE - 21%, LG&E - 7% and KU - 37%.

(b) The amounts borrowed at June 30, 2017 were a USD-denominated borrowing of $200 million and GBP-denominated borrowings which equated to $550 million. The unused capacity reflects the USD-denominated borrowing amount borrowed in GBP of £154 million as of the date borrowed. At June 30, 2017, the USD equivalent of unused capacity under the U.K. committed credit facilities was $910 million.

The commitments under the U.K. credit facilities are provided by a diverse bank group, with no one bank providing more than 20% of the total committed capacity.

See Note 7 to the Financial Statements for further discussion of the Registrants' credit facilities.

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Intercompany (LKE, LG&E and KU)

	Committed Capacity		Borrowed		Other Used Capacity		Unused Capacity
LKE Credit Facility	$	225	$	159	$	—	$	66
LG&E Money Pool (a)	500		—		207		293
KU Money Pool (a)	500		—		51		449

(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 10 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, 2017:

	Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding	$	1,000	$	424	$	576
PPL Electric	650		—		650
LG&E	350		207		143
KU	350		51		299
Total LKE	700		258		442
Total PPL	$	2,350	$	682	$	1,668

Long-term Debt

(PPL)

In March 2017, WPD (South Wales) issued £50 million of 0.01% Index-linked Senior Notes due 2029. WPD (South Wales) received proceeds of £53 million, which equated to $64 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes.

(PPL and PPL Electric)

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

(PPL, LKE and LG&E)

In June 2017, the County of Trimble, Kentucky issued $60 million of Environmental Facilities Revenue Refunding Bonds, 2017 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were issued bearing interest at a rate of 3.75% through their maturity and are subject to optional redemption on or after June 1, 2027. The proceeds of the bonds were used to redeem $60 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued by the County of Trimble, Kentucky on behalf of LG&E.

In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of

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

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

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

(PPL)

ATM Program

For the periods ended June 30, 2017, PPL issued the following:

	Three Months		Six Months
Number of shares (in thousands)	2,113		3,477
Average share price	$	39.15	$	38.17
Net Proceeds	$	82	$	132

See Note 7 to the Financial Statements for further discussion of the ATM program.

Common Stock Dividends

In May 2017, PPL declared a quarterly common stock dividend, payable July 3, 2017, of 39.5 cents per share (equivalent to $1.58 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 2017:

(PPL and PPL Electric)

In January 2017, Moody's and S&P affirmed their commercial paper ratings for PPL Electric's $650 million commercial paper program.

In May 2017, Moody's and S&P assigned ratings of A1 and A to PPL Electric's $475 million 3.95% First Mortgage Bonds due 2047.

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(PPL, LKE and LG&E)

In March 2017, Moody's assigned a rating of A1 and S&P confirmed a rating of A to LG&E's $128 million 1.5% Series A Pollution Control Revenue Bonds due 2033.

In May 2017, Moody's assigned a rating of A1, and in June 2017, S&P confirmed a rating of A to LG&E's $31 million 1.25% Series A Environmental Facilities Revenue Refunding Bonds due 2033.

In May 2017, Moody's assigned a rating of A1, and in June 2017, S&P confirmed a rating of A to LG&E's $35 million 1.25% Series B Environmental Facilities Revenue Refunding Bonds due 2033.

In May 2017, Moody's and S&P assigned ratings of A1 and A to LG&E's $60 million 3.75% Series A Pollution Control Revenue Bonds due 2033.

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 13 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, 2017.

(All Registrants)

For additional information on the Registrants' liquidity and capital resources, see "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Registrants' 2016 Form 10-K.

Risk Management

Market Risk

(All Registrants)

See Notes 12 and 13 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, 2017.

	Exposure Hedged		Fair Value, Net - Asset (Liability) (a)			Effect of a 10% Adverse Movement in Rates (b)			Maturities Ranging Through
PPL
Cash flow hedges
Interest rate swaps (c)	$	187	$	(2	)	$	(2	)	2027
Cross-currency swaps (c)	802		161			(91		)	2028
Economic hedges
Interest rate swaps (d)	147		(30		)	(2		)	2033
LKE
Economic hedges
Interest rate swaps (d)	147		(30		)	(2		)	2033
LG&E
Economic hedges
Interest rate swaps (d)	147		(30		)	(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, 2017 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, 2017 is shown below.

	10% Adverse Movement in Rates
PPL	$	578
PPL Electric	166
LKE	175
LG&E	64
KU	97

Foreign Currency Risk (PPL)

PPL is exposed to foreign currency risk primarily through investments in 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, 2017.

	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)	£	2,770	$	52	$	(335	)	2019

(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 exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to commodity price risk by entering into full-requirement supply agreements to serve its PLR customers. These supply agreements transfer the commodity price risk associated with the PLR obligation to the energy suppliers.

• LG&E's and KU's rates include certain mechanisms for fuel and fuel-related expenses. 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 period, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 2016 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 12 and 13 to the Financial Statements in this Form 10-Q and "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Risk Management - Credit Risk" in the Registrants' 2016 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 gain of $207 million for the six months ended June 30, 2017, which primarily reflected a $367 million increase to PP&E and a $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. Changes in this exchange rate resulted in a foreign currency translation loss of $199 million for the six months ended June 30, 2016, which primarily reflected a $398 million decrease to PP&E and $95 million decrease to goodwill partially offset by a $246 million decrease to long-term debt and a $48 million decrease to other net liabilities. The impact of foreign currency translation is recorded in AOCI.

Related Party Transactions(All Registrants)

The Registrants are not aware of any material ownership interests or operating responsibility by senior management in outside partnerships, including leasing transactions with variable interest entities, or other entities doing business with the Registrants. See Note 10 to the Financial Statements for additional information on related party transactions for PPL Electric, LKE, LG&E and KU.

Acquisitions, Development and Divestitures(All Registrants)

The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures and development projects. Development projects are reexamined based on market conditions and other factors to determine whether to proceed with, modify or terminate the projects. Any resulting transactions may impact future financial results. See Note 8 to the Financial Statements in the Registrants' 2016 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

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Registrants' businesses. The cost of compliance or alleged non-compliance cannot be predicted with certainty but could be significant. In addition, costs may increase significantly if the requirements or scope of environmental laws or regulations, or similar rules, are expanded or changed. Costs may take the form of increased capital expenditures or operating and maintenance expenses, monetary fines, penalties or other restrictions. In addition, the regulatory reviews specified in the President's March 2017 Executive Order promoting energy independence and economic growth could result in future regulatory changes and additional uncertainty. Many of these environmental law considerations are also applicable to the operations of key suppliers, or customers, such as coal producers and industrial power users, and may impact the cost for their products or their demand for the Registrants' services. Increased capital and operating costs are subject to rate recovery. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.

See Note 9 to the Financial Statements for a discussion of the more significant environmental matters including:

• Legal Matters,

• Climate Change,

• Coal Combustion Residuals,

• Effluent Limitations Guidelines, and

• National Ambient Air Quality Standards.

Additionally, see "Item 1. Business - Environmental Matters" in the Registrants' 2016 Form 10-K for additional information on environmental matters.

New Accounting Guidance(All Registrants)

See Note 17 to the Financial Statements for a discussion of new accounting guidance 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' 2016 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
Goodwill Impairment	X		X	X	X
AROs	X		X	X	X
Price Risk Management	X
Regulatory Assets and Liabilities	X	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, 2017, 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 regulatory, environmental and other matters, which information is incorporated by reference into this Part II, see:

• "Item 3. Legal Proceedings" in each Registrant's 2016 Form 10-K; and

• Notes 6 and 9 to the Financial Statements.

Item 1A. Risk Factors

There have been no material changes in the Registrants' risk factors from those disclosed in "Item 1A. Risk Factors" of the Registrants' 2016 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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4(a)	-	Supplemental Indenture No. 19, dated as of May 1, 2017, of PPL Electric Utilities Corporation to The Bank of New York Mellon, as Trustee (Exhibit 4(a) to PPL Electric Utilities Corporation Form 8-K Report (File No. 1-905) dated May 11, 2017)
4(b)	-	Loan Agreement dated as of June 1, 2017 between Louisville Gas and Electric Company and the County of Trimble, Kentucky (Exhibit 4(a) to Louisville Gas and Electric Company Form 8-K Report (File No. 1-2893) dated June 1, 2017)
4(c)	-	Supplemental Indenture No. 6, dated as of May 15, 2017, of Louisville Gas and Electric Company to The Bank of New York Mellon, as Trustee (Exhibit 4(b) to Louisville Gas and Electric Company Form 8-K Report (File No. 1-2893) dated June 1, 2017)
*10(a)	-	Amendment No. 1, dated as of August 1, 2017, to Letter of Credit Agreement, dated as of October 1, 2014, among Kentucky Utilities Company, as the Borrower, the Lenders party thereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch, as Administrative Agent
[_]10(b)	-	PPL Corporation Amended and Restated 2012 Stock Incentive Plan (Annex B to Definitive Proxy Statement on Schedule 14A filed on April 5, 2017)
*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, 2017, 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, 2017, 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

107

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

108

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 3, 2017	/s/  Stephen K. Breininger
		Stephen K. Breininger Vice President and Controller
		(Principal Accounting Officer)
		PPL Electric Utilities Corporation
		(Registrant)
Date:	August 3, 2017	/s/  Marlene C. Beers
		Marlene C. Beers 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 3, 2017	/s/  Kent W. Blake
		Kent W. Blake Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

109

EX-10.A

Exhibit 10(a)

EXECUTION VERSION

AMENDMENT NO. 1 TO LETTER OF CREDIT AGREEMENT

AMENDMENT dated as of August 1, 2017 (this “Amendment”) to the Letter of Credit Agreement dated as of October 1, 2014 (as amended, amended and restated or otherwise modified prior to the date hereof, the “Existing Letter of Credit Agreement”; and as amended hereby, the “Amended Letter of Credit Agreement”) among KENTUCKY UTILITIES COMPANY (the “Borrower”), the LENDERS party thereto (the “Lenders”) and THE BANK OF TOKYO-MITSUBISHI UFJ, LTD., NEW YORK BRANCH (“BTMU”), as the Administrative Agent (the “Administrative Agent”) and as Issuing Lender and Lender.

W I T N E S S E T H :

WHEREAS, the parties hereto desire to amend the Existing Letter of Credit Agreement to (i) extend the scheduled Termination Date and (ii) make certain other amendments, all as provided herein.

NOW, THEREFORE, the parties hereto agree as follows:

SECTION 1.     Defined Terms; References. Unless otherwise specifically defined herein, each term used herein that is defined in the Amended Letter of Credit Agreement has the meaning assigned to such term in the Amended Letter of Credit Agreement. Each reference to “hereof”, “hereunder”, “herein” and “hereby” and each other similar reference and each reference to “this Agreement” and each other similar reference contained in the Existing Letter of Credit Agreement shall, after this Amendment becomes effective, refer to the Amended Letter of Credit Agreement.

SECTION 2.     Letter of Credit Agreement Amendments. With effect from and including the Amendment Effective Date (as defined below), and subject to the satisfaction of the conditions precedent set forth in Section 6 below, the Existing Letter of Credit Agreement is hereby amended as follows:

(a) Defined Terms.

(i) Section 1.01 of the Existing Letter of Credit Agreement is amended by amending the definitions of the terms listed below as follows:

(A) The definition of “FATCA” is amended by replacing the phrase “Section 1471(b) of the Code” with the following: “Section 1471(b) of the Internal Revenue Code”.

(B) The definition of “Lender Default” is amended by adding the following new clause (v) after clause (iv) and immediately preceding the proviso thereto:

“, or (v) the Lender becomes the subject of a Bail-In Action”

(ii) Section 1.01 of the Existing Letter of Credit Agreement is amended by replacing the definitions of the terms listed below in their entirety with the following:

“Defaulting Lender” means at any time any Lender with respect to which a Lender Default is in effect at such time, including any Lender subject to a Bail-In Action. Any determination by the Administrative Agent that a Lender is a Defaulting Lender under any one or more clauses of the definition of “Lender Default” shall be conclusive and binding absent manifest error, and such Lender shall be deemed to be a Defaulting Lender (subject to cure as expressly contemplated in the definition of “Lender Default”) upon delivery of written notice of such determination to the Borrower, the Issuing Lenders and each other Lender.

“Federal Funds Rate” means for any day the rate per annum (rounded upward, if necessary, to the nearest 1/100th of 1%) equal to the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System, as published by the Federal Reserve Bank of New York on the Business Day next succeeding such day; provided, that (i) if such day is not a Business Day, the Federal Funds Rate for such day shall be such rate on such transactions on the next preceding Business Day as so published on the next succeeding Business Day, and (ii) if no such rate is so published on such next succeeding Business Day, the Federal Funds Rate for such day shall be the average rate (rounded upward, if necessary, to the nearest 1/100th of 1%) charged by BTMU on such day on such transactions as determined by the Administrative Agent; provided, further, that if any such rate shall be less than zero, such rate shall be deemed to be zero for the purposes of this Agreement.

“Fee Letter” means, collectively, (i) the fee letter dated as of October 1, 2014, among the Borrower and BTMU and (ii) the Amendment No. 1 Fee Letter, in each case as amended, modified or supplemented from time to time.

“LIBOR Market Index Rate” means, for any day, the rate for 1 month U.S. dollar deposits as reported on Reuters Screen LIBOR01 (or any applicable successor page) as of 11:00 a.m., London time, for such day, provided, if such day is not a London Business Day, the immediately preceding London Business Day (or if not so reported, then as determined by the Administrative Agent from another recognized source or interbank quotation); provided, however, that if any such rate shall be less than zero, such rate shall be deemed to be zero for the purposes of this Agreement.

“Sanctioned Country” means a country, region or territory that is, or whose government is, the subject of comprehensive territorial Sanctions (currently, Crimea, Cuba, Iran, North Korea, Sudan, and Syria).

“Sanctions” means sanctions administered or enforced by OFAC, the U.S. State Department, the European Union, any European Union member state, Her Majesty’s Treasury of the United Kingdom or any other applicable sanctions authority.

“Termination Date” means the earlier to occur of (i) October 1, 2020, and (ii) such earlier date upon which all Commitments shall have been terminated in their entirety in accordance with this Agreement.

(iii) Section 1.01 of the Existing Letter of Credit Agreement is amended by inserting the following definitions in their correct alphabetical order:

“Amendment No. 1 Closing Date” means August 1, 2017.

“Amendment No. 1 Fee Letter” means that certain fee letter dated as of August 1, 2017 among the Borrower and BTMU.

“Bail-In Action” means the exercise of any Write-Down and Conversion Powers by the applicable EEA Resolution Authority in respect of any liability of an EEA Financial Institution.

“Bail-In Legislation” means, with respect to any EEA Member Country implementing Article 55 of Directive 2014/59/EU of the European Parliament and of the Council of the European Union, the implementing law for such EEA Member Country from time to time which is described in the EU Bail-In Legislation Schedule.

“Connection Income Taxes” means Other Connection Taxes that are imposed on or measured by net income (however denominated) or that are franchise or branch profits or similar taxes, duties, levies, impost, deductions, charges, and withholdings and all liabilities with respect thereto.

“EEA Financial Institution” means (a) any credit institution or investment firm established in any EEA Member Country which is subject to the supervision of an EEA Resolution Authority, (b) any entity established in an EEA Member Country which is a parent of an institution described in clause (a) of this definition, or (c) any financial institution established in an EEA Member Country which is a subsidiary of an institution described in clauses (a) or (b) of this definition and is subject to consolidated supervision with its parent.

“EEA Member Country” means any of the member states of the European Union, Iceland, Liechtenstein, and Norway.

“EEA Resolution Authority” means any public administrative authority or any person entrusted with public administrative authority of any EEA Member Country (including any delegee) having responsibility for the resolution of any EEA Financial Institution.

“EU Bail-In Legislation Schedule” means the EU Bail-In Legislation Schedule published by the Loan Market Association (or any successor Person), as in effect from time to time.

“Other Connection Taxes” means, with respect to the Administrative Agent or Lender, taxes, duties, levies, impost, deductions, charges, and withholdings and all liabilities with respect thereto imposed as a result of a present or former connection between such Person and the jurisdiction imposing such tax (other than connections arising from such Person having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced any Loan Document, or sold or assigned an interest in any Loan or Loan Document).

“Write-Down and Conversion Powers” means, with respect to any EEA Resolution Authority, the write-down and conversion powers of such EEA Resolution Authority from time to time under the Bail-In Legislation for the applicable EEA Member Country, which write-down and conversion powers are described in the EU Bail-In Legislation Schedule.

(b) Increased Costs; Taxes.

(i) Section 2.08(a)(ii) of the Existing Letter of Credit Agreement is amended and replaced in its entirety with the following: “(ii) subject any Lender or any Issuing Lender to any tax of any kind whatsoever with respect to this Agreement, any Letter of Credit, any participation in a Letter of Credit or any Loan made by it, or change the basis of taxation of payments to such Lender or such Issuing Lender in respect thereof (other than (A) Taxes, (B) Other Taxes, (C) the imposition of, or any change in the rate of, any taxes described in clause (i)(a) and clauses (ii) through (iv) of the

definition of Taxes in Section 2.09(a), (D) Connection Income Taxes, and (E) Taxes attributable to a Lender’s or an Issuing Lender’s failure to comply with Section 2.09(e)) or”.

(ii) Section 2.09(a)(i) of the Existing Letter of Credit Agreement is amended by:

(A) inserting “(x)” after “Lender” where it first appears therein;

(B) replacing “principal executive office” where it appears therein with “principal office”; and

(C) inserting “or (y) that are Other Connection Taxes” at the end thereof.

(iii) Section 2.09(e)(ii)(C) of the Existing Letter of Credit Agreement is amended by replacing “Code” where it first appears therein with “Internal Revenue Code”.

(iv) Section 2.09(e)(iii)(y) of the Existing Letter of Credit Agreement is amended by replacing “Code” where it appears therein with “Internal Revenue Code”.

(v) The first Section 2.09(e) of the Existing Letter of Credit Agreement is amended by inserting the following sentence immediately prior to the second to last sentence thereof:

“For purposes of determining withholding Taxes imposed under FATCA, the Borrower and the Administrative Agent shall treat (and the Lenders hereby authorize the Administrative Agent to treat) this Agreement and any Loan or Letter of Credit issued under or pursuant to this Agreement as not qualifying as a “grandfathered obligation” within the meaning of Treasury Regulation Section 1.1471-2(b)(2)(i) or Treasury Regulation Section 1.1471-2T(b)(2)(i).”

(vi) The second Section 2.09(e), Section 2.09(f) and Section 2.09(g) of the Existing Letter of Credit Agreement are renumbered as Section 2.09(f), Section 2.09(g) and Section 2.09(h), respectively.

(c) Representations and Warranties.

(i) Sections 5.04(a) and 5.04(c) of the Existing Letter of Credit Agreement are amended and restated by replacing “December 31, 2013” where it appears therein with “December 31, 2016”.

(ii) Section 5.04(b) is amended and replaced in its entirety with the following: “The unaudited consolidated balance sheet of the Borrower and its Consolidated Subsidiaries as of March 31, 2017 and the related unaudited consolidated statements of income and cash flows for the three months then ended fairly present, in conformity with GAAP applied on a basis consistent with the financial statements referred to in subsection (a) of this Section, the consolidated financial position of the Borrower and its Consolidated Subsidiaries as of such date and their consolidated results of operations and cash flows for such three-month period (subject to normal year-end audit adjustments).”

(iii) Section 5.08 of the Existing Letter of Credit Agreement is amended and restated by inserting “or the Amendment No. 1 Closing Date” after “Effective Date” where it appears therein.

(iv) Article V of the Existing Letter of Credit Agreement is amended to insert the following new Section 5.16 at the end thereof:

“Section 5.16 EEA Financial Institution. The Borrower is not an EEA Financial Institution.”

(d) Sanctions.

(i) Section 6.06 of the Existing Letter of Credit Agreement is amended by adding the following sentence at the end thereof:

“The proceeds of any Letter of Credit will not be used, directly or indirectly, to fund any activities or business of or with any Sanctioned Person, or in any Sanctioned Country.”

(e) Submission to Jurisdiction.

(i) Section 9.07 of the Existing Letter of Credit Agreement is amended and restated by inserting “, borough of Manhattan,” immediately after “New York City” where it appears therein.

(f) Acknowledgment and Consent to Bail-In of EEA Financial Institutions.

(i) Article IX of the Existing Letter of Credit Agreement is amended by inserting the following sections at the end thereof:

“Section 9.16. Acknowledgment and Consent to Bail-In of EEA Financial Institutions. Notwithstanding anything to the contrary in any Loan Document or in any other agreement, arrangement or understanding among any such parties, each party hereto acknowledges that any liability of any EEA Financial Institution arising under any Loan Document, to the extent such liability is unsecured, may be subject to the Write-Down and Conversion Powers of an EEA Resolution Authority and agrees and consents to, and acknowledges and agrees to be bound by:

(a) the application of any Write-Down and Conversion Powers by an EEA Resolution Authority to any such liabilities arising hereunder which may be payable to it by any party hereto that is an EEA Financial Institution; and

(b) the effects of any Bail-In Action on any such liability, including, if applicable:

(i) a reduction in full or in part or cancellation of any such liability;

(ii) a conversion of all, or a portion of, such liability into shares or other instruments of ownership in such EEA Financial Institution, its parent undertaking, or a bridge institution that may be issued to it or otherwise conferred on it, and that such shares or other instruments of ownership will be accepted by it in lieu of any rights with respect

to any such liability under this Agreement or any other Loan Document; or

(iii) the variation of the terms of such liability in connection with the exercise of the Write-Down and Conversion Powers of any EEA Resolution Authority.”

(g) Miscellaneous. Article IX of the Existing Letter of Credit Agreement is amended by inserting the following sections at the end thereof:

“Section 9.17. Interest Rate Limitation. Notwithstanding anything herein to the contrary, if at any time the interest rate applicable to any Loan, together with all fees, charges and other amounts which are treated as interest on such Loan under applicable law (collectively the “Charges”), shall exceed the maximum lawful rate (the “Maximum Rate”) which may be contracted for, charged, taken, received or reserved by the Lender holding such Loan in accordance with applicable law, the rate of interest payable in respect of such Loan hereunder, together with all Charges payable in respect thereof, shall be limited to the Maximum Rate and, to the extent lawful, the interest and Charges that would have been payable in respect of such Loan but were not payable as a result of the operation of this Section shall be cumulated and the interest and Charges payable to such Lender in respect of other Loans or periods shall be increased (but not above the Maximum Rate therefor) until such cumulated amount, together with interest thereon at the Federal Funds Rate to the date of repayment, shall have been received by such Lender.”

“Section 9.18. Severability. Any provision of any Loan Document held to be invalid, illegal or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the extent of such invalidity, illegality or unenforceability without affecting the validity, legality and enforceability of the remaining provisions thereof; and the invalidity of a particular provision in a particular jurisdiction shall not invalidate such provision in any other jurisdiction.”

“Section 9.19. Headings. Article and Section headings and the Table of Contents used herein are for convenience of reference only, are not part of this Agreement and shall not affect the construction of, or be taken into consideration in interpreting, this Agreement.”

SECTION 3. Full Force and Effect; Ratification. Except as expressly modified herein, all of the terms and conditions of the Existing Letter of Credit Agreement are unchanged, and, as modified hereby, the Borrower confirms and ratifies all of the terms, covenants and conditions of the Existing Letter of Credit Agreement. This Amendment constitutes the entire and final agreement among the parties hereto with respect to the subject matter hereof and there are no other agreements, understandings, undertakings, representations or warranties among the parties hereto with respect to the subject matter hereof except as set forth herein.

SECTION 4. GOVERNING LAW. THIS AMENDMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK.

SECTION 5. Counterparts. This Amendment may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were

upon the same instrument. Delivery of an executed counterpart of a signature page to this Amendment by facsimile or email shall be effective as delivery of a manually executed counterpart of this Amendment. The words “execution,” “signed,” “signature,” “delivery,” and words of like import in or relating to any document to be signed in connection with this Amendment and the transactions contemplated hereby shall be deemed to include electronic signatures, deliveries or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature, physical delivery thereof or the use of a paper-based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act.

SECTION 6. Effectiveness. This Amendment shall become effective as of the first date when each of the following conditions are met (the “Amendment Effective Date”):

(a) the Administrative Agent shall have received from the Borrower, the Issuing Lenders and the Lenders a counterpart hereof signed by such party or facsimile or other written confirmation (in form satisfactory to the Administrative Agent) that such party has signed a counterpart hereof;

(b) the Administrative Agent shall have received satisfactory opinions of counsel for the Borrower, dated the Amendment Effective Date;

(c) the Administrative Agent shall have received a certificate dated the Amendment Effective Date signed on behalf of the Borrower by the Chairman of the Board, the President, any Vice President, the Treasurer or any Assistant Treasurer of the Borrower stating that (i) on the Amendment Effective Date, before and after giving effect to this Amendment, no Default shall have occurred or be continuing, (ii) the representations and warranties contained in the Amended Letter of Credit Agreement are true and correct on and as of the Amendment Effective Date, except to the extent that such representations and warranties specifically refer to an earlier date, in which case they were true and correct as of such earlier date and (iii) no authorization, consent or approval from any Governmental Authority is required for the execution, delivery and performance by the Borrower of this Amendment, the Amended Letter of Credit Agreement and the other Loan Documents to which it is a party except such authorizations, consents and approvals, including, without limitation, the KPSC Order, TRA Order and VSCC Order, as shall have been obtained prior to the Amendment Effective Date and shall be in full force and effect; provided that the Borrower may require additional approvals of the KPSC, TRA, VSCC and/or FERC in order to incur obligations in respect of the Letters of Credit to support issuances of bonds other than the Existing Pollution Control Bonds;

(d) the Administrative Agent shall have received (i) a certificate of the Secretary of State of the Commonwealth of Kentucky and a certificate of the Secretary of the Commonwealth of the Commonwealth of Virginia, each dated as of a recent date, as to the good standing of the Borrower and (ii) a certificate of the Secretary or an Assistant Secretary of the Borrower dated the Amendment Effective Date and certifying (A) that attached thereto is a true, correct and complete copies of (x) the Borrower’s articles of incorporation certified by the Secretary of State of the Commonwealth of Kentucky and

the Secretary of the Commonwealth of the Commonwealth of Virginia and (y) the bylaws of the Borrower, (B) as to the absence of dissolution or liquidation proceedings by or against the Borrower, (C) that attached thereto is a true, correct and complete copy of resolutions adopted by the board of directors of the Borrower authorizing the execution, delivery and performance of this Amendment and each other document delivered in connection herewith and that such resolutions have not been amended and are in full force and effect on the date of such certificate and (D) as to the incumbency and specimen signatures of each officer of the Borrower executing this Amendment or any other document delivered in connection herewith;

(e) all necessary governmental (domestic or foreign), regulatory and third party approvals, including, without limitation, the orders of the KPSC, TRA, VSCC and any required approvals of the FERC, authorizing the Borrower to incur liabilities pursuant to the Amended Letter of Credit Agreement and the other Loan Documents in connection with the transactions contemplated by this Amendment and the other Loan Documents shall have been obtained and remain in full force and effect, in each case without any action being taken by any competent authority which could restrain or prevent such transaction or impose, in the reasonable judgment of the Administrative Agent, materially adverse conditions upon the consummation of such transactions; and

(f) the Administrative Agent shall have received all costs, fees and expenses due to the Administrative Agent, the Issuing Lenders and the other Lenders.

SECTION 7. Representations and Warranties and Reaffirmations of the Borrower.

(a) The Borrower hereby represents and warrants that (i) this Amendment and the Existing Letter of Credit Agreement as previously executed and as modified hereby constitute legal, valid and binding obligations of the Borrower enforceable against the Borrower in accordance with their terms except to the extent limited by (x) bankruptcy, insolvency, fraudulent conveyance or reorganization laws or by other similar laws relating to or affecting the enforceability of creditors’ rights generally and by general equitable principles which may limit the right to obtain equitable remedies regardless of whether enforcement is considered in a proceeding of law or equity or (y) any applicable public policy on enforceability of provisions relating to contribution and indemnification, and (ii) no Default or Event of Default has occurred and is continuing.

(b) Upon the effectiveness of this Amendment and after giving effect hereto, the Borrower hereby reaffirms all covenants, representations and warranties made in the Amended Letter of Credit Agreement, and agrees that all such covenants, representations and warranties shall be deemed to have been remade as of the Amendment Effective Date, except that any such covenant, representation, or warranty that was made as of a specific date shall be considered reaffirmed only as of such date.

SECTION 8. Reference to the Effect on the Existing Letter of Credit Agreement.

(a) Upon the effectiveness of Section 2 hereof, on and after the date hereof, each reference in the Existing Letter of Credit Agreement (including any reference therein to “this Letter of Credit Agreement,” “this Agreement,” “hereunder,” “hereof,” “herein” or words of

like import referring thereto) or in any other Loan Document shall mean and be a reference to the Amended Letter of Credit Agreement.

(b) Upon satisfaction of the conditions set forth in Section 6 hereof and the execution hereof by the Borrower, the Issuing Lender, the Lenders and the Administrative Agent, this Amendment shall be binding upon all parties to the Exiting Letter of Credit Agreement.

SECTION 9. Miscellaneous. This Amendment shall constitute a Loan Document for all purposes of the Amended Letter of Credit Agreement and the other Loan Documents. The provisions of this Amendment are deemed incorporated into the Amended Letter of Credit Agreement as if fully set forth therein. The Borrower shall pay all reasonable out-of-pocket costs and expenses of the Administrative Agent incurred in connection with the negotiation, preparation and execution of this Amendment and the transactions contemplated hereby. The execution, delivery and effectiveness of this Amendment shall not, except as expressly provided herein, operate as a waiver of any right, power or remedy of any Lender or the Administrative Agent under any of the Loan Documents, nor constitute a waiver of any provision of any of the Loan Documents.

[Signature Pages to Follow]

IN WITNESS WHEREOF, this Amendment has been duly executed as of the day and year first above written.

KENTUCKY UTILITIES COMPANY,
as the Borrower

By:           /s/ Daniel K. Arbough

Name:          Daniel K. Arbough

Title:            Treasurer

Signature Page to Amendment No. 1 to Letter of Credit Agreement

Kentucky Utilities Company (2017)

THE BANK OF TOKYO-MITSUBISHI UFJ, LTD., NEW YORK BRANCH, as Administrative Agent, Issuing Lender and Lender
By:	/s/ Chi-Cheng Chen
Name:		Chi-Cheng Chen
Title:		Director

Signature Page to Amendment No. 1 to Letter of Credit Agreement

Kentucky Utilities Company (2017)

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,
	2017		2016			2015 (a)			2014 (a)		2013 (a)		2012 (a)
Earnings, as defined:
Income from Continuing Operations Before Income Taxes	$	900	$	2,550		$	2,068		$	2,129	$	1,728	$	1,406
Adjustment to reflect earnings from equity method investments on a cash basis (b)	1		(1		)	(1		)	—		—		34
	901		2,549			2,067			2,129		1,728		1,440
Total fixed charges as below	449		917			1,054			1,095		1,096		1,065
Less:
Capitalized interest	2		4			11			11		11		6
Preferred security distributions of subsidiaries on a pre-tax basis	—		—			—			—		—		5
Interest expense and fixed charges related to discontinued operations	—		—			150			186		235		235
Total fixed charges included in Income from Continuing Operations Before Income Taxes	447		913			893			898		850		819
Total earnings	$	1,348	$	3,462		$	2,960		$	3,027	$	2,578	$	2,259
Fixed charges, as defined:
Interest charges (c)	$	444	$	900		$	1,038		$	1,073	$	1,058	$	1,019
Estimated interest component of operating rentals	5		17			16			22		38		41
Preferred security distributions of subsidiaries on a pre-tax basis	—		—			—			—		—		5
Total fixed charges (d)	$	449	$	917		$	1,054		$	1,095	$	1,096	$	1,065
Ratio of earnings to fixed charges	3.0		3.8			2.8			2.8		2.4		2.1
Ratio of earnings to combined fixed charges and preferred stock dividends (e)	3.0		3.8			2.8			2.8		2.4		2.1

(a)	Reflects PPL's former Supply segment as Discontinued Operations.
(b)	Includes other-than-temporary impairment loss of $25 million in 2012.
(c)	Includes interest on long-term and short-term debt, as well as amortization of debt discount, expense and premium - net.
(d)	Interest on unrecognized tax benefits is not included in fixed charges.
(e)	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,
	2017		2016		2015		2014		2013		2012
Earnings, as defined:
Income Before Income Taxes	$	251	$	552	$	416	$	423	$	317	$	204
Total fixed charges as below	74		141		139		131		117		107
Total earnings	$	325	$	693	$	555	$	554	$	434	$	311
Fixed charges, as defined:
Interest charges (a)	$	72	$	137	$	135	$	127	$	113	$	104
Estimated interest component of operating rentals	2		4		4		4		4		3
Total fixed charges (b)	$	74	$	141	$	139	$	131	$	117	$	107
Ratio of earnings to fixed charges	4.4		4.9		4.0		4.2		3.7		2.9
Preferred stock dividend requirements on a pre-tax basis	$	—	$	—	$	—	$	—	$	—	$	6
Fixed charges, as above	74		141		139		131		117		107
Total fixed charges and preferred stock dividends	$	74	$	141	$	139	$	131	$	117	$	113
Ratio of earnings to combined fixed charges and preferred stock dividends	4.4		4.9		4.0		4.2		3.7		2.8

(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.

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,
	2017		2016			2015			2014			2013			2012
Earnings, as defined:
Income from Continuing Operations Before Income Taxes	$	306	$	686		$	603		$	553		$	551		$	331
Adjustment to reflect earnings from equity method investments on a cash basis (a)	1		(1		)	(1		)	(1		)	(1		)	33
	307		685			602			552			550			364
Total fixed charges as below	112		223			189			173			151			157
Total earnings	$	419	$	908		$	791		$	725		$	701		$	521
Fixed charges, as defined:
Interest charges (b) (c)	$	107	$	214		$	181		$	167		$	145		$	151
Estimated interest component of operating rentals	5		9			8			6			6			6
Total fixed charges	$	112	$	223		$	189		$	173		$	151		$	157
Ratio of earnings to fixed charges	3.7		4.1			4.2			4.2			4.6			3.3

(a)	Includes other-than-temporary impairment loss of $25 million in 2012.
(b)	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.
(c)	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,
	2017		2016		2015		2014		2013		2012
Earnings, as defined:
Income Before Income Taxes	$	156	$	329	$	299	$	272	$	257	$	192
Total fixed charges as below	38		76		61		51		36		44
Total earnings	$	194	$	405	$	360	$	323	$	293	$	236
Fixed charges, as defined:
Interest charges (a) (b)	$	36	$	71	$	57	$	49	$	34	$	42
Estimated interest component of operating rentals	2		5		4		2		2		2
Total fixed charges	$	38	$	76	$	61	$	51	$	36	$	44
Ratio of earnings to fixed charges	5.1		5.3		5.9		6.3		8.1		5.4

(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,
	2017		2016			2015			2014			2013			2012
Earnings, as defined:
Income Before Income Taxes	$	192	$	428		$	374		$	355		$	360		$	215
Adjustment to reflect earnings from equity method investments on a cash basis (a)	1		(1		)	(1		)	(1		)	(1		)	33
	193		427			373			354			359			248
Total fixed charges as below	50		100			86			80			73			72
Total earnings	$	243	$	527		$	459		$	434		$	432		$	320
Fixed charges, as defined:
Interest charges (b)	$	48	$	96		$	82		$	77		$	70		$	69
Estimated interest component of operating rentals	2		4			4			3			3			3
Total fixed charges	$	50	$	100		$	86		$	80		$	73		$	72
Ratio of earnings to fixed charges	4.9		5.3			5.3			5.4			5.9			4.4

(a)	Includes other-than-temporary impairment loss of $25 million in 2012.
(b)	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 3, 2017	/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 3, 2017	/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 3, 2017	/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 3, 2017	/s/  Marlene C. Beers
		Marlene C. Beers
		Controller
		(Principal Financial Officer)
		PPL Electric Utilities Corporation

EX-31.E

Exhibit 31(e)

CERTIFICATION

I, VICTOR A. STAFFIERI, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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 3, 2017	/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, VICTOR A. STAFFIERI, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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 3, 2017	/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, VICTOR A. STAFFIERI, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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 3, 2017	/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, 2017

In connection with the quarterly report on Form 10-Q of PPL Corporation (the "Company") for the quarter ended June 30, 2017, 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 3, 2017	/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, 2017

In connection with the quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "Company") for the quarter ended June 30, 2017, 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 3, 2017	/s/  Gregory N. Dudkin
		Gregory N. Dudkin
		President
		(Principal Executive Officer)
		PPL Electric Utilities Corporation
		/s/  Marlene C. Beers
		Marlene C. Beers
		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, 2017

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, 2017, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Victor A. Staffieri, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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, 2017

In connection with the quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "Company") for the quarter ended June 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Victor A. Staffieri, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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, 2017

In connection with the quarterly report on Form 10-Q of Kentucky Utilities Company (the "Company") for the quarter ended June 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Victor A. Staffieri, 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 3, 2017	/s/  Victor A. Staffieri
		Victor A. Staffieri
		Chairman of the Board and Chief Executive Officer
		(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, 2017	Jul. 27, 2017
Document Entity Information [Line Items]
Document Type	10-Q
Document Period End Date	Jun. 30, 2017
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		685,855,683
Document Fiscal Year Focus	2017
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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Operating Revenues
Operating Revenues		$ 1,725	$ 1,785	$ 3,676	$ 3,796
Operation
Fuel		183	183	374	380
Energy purchases		136	147	351	380
Other operation and maintenance		388	425	820	875
Depreciation		246	231	488	460
Taxes, other than income		70	74	145	153
Total Operating Expenses		1,023	1,060	2,178	2,248
Operating Income		702	725	1,498	1,548
Other Income (Expense) - net		(112)	174	(159)	235
Interest Expense		222	224	439	448
Income Before Income Taxes		368	675	900	1,335
Income Taxes		76	192	205	371
Net Income		$ 292	$ 483	$ 695	$ 964
Net Income:
Basic (in dollars per share)		$ 0.43	$ 0.71	$ 1.02	$ 1.42
Diluted (in dollars per share)		0.43	0.71	1.01	1.41
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.3950	$ 0.38	$ 0.79	$ 0.76
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		683,841	677,145	682,370	676,293
Diluted (in shares)		686,351	680,729	684,725	679,773
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 500	$ 495	$ 1,073	$ 1,080
Operation
Energy purchases		107	118	253	285
Other operation and maintenance		138	137	302	287
Depreciation		76	62	151	121
Taxes, other than income		23	24	52	53
Total Operating Expenses		344	341	758	746
Operating Income		156	154	315	334
Other Income (Expense) - net		3	5	4	8
Interest Income from Affiliate		1	0	1	0
Interest Expense		36	32	69	65
Income Before Income Taxes		124	127	251	277
Income Taxes		47	48	95	104
Net Income	[1]	77	79	156	173
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		723	721	1,532	1,547
Operation
Fuel		183	182	374	380
Energy purchases		29	28	98	94
Other operation and maintenance		192	204	399	406
Depreciation		105	100	210	199
Taxes, other than income		16	15	32	30
Total Operating Expenses		525	529	1,113	1,109
Operating Income		198	192	419	438
Other Income (Expense) - net		(4)	(5)	(6)	(6)
Interest Expense		50	48	99	97
Interest Expense with Affiliate		4	4	8	8
Income Before Income Taxes		140	135	306	327
Income Taxes		53	51	116	123
Net Income		87	84	190	204
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		320	317	694	692
Electric revenue from affiliate		4	6	21	17
Operating Revenues		324	323	715	709
Operation
Fuel		69	69	149	147
Energy purchases		25	23	89	85
Energy purchases from affiliate		3	3	5	5
Other operation and maintenance		86	92	173	179
Depreciation		45	42	89	83
Taxes, other than income		9	7	17	15
Total Operating Expenses		237	236	522	514
Operating Income		87	87	193	195
Other Income (Expense) - net		1	(5)	(1)	(5)
Interest Expense		19	18	36	35
Income Before Income Taxes		69	64	156	155
Income Taxes		27	24	60	59
Net Income	[1]	42	40	96	96
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		403	404	838	855
Electric revenue from affiliate		3	3	5	5
Operating Revenues		406	407	843	860
Operation
Fuel		114	113	225	233
Energy purchases		4	5	9	9
Energy purchases from affiliate		4	6	21	17
Other operation and maintenance		100	107	209	213
Depreciation		61	58	121	116
Taxes, other than income		7	8	15	15
Total Operating Expenses		290	297	600	603
Operating Income		116	110	243	257
Other Income (Expense) - net		(2)	1	(3)	(1)
Interest Expense		24	23	48	47
Income Before Income Taxes		90	88	192	209
Income Taxes		34	34	73	80
Net Income	[2]	$ 56	$ 54	$ 119	$ 129

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Net Income	$ 292	$ 483	$ 695	$ 964
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	231	268	207	(196)
Qualifying derivatives, net of tax	(24)	(85)	(30)	(5)
Defined benefit plans:
Net actuarial gain (loss), net of tax	(11)	2	(11)	2
Reclassifications from accumulated other comprehensive income (loss) - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	25	85	24	7
Equity investees' other comprehensive (income) loss, net of tax	1	(1)	1	(1)
Defined benefit plans:
Prior service costs, net of tax	1	1	1	1
Net actuarial (gain) loss, net of tax	31	32	63	63
Total other comprehensive income (loss)	254	302	255	(129)
Comprehensive income	546	785	950	835
LG And E And KU Energy LLC [Member]
Net Income	87	84	190	204
Defined benefit plans:
Net actuarial gain (loss), net of tax	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income (loss) - (gains) losses, net of tax expense (benefit):
Equity investees' other comprehensive (income) loss, net of tax	0	(1)	1	(1)
Defined benefit plans:
Prior service costs, net of tax	1	1	1	1
Net actuarial (gain) loss, net of tax	1	1	2	2
Total other comprehensive income (loss)	(9)	2	(7)	3
Comprehensive income	$ 78	$ 86	$ 183	$ 207

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ 0	$ (1)	$ (2)
Tax effect of qualifying derivatives arising during the period	5	22	7	7
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	7	(1)	7	(1)
Tax effect of qualifying derivatives reclassified from accumulated other comprehensive income (loss)	(7)	(21)	(7)	(2)
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)	(8)	(18)	(17)
LG And E And KU Energy LLC [Member]
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	7	(1)	7	(1)
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)	$ (1)	$ (1)	$ (2)	$ (1)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016
Cash Flows from Operating Activities
Net Income		$ 695	$ 964
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		488	460
Amortization		45	37
Defined benefit plans - expense (income)		(45)	(24)
Deferred income taxes and investment tax credits		201	320
Unrealized (gains) losses on derivatives, and other hedging activities		135	(192)
Stock-based compensation expense		22	18
Other		(5)	(11)
Change in current assets and current liabilities
Accounts receivable		26	16
Accounts payable		(92)	(39)
Unbilled revenues		70	(2)
Fuel, materials and supplies		42	21
Prepayments		(66)	(66)
Counterparty collateral		8	76
Taxes payable		(27)	22
Accrued interest		(77)	(85)
Other current liabilities		(52)	(47)
Other		(14)	(21)
Other operating activities
Defined benefit plans - funding		(552)	(224)
Other assets		(1)	2
Other liabilities		(11)	(55)
Net cash provided by operating activities		790	1,170
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,373)	(1,346)
Expenditures for intangible assets		(15)	(14)
Other investing activities		6	13
Net cash used in investing activities		(1,382)	(1,347)
Cash Flows from Financing Activities
Issuance of long-term debt		594	1,020
Retirement of long-term debt		(60)	(684)
Settlement of cross-currency swaps		0	46
Issuance of common stock		177	76
Payment of common stock dividends		(529)	(513)
Net increase (decrease) in short-term debt		554	(66)
Other financing activities		(25)	(31)
Net cash provided by (used in) financing activities		711	(152)
Effect of Exchange Rates on Cash and Cash Equivalents		7	(15)
Net Increase (Decrease) in Cash and Cash Equivalents		126	(344)
Cash and Cash Equivalents at Beginning of Period		341	836
Cash and Cash Equivalents at End of Period		467	492
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		284	283
Accrued expenditures for intangible assets at June 30,		56	94
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net Income	[1]	156	173
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		151	121
Amortization		15	15
Defined benefit plans - expense (income)		7	7
Deferred income taxes and investment tax credits		84	107
Other		(4)	(10)
Change in current assets and current liabilities
Accounts receivable		13	(6)
Accounts payable		(59)	(26)
Unbilled revenues		17	3
Prepayments		(52)	3
Regulatory assets and liabilities		(12)	(40)
Taxes payable		(4)	(16)
Other		(6)	(6)
Other operating activities
Defined benefit plans - funding		(24)	0
Other assets		(4)	11
Other liabilities		1	(8)
Net cash provided by operating activities		279	328
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(550)	(424)
Expenditures for intangible assets		(5)	(2)
Net increase in notes receivable from affiliate		(270)	0
Other investing activities		1	(1)
Net cash used in investing activities		(824)	(427)
Cash Flows from Financing Activities
Issuance of long-term debt		470	224
Retirement of long-term debt		0	(224)
Contributions from parent		575	200
Payment of common stock dividends to parent		(154)	(117)
Net increase (decrease) in short-term debt		(295)	6
Other financing activities		(5)	(2)
Net cash provided by (used in) financing activities		591	87
Net Increase (Decrease) in Cash and Cash Equivalents		46	(12)
Cash and Cash Equivalents at Beginning of Period		13	47
Cash and Cash Equivalents at End of Period		59	35
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		157	130
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net Income		190	204
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		210	199
Amortization		14	15
Defined benefit plans - expense (income)		12	13
Deferred income taxes and investment tax credits		91	121
Other		0	(1)
Change in current assets and current liabilities
Accounts receivable		13	9
Accounts payable		(28)	28
Unbilled revenues		23	(14)
Fuel, materials and supplies		41	20
Taxes payable		3	(13)
Other		(21)	(23)
Other operating activities
Defined benefit plans - funding		(29)	(45)
Expenditures for asset retirement obligations		(12)	(8)
Other assets		(2)	1
Other liabilities		6	0
Net cash provided by operating activities		511	506
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(355)	(439)
Net cash used in investing activities		(355)	(439)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate		(4)	123
Issuance of long-term debt		60	0
Retirement of long-term debt		(60)	0
Debt issuance and credit facility costs		(1)	(1)
Net increase (decrease) in short-term debt		73	(126)
Distributions to member		(218)	(114)
Contributions from member		0	37
Net cash provided by (used in) financing activities		(150)	(81)
Net Increase (Decrease) in Cash and Cash Equivalents		6	(14)
Cash and Cash Equivalents at Beginning of Period		13	30
Cash and Cash Equivalents at End of Period		19	16
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		83	105
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net Income	[1]	96	96
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		89	83
Amortization		7	6
Defined benefit plans - expense (income)		3	4
Deferred income taxes and investment tax credits		57	62
Change in current assets and current liabilities
Accounts receivable		9	2
Accounts receivable from affiliates		11	(7)
Accounts payable		(17)	20
Accounts payable to affiliates		(3)	8
Unbilled revenues		14	(1)
Fuel, materials and supplies		33	29
Taxes payable		(23)	0
Other		(3)	(6)
Other operating activities
Defined benefit plans - funding		(3)	(16)
Expenditures for asset retirement obligations		(7)	(6)
Other assets		0	(4)
Other liabilities		1	3
Net cash provided by operating activities		264	273
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(177)	(237)
Net cash used in investing activities		(177)	(237)
Cash Flows from Financing Activities
Issuance of long-term debt		60	0
Retirement of long-term debt		(60)	0
Contributions from parent		0	47
Debt issuance and credit facility costs		(1)	(1)
Payment of common stock dividends to parent		(122)	(61)
Net increase (decrease) in short-term debt		38	(32)
Net cash provided by (used in) financing activities		(85)	(47)
Net Increase (Decrease) in Cash and Cash Equivalents		2	(11)
Cash and Cash Equivalents at Beginning of Period		5	19
Cash and Cash Equivalents at End of Period		7	8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		40	69
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net Income	[2]	119	129
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		121	116
Amortization		6	7
Defined benefit plans - expense (income)		2	3
Deferred income taxes and investment tax credits		70	77
Other		0	(1)
Change in current assets and current liabilities
Accounts receivable		5	11
Accounts receivable from affiliates		0	1
Accounts payable		(1)	11
Accounts payable to affiliates		(15)	12
Unbilled revenues		9	(13)
Fuel, materials and supplies		8	(9)
Taxes payable		(29)	(3)
Other		(13)	(11)
Other operating activities
Defined benefit plans - funding		(21)	(13)
Expenditures for asset retirement obligations		(5)	(2)
Other assets		(3)	(3)
Other liabilities		4	(1)
Net cash provided by operating activities		257	311
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(177)	(201)
Net cash used in investing activities		(177)	(201)
Cash Flows from Financing Activities
Contributions from parent		0	20
Debt issuance and credit facility costs		0	(1)
Payment of common stock dividends to parent		(110)	(113)
Net increase (decrease) in short-term debt		35	(19)
Net cash provided by (used in) financing activities		(75)	(113)
Net Increase (Decrease) in Cash and Cash Equivalents		5	(3)
Cash and Cash Equivalents at Beginning of Period		7	11
Cash and Cash Equivalents at End of Period		12	8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at June 30,		$ 43	$ 36

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Jun. 30, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents		$ 467	$ 341
Accounts receivable (less reserve:)
Customer		628	666
Other		85	46
Unbilled revenues		416	480
Fuel, materials and supplies		316	356
Prepayments		131	63
Price risk management assets		69	63
Regulatory assets		37	39
Other current assets		54	52
Total Current Assets		2,166	2,067
Property, Plant and Equipment
Regulated utility plant		36,173	34,674
Less: accumulated depreciation - regulated utility plant		6,446	6,013
Regulated utility plant, net		29,727	28,661
Non-regulated property, plant and equipment		424	413
Less: accumulated depreciation - non-regulated property, plant and equipment		147	134
Non-regulated property, plant and equipment, net		277	279
Construction work in progress		1,229	1,134
Property, Plant and Equipment, net		31,233	30,074
Other Noncurrent Assets
Regulatory assets		1,906	1,918
Goodwill		3,139	3,060
Other intangibles		656	700
Pension benefit asset		467	9
Price risk management assets		245	336
Other noncurrent assets		152	151
Total Other Noncurrent Assets		6,565	6,174
Total Assets		39,964	38,315
Current Liabilities
Short-term debt		1,497	923
Long-term debt due within one year		671	518
Accounts payable		752	820
Taxes		77	101
Interest		196	270
Dividends		271	259
Customer deposits		289	276
Regulatory liabilities		71	101
Other current liabilities		526	569
Total Current Liabilities		4,350	3,837
Long-term Debt
Long-term Debt		18,397	17,808
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		4,130	3,889
Investment tax credits		131	132
Accrued pension obligations		787	1,001
Asset retirement obligations		343	428
Regulatory liabilities		902	899
Other deferred credits and noncurrent liabilities		434	422
Total Deferred Credits and Other Noncurrent Liabilities		6,727	6,771
Commitments and Contingent Liabilities
Equity
Common stock	[1]	7	7
Additional paid-in capital		10,023	9,841
Earnings reinvested		3,983	3,829
Accumulated other comprehensive loss		(3,523)	(3,778)
Total Equity		10,490	9,899
Total Liabilities and Equity		39,964	38,315
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents		59	13
Accounts receivable (less reserve:)
Customer		267	272
Other		12	21
Accounts receivable from affiliates		1	0
Notes receivable from affiliate		270	0
Unbilled revenues		97	114
Fuel, materials and supplies		29	32
Prepayments		61	9
Regulatory assets		14	19
Other current assets		6	8
Total Current Assets		816	488
Property, Plant and Equipment
Regulated utility plant		10,235	9,654
Less: accumulated depreciation - regulated utility plant		2,814	2,714
Regulated utility plant, net		7,421	6,940
Construction work in progress		593	641
Property, Plant and Equipment, net		8,014	7,581
Other Noncurrent Assets
Regulatory assets		1,076	1,094
Other intangibles		254	251
Other noncurrent assets		15	12
Total Other Noncurrent Assets		1,345	1,357
Total Assets		10,175	9,426
Current Liabilities
Short-term debt		0	295
Long-term debt due within one year		224	224
Accounts payable		353	367
Accounts payable to affiliates		29	42
Taxes		8	12
Interest		37	34
Regulatory liabilities		57	83
Other current liabilities		88	101
Total Current Liabilities		796	1,158
Long-term Debt
Long-term Debt		3,074	2,607
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,990	1,899
Accrued pension obligations		257	281
Regulatory liabilities		0	0
Other deferred credits and noncurrent liabilities		90	90
Total Deferred Credits and Other Noncurrent Liabilities		2,337	2,270
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		2,729	2,154
Earnings reinvested		875	873
Total Equity		3,968	3,391
Total Liabilities and Equity		10,175	9,426
LG And E And KU Energy LLC [Member]
Assets
Cash and cash equivalents		19	13
Accounts receivable (less reserve:)
Customer		221	235
Other		40	17
Unbilled revenues		147	170
Fuel, materials and supplies		257	297
Prepayments		32	24
Regulatory assets		23	20
Other current assets		9	4
Total Current Assets		748	780
Property, Plant and Equipment
Regulated utility plant		12,852	12,746
Less: accumulated depreciation - regulated utility plant		1,630	1,465
Regulated utility plant, net		11,222	11,281
Construction work in progress		411	317
Property, Plant and Equipment, net		11,633	11,598
Other Noncurrent Assets
Regulatory assets		830	824
Goodwill		996	996
Other intangibles		90	95
Other noncurrent assets		80	78
Total Other Noncurrent Assets		1,996	1,993
Total Assets		14,377	14,371
Current Liabilities
Short-term debt		258	185
Long-term debt due within one year		98	194
Notes payable with affiliate		159	163
Accounts payable		225	251
Accounts payable to affiliates		6	6
Taxes		42	39
Price risk management liabilities		5	4
Interest		31	32
Customer deposits		57	56
Regulatory liabilities		14	18
Asset retirement obligations		73	60
Other current liabilities		115	119
Total Current Liabilities		1,083	1,127
Long-term Debt
Long-term debt		4,569	4,471
Long-term debt to affiliate		400	400
Long-term Debt		4,969	4,871
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,823	1,735
Investment tax credits		131	132
Accrued pension obligations		344	350
Asset retirement obligations		292	373
Regulatory liabilities		902	899
Price risk management liabilities		25	27
Other deferred credits and noncurrent liabilities		176	190
Total Deferred Credits and Other Noncurrent Liabilities		3,693	3,706
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(77)	(70)
Member's Equity		4,632	4,667
Total Liabilities and Equity		14,377	14,371
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents		7	5
Accounts receivable (less reserve:)
Customer		101	109
Other		11	11
Accounts receivable from affiliates		17	28
Unbilled revenues		61	75
Fuel, materials and supplies		110	143
Prepayments		15	12
Regulatory assets		11	9
Other current assets		3	1
Total Current Assets		336	393
Property, Plant and Equipment
Regulated utility plant		5,440	5,357
Less: accumulated depreciation - regulated utility plant		566	498
Regulated utility plant, net		4,874	4,859
Construction work in progress		174	133
Property, Plant and Equipment, net		5,048	4,992
Other Noncurrent Assets
Regulatory assets		449	450
Goodwill		389	389
Other intangibles		55	59
Other noncurrent assets		17	17
Total Other Noncurrent Assets		910	915
Total Assets		6,294	6,300
Current Liabilities
Short-term debt		207	169
Long-term debt due within one year		98	194
Accounts payable		116	148
Accounts payable to affiliates		23	26
Taxes		17	40
Price risk management liabilities		5	4
Interest		10	11
Customer deposits		27	27
Regulatory liabilities		4	5
Asset retirement obligations		29	41
Other current liabilities		40	36
Total Current Liabilities		576	701
Long-term Debt
Long-term Debt		1,521	1,423
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,033	974
Investment tax credits		36	36
Accrued pension obligations		49	53
Asset retirement obligations		103	104
Regulatory liabilities		418	419
Price risk management liabilities		25	27
Other deferred credits and noncurrent liabilities		83	87
Total Deferred Credits and Other Noncurrent Liabilities		1,747	1,700
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,682	1,682
Earnings reinvested		344	370
Total Equity		2,450	2,476
Total Liabilities and Equity		6,294	6,300
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents		12	7
Accounts receivable (less reserve:)
Customer		120	126
Other		27	5
Unbilled revenues		86	95
Fuel, materials and supplies		147	154
Prepayments		15	12
Regulatory assets		12	11
Other current assets		6	3
Total Current Assets		425	413
Property, Plant and Equipment
Regulated utility plant		7,404	7,382
Less: accumulated depreciation - regulated utility plant		1,062	965
Regulated utility plant, net		6,342	6,417
Construction work in progress		236	181
Property, Plant and Equipment, net		6,578	6,598
Other Noncurrent Assets
Regulatory assets		381	374
Goodwill		607	607
Other intangibles		35	36
Other noncurrent assets		60	57
Total Other Noncurrent Assets		1,083	1,074
Total Assets		8,086	8,085
Current Liabilities
Short-term debt		51	16
Accounts payable		94	78
Accounts payable to affiliates		43	56
Taxes		16	45
Interest		16	16
Customer deposits		30	29
Regulatory liabilities		10	13
Asset retirement obligations		44	19
Other current liabilities		32	36
Total Current Liabilities		336	308
Long-term Debt
Long-term Debt		2,327	2,327
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,242	1,170
Investment tax credits		95	96
Accrued pension obligations		38	62
Asset retirement obligations		189	269
Regulatory liabilities		484	480
Other deferred credits and noncurrent liabilities		42	50
Total Deferred Credits and Other Noncurrent Liabilities		2,090	2,127
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,616	2,616
Earnings reinvested		409	400
Accumulated other comprehensive loss		0	(1)
Total Equity		3,333	3,323
Total Liabilities and Equity		$ 8,086	$ 8,085

[1] 1,560,000 shares authorized; 685,473 and 679,731 shares issued and outstanding at June 30, 2017 and December 31, 2016.

[2] 170,000 shares authorized; 66,368 shares issued and outstanding at June 30, 2017 and December 31, 2016.

[3] 75,000 shares authorized; 21,294 shares issued and outstanding at June 30, 2017 and December 31, 2016.

[4] 80,000 shares authorized; 37,818 shares issued and outstanding at June 30, 2017 and December 31, 2016.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 53	$ 54
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)	685,473	679,731
Common stock shares outstanding (in shares)	685,473	679,731
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 26	$ 28
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	$ 25	$ 24
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 1	$ 2
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	$ 2	$ 2
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, 2015			673,857	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2015		$ 9,919	$ 7		$ 9,687	$ 2,953	$ (2,728)	$ 3,119		$ 364		$ 1,934	$ 821		$ 2,330		$ 424		$ 1,611	$ 295	$ 3,287		$ 308		$ 2,596	$ 383	$ 0
Balance at beginning of period at Dec. 31, 2015														$ 4,517
Common stock shares issued	[1]		3,692
Common stock issued		109			109
Stock-based compensation		(30)			(30)
Net Income		964				964		173	[5]				173	204	96	[5]				96	129	[6]				129
Contributions from member														37
Capital contributions from parent								200				200			47				47		20				20
Dividends and dividend equivalents		(515)				(515)
Dividends declared on common stock								(116)					(116)		(61)					(61)	(113)					(113)
Distributions to member														(114)
Other comprehensive income (loss)		(129)					(129)							3							(1)						(1)
Adoption of stock-based compensation guidance cumulative effect adjustment		7				7
Balance at end of period - shares at Jun. 30, 2016			677,549	[1]						66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Jun. 30, 2016		$ 10,325	$ 7		9,766	3,409	(2,857)	$ 3,376		$ 364		2,134	878		$ 2,412		$ 424		1,658	330	$ 3,322		$ 308		2,616	399	(1)
Balance at end of period at Jun. 30, 2016														4,647
Balance at beginning of period - shares at Dec. 31, 2016		679,731	679,731	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		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	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	685,473	[1]				66,368		66,368	[2]				21,294		21,294	[3]			37,818		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

[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, 2017 Integer
Vote per share of PPL's common stock	1

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Interim Financial Statements

6 Months Ended

Jun. 30, 2017

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, 2016 is derived from that Registrant's 2016 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2016 Form 10-K. The results of operations for the three and six months ended June 30, 2017 are not necessarily indicative of the results to be expected for the full year ending December 31, 2017 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, 2017

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 2016 Form 10-K and should be read in conjunction with those disclosures.

Accounts Receivable(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, 2017, PPL Electric purchased $288 million and $644 million of accounts receivable from alternative energy suppliers. During the three and six months ended June 30, 2016, PPL Electric purchased $297 million and $679 million of accounts receivable from alternative electricity suppliers.

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Segment and Related Information

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Segment and Related Information

3. Segment and Related Information

(PPL)

See Note 2 in PPL's 2016 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
	2017			2016			2017			2016
Income Statement Data
Revenues from external customers
U.K. Regulated	$	502		$	563		$	1,070		$	1,158
Kentucky Regulated	723			721			1,532			1,547
Pennsylvania Regulated	500			495			1,073			1,080
Corporate and Other	—			6			1			11
Total	$	1,725		$	1,785		$	3,676		$	3,796
Net Income
U.K. Regulated (a)	$	148		$	345		$	434		$	634
Kentucky Regulated	79			76			174			188
Pennsylvania Regulated	77			78			156			172
Corporate and Other	(12		)	(16		)	(69		)	(30		)
Total	$	292		$	483		$	695		$	964

(a) Includes unrealized gains and losses from hedging foreign-currency related economic activity. See Note 13 for additional information.

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

	June 30, 2017			December 31, 2016
Balance Sheet Data
Assets
U.K. Regulated (a)	$	15,798		$	14,537
Kentucky Regulated	14,043			14,037
Pennsylvania Regulated	10,175			9,426
Corporate and Other (b)	(52		)	315
Total	$	39,964		$	38,315

(a) Includes $11.5 billion and $10.8 billion of net PP&E as of June 30, 2017 and December 31, 2016. 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 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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Earnings Per Share

6 Months Ended

Jun. 30, 2017

Earnings Per Share [Abstract]

Earnings Per Share

4. Earnings Per Share

(PPL)

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

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
	2017		2016		2017		2016
Income (Numerator)
Net income	$	292	$	483	$	695	$	964
Less amounts allocated to participating securities	—		1		1		3
Net income available to PPL common shareowners - Basic and Diluted	$	292	$	482	$	694	$	961
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	683,841		677,145		682,370		676,293
Add incremental non-participating securities:
Share-based payment awards	2,510		3,584		2,355		3,480
Weighted-average shares - Diluted EPS	686,351		680,729		684,725		679,773
Basic EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.02	$	1.42
Diluted EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.01	$	1.41

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
	2017	2016	2017	2016
Stock-based compensation plans (a)	564	795	1,451	2,920
DRIP	369	370	814	772

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

See Note 7 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
	2017	2016	2017	2016
Stock options	696	696	696	696
Performance units	—	78	—	39

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Income Taxes

6 Months Ended

Jun. 30, 2017

Income Tax Disclosure [Abstract]

Income Taxes

5. Income Taxes

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

(PPL)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	129		$	236		$	315		$	467
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			9			23			22
Valuation allowance adjustments	—			3			5			9
Impact of lower U.K. income tax rates	(40		)	(45		)	(88		)	(99		)
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(7		)	—			(16		)	(2		)
Impact of the U.K. Finance Acts	(6		)	(2		)	(9		)	(2		)
Depreciation not normalized	(2		)	(3		)	(5		)	(4		)
Interest benefit on U.K. financing entities	(4		)	(4		)	(8		)	(9		)
Stock-based compensation	(4		)	(3		)	(7		)	(11		)
Other	—			1			(5		)	—
Total increase (decrease)	(53		)	(44		)	(110		)	(96		)
Total income taxes	$	76		$	192		$	205		$	371

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

(PPL Electric)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	44		$	44		$	88		$	97
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	9			8			17			18
Depreciation not normalized	(2		)	(2		)	(4		)	(3		)
Stock-based compensation	(3		)	(2		)	(5		)	(7		)
Other	(1		)	—			(1		)	(1		)
Total increase (decrease)	3			4			7			7
Total income taxes	$	47		$	48		$	95		$	104

(LKE)
	Three Months						Six Months
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	49		$	47		$	107		$	114
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5			5			11			12
Other	(1		)	(1		)	(2		)	(3		)
Total increase (decrease)	4			4			9			9
Total income taxes	$	53		$	51		$	116		$	123

(LG&E)
	Three Months				Six Months
	2017		2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	24	$	22	$	55		$	54
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3		2		6			6
Other	—		—		(1		)	(1		)
Total increase (decrease)	3		2		5			5
Total income taxes	$	27	$	24	$	60		$	59

(KU)
	Three Months					Six Months
	2017			2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	32		$	31	$	67		$	73
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3			3		7			7
Other	(1		)	—		(1		)	—
Total increase (decrease)	2			3		6			7
Total income taxes	$	34		$	34	$	73		$	80

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Utility Rate Regulation

6 Months Ended

Jun. 30, 2017

Regulated Operations [Abstract]

Utility Rate Regulation

6. Utility Rate Regulation

(All Registrants)

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

	PPL				PPL Electric
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	—	$	—
Generation formula rate	10		11		—		—
Transmission service charge	—		7		—		7
Gas supply clause	7		3		—		—
Smart meter rider	10		6		10		6
Storm costs	3		5		3		5
Other	1		1		1		1
Total current regulatory assets (a)	$	37	$	39	$	14	$	19
Noncurrent Regulatory Assets:
Defined benefit plans	$	920	$	947	$	537	$	549
Taxes recoverable through future rates	345		340		345		340
Storm costs	40		58		—		10
Unamortized loss on debt	57		61		32		36
Interest rate swaps	124		129		—		—
Accumulated cost of removal of utility plant	162		159		162		159
AROs	245		211		—		—
Other	13		13		—		—
Total noncurrent regulatory assets	$	1,906	$	1,918	$	1,076	$	1,094

	PPL				PPL Electric
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Generation supply charge	$	19	$	23	$	19	$	23
Transmission service charge	6		—		6		—
Universal service rider	14		14		14		14
Transmission formula rate	3		15		3		15
Fuel adjustment clause	13		11		—		—
Act 129 compliance rider	11		17		11		17
Storm damage expense	4		13		4		13
Other	1		8		—		1
Total current regulatory liabilities	$	71	$	101	$	57	$	83
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	—	$	—
Power purchase agreement - OVEC (b)	72		75		—		—
Net deferred tax assets	21		23		—		—
Defined benefit plans	27		23		—		—
Interest rate swaps	76		78		—		—
Other	3		—		—		—
Total noncurrent regulatory liabilities	$	902	$	899	$	—	$	—

	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	4	$	6	$	2	$	—
Generation formula rate	10		11		—		—		10		11
Gas supply clause	7		3		7		3		—		—
Total current regulatory assets	$	23	$	20	$	11	$	9	$	12	$	11
Noncurrent Regulatory Assets:
Defined benefit plans	$	383	$	398	$	238	$	246	$	145	$	152
Storm costs	40		48		22		26		18		22
Unamortized loss on debt	25		25		16		16		9		9
Interest rate swaps	124		129		85		88		39		41
AROs	245		211		84		70		161		141
Plant retirement costs	3		4		—		—		3		4
Other	10		9		4		4		6		5
Total noncurrent regulatory assets	$	830	$	824	$	449	$	450	$	381	$	374

	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Demand side management	$	—	$	3	$	—	$	2	$	—	$	1
Fuel adjustment clause	13		11		4		2		9		9
Other	1		4		—		1		1		3
Total current regulatory liabilities	$	14	$	18	$	4	$	5	$	10	$	13
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	308	$	305	$	395	$	395
Power purchase agreement - OVEC (b)	72		75		50		52		22		23
Net deferred tax assets	21		23		21		23		—		—
Defined benefit plans	27		23		—		—		27		23
Interest rate swaps	76		78		38		39		38		39
Other	3		—		1		—		2		—
Total noncurrent regulatory liabilities	$	902	$	899	$	418	$	419	$	484	$	480

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

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

Regulatory Matters

Kentucky Activities

(PPL, LKE, LG&E and KU)

Rate Case Proceedings

In November 2016, LG&E and KU filed requests with the KPSC for increases in annual base electricity and gas rates. LG&E's and KU's applications included requests for CPCNs for implementing an Advanced Metering System program and a Distribution Automation program.

On April 19, 2017 and May 1, 2017, LG&E and KU, along with all intervening parties to the proceeding, filed with the KPSC, stipulation and recommendation agreements (stipulations) resolving all issues with the parties. Among other things, the proposed stipulations provided for increases in annual revenue requirements associated with KU base electricity rates of $55 million, LG&E base electricity rates of $59 millionand LG&E base gas rates of $8 million, reflecting a return on equity of 9.75%, the withdrawal of LG&E's and KU's request for a CPCN for the Advanced Metering System and other changes to the revenue requirements, which dealt primarily with the timing of cost recovery, including depreciation rates.

On June 22, 2017, the KPSC issued orders approving, with certain modifications, the proposed stipulations filed in April and May 2017. On June 29, 2017, the KPSC issued further orders correcting certain revenue requirement and rate calculations and making other technical corrections to the June 22, 2017 orders. The combined KPSC orders modified the stipulations to provide for increases in annual revenue requirements associated with KU base electricity rates of $52 million, LG&E base electricity rates of $57 million and LG&E base gas rates of $7 million, and incorporate an authorized return on equity of 9.7%. Consistent with the stipulations, the orders approved LG&E's and KU's request for implementing a Distribution Automation program and their withdrawal of a request for a CPCN for the Advanced Metering System program. The orders also approved new depreciation rates for LG&E and KU that will result in higher depreciation of approximately $15 million ($4 million for LG&E and $11 million for KU) in 2017, exclusive of net additions to PP&E. The orders result in a base electricity rate increase of3.2% at KU and base electricity and gas rate increases of 5.2% and 2.1% at LG&E. The new base rates and all elements of the orders became effective July 1, 2017.On June 23, 2017, the KPSC also issued orders establishing an authorized return on equity of 9.7%for all of LG&E's and KU's existing approved ECR plans and projects, replacing the prior authorized return on equity levels of 9.8%for CCR projects and 10%for all other ECR approved projects, effective with bills issued in August 2017. The impact of the new authorized return for ECR projects is not expected to be significant in 2017.

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 customers, the franchise fee will revert to zero. In August 2016, LG&E filed an application in a KPSC proceeding to review and rule upon the recoverability of the franchise fee.

In August 2016, Louisville/Jefferson County submitted a motion to dismiss the proceeding filed by LG&E and, in November 2016, filed an amended complaint against LG&E relating to these issues. LG&E submitted KPSC filings to respond to, request dismissal of and consolidate certain claims or aspects of the proceedings. In January 2017, the KPSC issued an order denying Louisville/Jefferson County's motion to dismiss, consolidating the matter with LG&E's filed application and establishing a procedural schedule for the case. Louisville/Jefferson County and LG&E continue to file certain procedural motions, testimony and discovery with the KPSC. Until the KPSC issues a final order in this proceeding, LG&E cannot predict the ultimate outcome of this matter but does not anticipate that it will have a material effect on its financial condition or results of operation. LG&E continues to provide gas service to customers in this franchise area at existing rates, but without collecting or remitting a franchise fee.

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Financing Activities

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Financing Activities

7. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, 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. The following credit facilities were in place at: 

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2022	£	210	£	155	£	—	£	56	£	160	£	—
Term Loan Facility (b)	Dec. 2017	230		230		—		—		—		—
WPD (South West)
Syndicated Credit Facility (c)	July 2021	245		80		—		165		110		—
WPD (East Midlands)
Syndicated Credit Facility (d)	July 2021	300		116		—		184		9		—
WPD (West Midlands)
Syndicated Credit Facility	July 2021	300		—		—		300		—		—
Uncommitted Credit Facilities (e)		90		50		4		36		60		4
Total U.K. Credit Facilities (f)		£	1,375	£	631	£	4	£	741	£	339	£	4

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2022	$	950	$	—	$	424	$	526	$	—	$	20
Syndicated Credit Facility	Nov. 2018	300		—		—		300		—		—
Bilateral Credit Facility	Mar. 2018	150		—		17		133		—		17
Total PPL Capital Funding Credit Facilities		$	1,400	$	—	$	441	$	959	$	—	$	37
PPL Electric
Syndicated Credit Facility	Jan. 2022	$	650	$	—	$	1	$	649	$	—	$	296
LKE
Syndicated Credit Facility	Oct. 2018	$	75	$	—	$	—	$	75	$	—	$	—
LG&E
Syndicated Credit Facility	Jan. 2022	$	500	$	—	$	207	$	293	$	—	$	169
KU
Syndicated Credit Facility	Jan. 2022	$	400	$	—	$	51	$	349	$	—	$	16
Letter of Credit Facility	Oct. 2017	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	249	$	349	$	—	$	214

(a) The amounts borrowed at June 30, 2017 and December 31, 2016 were USD-denominated borrowings of $200 million for both periods, which bore interest at 1.87% and 1.43%. The unused capacity reflects the amount borrowed in GBP of £154 million as of the date borrowed.

(b) The amount borrowed at June 30, 2017 was a GBP-denominated borrowing which equated to $297 million and bore interest at 1.50%.

(c) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $103 million and $137 million and bore interest at 0.65% and 0.66%.

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

(e) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $65 million and $75 million and bore interest at 1.07% and 1.26%.

(f) At June 30, 2017, the unused capacity under the U.K. credit facilities was $956 million.

(PPL, LKE and KU)

In August 2017, the expiration date for the KU letter of credit facility was extended to October 2020.

(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, 2017							December 31, 2016
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	1.46%	$	1,000	$	424	$	576	1.10%	$	20
PPL Electric		650		—		650		1.05%	295
LG&E	1.35%	350		207		143		0.94%	169
KU	1.40%	350		51		299		0.87%	16
Total		$	2,350	$	682	$	1,668		$	500

(PPL Electric and LKE)

See Note 10 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

In March 2017, WPD (South Wales) issued £50 million of 0.01% Index-linked Senior Notes due 2029. WPD (South Wales) received proceeds of £53 million, which equated to $64 million at the time of issuance, net of fees and including a premium. The principal amount of the notes is adjusted based on changes in a specified index, as detailed in the terms of the related indenture. The proceeds were used for general corporate purposes.

(PPL and PPL Electric)

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

(PPL, LKE and LG&E)

In June 2017, the County of Trimble, Kentucky issued $60 million of Environmental Facilities Revenue Refunding Bonds, 2017 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were issued bearing interest at a rate of 3.75% through their maturity and are subject to an optional redemption on or after June 1, 2027. The proceeds of the bonds were used to redeem $60 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 previously issued by the County of Trimble, Kentucky on behalf of LG&E.

In June 2017, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A (Louisville Gas and Electric Company Project) due 2033 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.25% through their mandatory purchase date of June 3, 2019.

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

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

(PPL)

ATM Program

In February 2015, PPL entered into two separate equity distribution agreements, pursuant to which PPL may sell, from time to time, up to an aggregate of $500 million of its common stock. For the periods ended June 30, PPL issued the following:

	Three Months				Six Months
	2017		2016		2017		2016
Number of shares (in thousands)	2,113		—		3,477		—
Average share price	$	39.15	$	—	$	38.17	$	—
Net Proceeds	$	82	$	—	$	132	$	—

Distributions

In May 2017, PPL declared a quarterly common stock dividend, payable July 3, 2017, of 39.5 cents per share (equivalent to $1.58 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, 2017

Compensation and Retirement Disclosure [Abstract]

Defined Benefits

8. Defined Benefits

(PPL, LKE and LG&E)

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

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2017			2016			2017			2016			2017			2016			2017			2016
PPL
Service cost	$	15		$	16		$	18		$	18		$	32		$	33		$	37		$	36
Interest cost	42			44			44			62			84			87			87			124
Expected return on plan assets	(58		)	(58		)	(127		)	(132		)	(115		)	(114		)	(252		)	(265		)
Amortization of:
Prior service cost	3			3			—			—			5			4			—			—
Actuarial loss	14			10			36			36			34			25			71			73
Net periodic defined benefit costs (credits) before special termination benefits	16			15			(29		)	(16		)	40			35			(57		)	(32		)
Special termination benefits (a)	(1		)	—			—			—			1			—			—			—
Net periodic defined benefit costs (credits)	$	15		$	15		$	(29	)	$	(16	)	$	41		$	35		$	(57	)	$	(32	)

(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
	2017			2016			2017			2016
LKE
Service cost	$	5		$	6		$	12		$	12
Interest cost	18			18			34			35
Expected return on plan assets	(24		)	(24		)	(46		)	(45		)
Amortization of:
Prior service cost	2			3			4			4
Actuarial loss	4			5			15			10
Net periodic defined benefit costs	$	5		$	8		$	19		$	16

	Pension Benefits
	Three Months						Six Months
	2017			2016			2017			2016
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			4			$	6		$	7
Expected return on plan assets	(6		)	(5		)	(11		)	(10		)
Amortization of:
Prior service cost	1			1			2			2
Actuarial loss	1			1			4			3
Net periodic defined benefit costs	$	—		$	2		$	2		$	3

	Other Postretirement Benefits
	Three Months						Six Months
	2017			2016			2017			2016
PPL
Service cost	$	2		$	2		$	4		$	4
Interest cost	6			7			12			13
Expected return on plan assets	(5		)	(6		)	(11		)	(11		)
Amortization of prior service cost	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	2		$	3		$	4		$	6
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			3			4			5
Expected return on plan assets	(2		)	(1		)	(3		)	(3		)
Amortization of prior service cost	—			—			—			1
Net periodic defined benefit costs	$	1		$	3		$	3		$	5

(PPL Electric, LG&E and KU)

In addition to the specific plans 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. 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
	2017		2016		2017		2016
PPL Electric	$	5	$	5	$	13	$	11
LG&E	2		3		5		5
KU	1		3		5		6

Expected Cash Flows - U.K. Pension Plans

(PPL)

For the six months ended June 30, 2017, WPD contributed $485 million to its U.K. pension plans. These accelerated contributions fund all 2017 required contributions and a portion of 2018 required contributions. WPD does not expect to make additional contributions in 2017.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

9. Commitments and Contingencies

Legal Matters

(All Registrants)

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

WKE Indemnification(PPL and LKE)

See footnote (e) to the table in "Guarantees and Other Assurances" below for information on an LKE indemnity relating to its former WKE lease, including related legal proceedings.

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 and RCRA. In addition, these plaintiffs assert common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within four miles of the Cane Run plant. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In response to a motion to dismiss filed by PPL and LG&E, in July 2014, the court dismissed the plaintiffs' RCRA claims and all but one Clean Air Act claim, but declined to dismiss the common law tort claims. In November 2016, 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 under the Clean Air Act, and directed the parties to submit briefs regarding whether the court should continue to exercise supplemental jurisdiction regarding the remaining state law-only claims. On April 13, 2017, the District Court issued an order declining to exercise supplemental jurisdiction and dismissing the case in its entirety, subject to certain federal appeals or state court re-filing rights of the parties. On June 16, 2017, the plaintiffs filed a class action complaint in Jefferson Circuit Court, Kentucky, against LG&E regarding the 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.PPL, LKE and LG&E cannot predict the outcome of this matter. LG&E retired one coal-fired unit at the Cane Run plant in March 2015 and the remaining two coal-fired units at the plant in June 2015.

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 seek injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act violations, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also seek assessment of civil penalties and an award of litigation costs and attorney fees. PPL, LKE and KU cannot predict the outcome of this matter or the potential impact on the operations of the E.W. Brown plant, including increased capital or operating costs, if any.  

(PPL, LKE, LG&E and KU)

Trimble County Water Discharge Permit

In May 2010, the Kentucky Waterways Alliance and other environmental groups filed a petition with the Kentucky Energy and Environment Cabinet (KEEC) challenging the Kentucky Pollutant Discharge Elimination System permit issued in April 2010, which covers water discharges from the Trimble County plant. In November 2010, the KEEC issued a final order upholding the permit, which was subsequently appealed by the environmental groups. In September 2013, the Franklin Circuit Court reversed the KEEC order upholding the permit and remanded the permit to the agency for further proceedings. LG&E and the KEEC appealed the order to the Kentucky Court of Appeals. In July 2015, the Court of Appeals upheld the lower court ruling. LG&E and the KEEC moved for discretionary review by the Kentucky Supreme Court. In February 2016, the Kentucky Supreme Court issued an order granting discretionary review and oral arguments were held in September 2016. On April 27, 2017, the Kentucky Supreme Court issued an order reversing the decision of the appellate court and upholding the permit issued to LG&E by the KEEC. PPL, LKE, LG&E and KU are unable to predict the outcome of this matter or the potential impact on the operations of the Trimble County plant, including increased capital or operating costs, if any, but do not expect such costs to be material.

Trimble County Landfill

Various state and federal permits and regulatory approvals are required in order to construct a landfill at the Trimble County plant to be used for disposal of CCRs. In October 2016, the Kentucky Division of Water issued a water quality certification and in February 2017, the Kentucky Division of Waste Management issued a “special waste” landfill permit. In March 2017, the Sierra Club and a resident adjacent to the plant filed administrative challenges to the landfill permit before the KEEC. In June 2017, the U.S. Army Corps of Engineers issued a dredge and fill permit, the final approval required for construction of the landfill. PPL, LKE, LG&E and KU believe that all permits and regulatory approvals issued for the project comply with applicable state and federal laws, but cannot predict the outcome of legal challenges or the potential impact, if any, on plant operations, or future capital or operating costs. However, PPL, LKE, LG&E and KU believe that additional costs, if any, resulting from such legal challenges would be subject to cost recovery.

Regulatory Issues(All Registrants)

See Note 6 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

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

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

PPL Electric, LG&E and KU monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity (including RFC or SERC) determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC.

In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any.

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)

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 plants. The Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six criteria pollutants to protect public health and welfare. These concentration levels are known as NAAQS. The six criteria pollutants are carbon monoxide, lead, nitrogen dioxide, ozone, particulate matter and sulfur dioxide.

Federal environmental regulations of these criteria pollutants require states to adopt implementation plans, known as state implementation plans, for certain pollutants, 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.

National Ambient Air Quality Standards (NAAQS)

Under the Clean Air Act, the EPA is required to reassess the NAAQS for certain air pollutants on a five-year schedule. In 2008, the EPA revised the NAAQS for ozone and proposed to further strengthen the standard in November 2014. The EPA released a new ozone standard on October 1, 2015. The states and the EPA will determine attainment with the new ozone standard through review of relevant ambient air monitoring data, with attainment or nonattainment designations scheduled no later than October 2018. States are also obligated to address interstate transport issues associated with new 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. States that are not in the ozone transport region, including Kentucky, worked together to evaluate the need for further nitrogen oxide reductions from fossil-fueled plants with SCRs. Based on regulatory developments to date, PPL, LKE, LG&E and KU do not anticipate requirements for nitrogen oxide reductions beyond those currently required under the Cross State Air Pollution Rule.

In 2010, the EPA finalized revised NAAQS for sulfur dioxide and required states to identify areas that meet those standards and areas that are in "non-attainment". In July 2013, the EPA finalized non-attainment designations for parts of the country, including part of Jefferson County in Kentucky. Attainment must be achieved by 2018. Based on regulatory developments to date, PPL, LKE, LG&E and KU expect that certain previously required compliance measures, such as upgraded or new sulfur dioxide Scrubbers and additional sulfur dioxide limits at certain plants and the retirement of coal-fired generating units at LG&E's Cane Run plant and KU's Green River plant, are sufficient to achieve compliance with the new sulfur dioxide and ozone 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 Clean Power Plan described below, 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, in March 2017, the President issued an Executive Order (the March 2017 Executive Order) directing the EPA to review proposed and final rules relating to GHG reductions for consistency with certain policy directives and suspend, revise, or rescind those rules as appropriate. The March 2017 Executive Order also directs rescission of specified guidance, directives, and prior Presidential actions regarding climate change. PPL, LKE, LG&E and KU cannot predict the outcome of such regulatory actions or the impact, if any, on plant operations, rate treatment or future capital or operating needs.

The U.K. has enacted binding carbon reduction requirements that are applicable to WPD. Under the U.K. law, WPD must purchase carbon allowances to offset emissions associated with WPD's operations. The cost of these allowances is 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

As further described below, the EPA finalized rules imposing GHG emission standards for both new and existing power plants. The EPA has also issued a proposed federal implementation plan that would apply to any states that fail to submit an acceptable state implementation plan under these rules.

The future of these rules is uncertain. The EPA's authority to promulgate these regulations under Section 111 of the Clean Air Act has been challenged in the D.C. Circuit Court by several states and industry groups. In February 2016, the U.S. Supreme Court stayed the rule for existing plants (the Clean Power Plan) pending the D.C. Circuit Court's review and subsequent review by the U.S. Supreme Court if a writ of certiorari is filed and granted. In addition, the President's March 2017 Executive Order requires the EPA to review the rules for new plants and existing power plants and suspend, revise or rescind them as appropriate.

The EPA's rule for new power plants imposes separate emission standards for coal and natural gas units based on the application of different technologies. The coal standard is based on the application of partial carbon capture and sequestration technology, but because this technology is not presently commercially viable, the rule effectively precludes the construction of new coal-fired plants. The standard for NGCC power plants is the same as what the EPA proposed in 2012 and is not continuously achievable. The preclusion of new coal-fired plants and the compliance difficulties posed for new natural gas-fired plants could have a significant industry-wide impact.

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

LG&E and KU are monitoring developments at the state and federal level. Various states, industry groups and individual companies including LKE have filed petitions for reconsideration with the EPA and petitions for review with the D.C. Circuit Court challenging the Clean Power Plan. In February 2016, the U.S. Supreme Court stayed the rule pending the D.C. Circuit Court's review. The EPA has commenced review of the Clean Power Plan and related actions, as directed by the President's March 2017 Executive Order. In April 2017, in response to a motion filed by the EPA, the D.C. Circuit temporarily held the litigation in abeyance in light of the EPA's ongoing review of the Clean Power Plan. PPL, LKE, LG&E and KU cannot predict the outcome of the pending litigation, any changes in regulations, interpretations, or litigation positions that may be implemented by the U.S. presidential administration or the potential impact, if any, on plant operations, or future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, would be subject to cost recovery.

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

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. 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)

Coal Combustion Residuals (CCRs)

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

Recently enacted federal legislation has authorized the EPA to approve equally protective state programs that would operate in lieu of the CCR Rule. In January 2017, Kentucky issued a state rule, effective May 2017, aimed at reflecting the requirements of the federal rule. In May 2017, a resident adjacent to LG&E's and KU's Trimble County plant filed a lawsuit in state court against the Kentucky Energy and Environmental Cabinet and LG&E seeking to invalidate the new rule. PPL, LKE, LG&E and KU cannot predict the outcome of the litigation, but anticipate continued operation under the former program in the event that the new rule is struck down.

LG&E and KU have received KPSC approval for a compliance plan providing for construction of additional landfill capacity at the E.W. Brown station, closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with federal CCR rule requirements, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law requirements. See Note 6 in the Registrants' 2016 Form 10-K for additional information.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs during 2015, 2016 and 2017. See Note 15 below and Note 19 in the Registrants' 2016 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.

Effluent Limitations Guidelines (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 June 2017, the EPA published in the Federal Register a rule that would postpone applicable compliance dates until the agency completes reconsideration of the rule. 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 at this time, although certain preliminary estimates are included in current capital forecasts for applicable periods. 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. A range of reasonably possible costs cannot currently be estimated. Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant.

(All Registrants)

Other Issues

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

Superfund and Other Remediation

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

PPL Electric, LG&E and KU are investigating, responding to agency inquiries, remediating, or have completed the remediation of, several sites that were not addressed under a regulatory program such as Superfund, but for which PPL Electric, LG&E and KU may be liable for remediation. 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 on such additional sites and are therefore unable to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

At June 30, 2017 and December 31, 2016, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites noted 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 for compliance 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 applicable to certain of the costs or other obligations related to these matters but the amount of insurance coverage or reimbursement cannot be estimated or assured.

Other

Labor Union Agreements

(PPL and PPL Electric)

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

(LKE and KU)

In August 2017, KU and the United Steelworkers of America ratified a three-year labor agreement through August 2020. The agreement covers approximately 53 employees. The terms of the new labor agreement are not expected to have a significant impact on the financial results of LKE or 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, 2017. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote except for "WPD guarantee of pension and other obligations of unconsolidated entities" and "Indemnification of lease termination and other divestitures." The total recorded liability at June 30, 2017 and December 31, 2016 was $22 million for PPL and $17 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, 2017			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2019
WPD guarantee of pension and other obligations of unconsolidated entities	92		(c)
PPL Electric
Guarantee of inventory value	15		(d)	2018
LKE
Indemnification of lease termination and other divestitures	301		(e)	2021 - 2023
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, 2017, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.

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

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

(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 $120 million at June 30, 2017, consisting of LG&E's share of $83 million and KU's share of $37 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LKE's, LG&E's and KU's 2016 Form 10-K for additional information on the OVEC power purchase contract. In connection with recent credit market related developments at OVEC or certain of its sponsors, such parties, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs and accelerated maturities of OVEC's existing short and long-term debt. The ultimate outcome of these matters, including any potential impact on LG&E's and KU's obligations relating to OVEC debt under the power purchase contract cannot be predicted.

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, 2017

PPL Electric Utilities Corp [Member]

Related Party Transactions [Line Items]

Related Party Transactions

10. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other, as applicable, with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. 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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81%.

(LKE)

LKE maintains a $225 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, 2017 and December 31, 2016, $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12%.

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

Other(PPL Electric, LG&E and KU)

See Note 8 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

10. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other, as applicable, with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. 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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81%.

(LKE)

LKE maintains a $225 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, 2017 and December 31, 2016, $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12%.

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

Other(PPL Electric, LG&E and KU)

See Note 8 for discussions regarding intercompany allocations associated with defined benefits.

Louisville Gas And Electric Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

10. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other, as applicable, with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. 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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81%.

(LKE)

LKE maintains a $225 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, 2017 and December 31, 2016, $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12%.

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

Other(PPL Electric, LG&E and KU)

See Note 8 for discussions regarding intercompany allocations associated with defined benefits.

Kentucky Utilities Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

10. Related Party Transactions

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

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other, as applicable, with administrative, management and support services. For all service companies, the costs of these services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. 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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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. At June 30, 2017, $270 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet. No balance was outstanding at December 31, 2016. The interest rates on borrowings are equal to one-month LIBOR plus a spread. The interest rate on the outstanding borrowing at June 30, 2017 was 2.81%.

(LKE)

LKE maintains a $225 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, 2017 and December 31, 2016, $159 million and $163 million were outstanding and reflected in "Notes payable with affiliate" on the Balance Sheets. The interest rates on the outstanding borrowing at June 30, 2017 and December 31, 2016 were 2.56% and 2.12%.

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

Other(PPL Electric, LG&E and KU)

See Note 8 for discussions regarding intercompany allocations associated with defined benefits.

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Other Income (Expense) - net

6 Months Ended

Jun. 30, 2017

Other Nonoperating Income (Expense) [Abstract]

Other Income (Expense) - net

11. Other Income (Expense) - net

(PPL)

"Other Income (Expense) - net" for the three and six months ended June 30, 2017 and 2016 consisted primarily of gains (losses) on foreign currency contracts to economically hedge PPL's translation risk related to its GBP denominated earnings in the U.K. See Note 13 for additional information on these derivatives.

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Fair Value Measurements

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

12. 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, 2017 and 2016, there were no transfers between Level 1 and Level 2. See Note 1 in each Registrant's 2016 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, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	467	$	467	$	—	$	—	$	341	$	341	$	—	$	—
Restricted cash and cash equivalents (a)	25		25		—		—		26		26		—		—
Price risk management assets (b):
Foreign currency contracts	156		—		156		—		211		—		211		—
Cross-currency swaps	158		—		158		—		188		—		188		—
Total price risk management assets	314		—		314		—		399		—		399		—
Total assets	$	806	$	492	$	314	$	—	$	766	$	367	$	399	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	31	$	—	$	31	$	—	$	31	$	—	$	31	$	—
Foreign currency contracts	104		—		104		—		27		—		27		—
Total price risk management liabilities	$	135	$	—	$	135	$	—	$	58	$	—	$	58	$	—
PPL Electric
Assets
Cash and cash equivalents	$	59	$	59	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	61	$	61	$	—	$	—	$	15	$	15	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	13	$	13	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	21	$	21	$	—	$	—	$	16	$	16	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
LG&E
Assets
Cash and cash equivalents	$	7	$	7	$	—	$	—	$	5	$	5	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	9	$	9	$	—	$	—	$	8	$	8	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—

	June 30, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—
Total assets	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—

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

(b) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

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

Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps

(PPL, LKE, LG&E and KU)

To manage interest rate risk, PPL, LKE, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency risk, PPL uses foreign currency contracts such as forwards, options and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3.

Financial Instruments Not Recorded at Fair Value(All Registrants)

The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. The fair values were estimated using an income approach by discounting future cash flows at estimated current cost of funding rates, which incorporate the credit risk of the Registrants. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.

	June 30, 2017				December 31, 2016
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	19,068	$	22,791	$	18,326	$	21,355
PPL Electric	3,298		3,705		2,831		3,148
LKE	5,067		5,535		5,065		5,439
LG&E	1,619		1,749		1,617		1,710
KU	2,327		2,572		2,327		2,514

(a) Amounts are net of debt issuance costs.

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

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Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

13. 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 the 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 mechanisms in place.

Foreign currency risk

• PPL is exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates.

Commodity price risk

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

• PPL Electric is exposed to commodity price risk from its obligation as PLR; however, its PUC-approved cost recovery mechanism substantially eliminates its exposure to this risk. PPL Electric also mitigates its exposure to commodity price risk by entering into full-requirement supply agreements to serve its PLR customers. These supply agreements transfer the commodity price risk associated with the PLR obligation to the energy suppliers.

• LG&E's and KU's rates include certain mechanisms for fuel and fuel-related expenses. 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 period, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's 2016 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 mechanisms 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 LG&E, KU or PPL Electric defaults on its obligation, those entities 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, thus 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

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 $27 million obligation to return cash collateral under master netting arrangements at June 30, 2017 and a $19 million obligation to return cash collateral under master netting arrangements at December 31, 2016.

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

PPL, LKE and LG&E posted $2 million of cash collateral under master netting arrangements at June 30, 2017 and $3 million of cash collateral under master netting arrangements at December 31, 2016.

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. Various financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolio, adjust the duration of the debt portfolio 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. At June 30, 2017, PPL held an aggregate notional value in interest rate swap contracts of £145 million (approximately $187 million based on spot rates) that mature in 2027 to hedge the interest payments of anticipated WPD debt issuances. These swaps require a mandatory early redemption on or before November 30, 2017.

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

At June 30, 2017, PPL held an aggregate notional value in cross-currency interest rate swap contracts of $802 million that range in maturity from 2017 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, 2017 and 2016, 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, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. For the three and six months ended June 30, 2016, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At June 30, 2017, 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, 2017, 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 such contracts outstanding at June 30, 2017.

At June 30, 2017 and December 31, 2016, PPL had $21 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, 2017, the total exposure hedged by PPL was approximately £2.8 billion (approximately $3.7 billion based on contracted rates). These contracts had termination dates ranging from July 2017 through December 2019.

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 and KU's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at June 30, 2017 and December 31, 2016.

See Notes 1 and 17 in each Registrant's 2016 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, 2017								December 31, 2016
	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)	$	—	$	1	$	—	$	5	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	28		—		—		—		32		—		—		—
Foreign currency contracts	—		—		41		60		—		—		31		21
Total current	28		1		41		65		32		—		31		25
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		25		—		—		—		27
Cross-currency swaps (b)	130		—		—		—		156		—		—		—
Foreign currency contracts	—		—		115		44		—		—		180		6
Total noncurrent	130		—		115		69		156		—		180		33
Total derivatives	$	158	$	1	$	156	$	134	$	188	$	—	$	211	$	58

(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, 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

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, 2016.

								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	$	(3	)	$	(21	)	Interest expense	$	(2	)	$	—	$	(3	)	$	—
Cross-currency swaps	(104		)	9			Interest expense	(1		)	—		—			—
							Other income (expense) - net	(103		)	—		(6		)	—
Total	$	(107	)	$	(12	)		$	(106	)	$	—	$	(9	)	$	—
Net Investment Hedges:
Foreign currency contracts	$	1		$	4

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	$	171		$	231
Interest rate swaps	Interest expense	(2		)	(4		)
	Total	$	169		$	227
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	$	(3	)	$	(9	)

(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, 2017				December 31, 2016
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4
Total current	—		5		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		25		—		27
Total noncurrent	—		25		—		27
Total derivatives	$	—	$	30	$	—	$	31

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets 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

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, 2016. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(4	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(3	)	$	(9	)

(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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

Credit Risk-Related Contingent Features

Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LKE, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.

Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LKE's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.

(PPL, LKE and LG&E)

At June 30, 2017, 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	$	23	$	12	$	12
Aggregate fair value of collateral posted on these derivative instruments	2		2		2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	21		10		10

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

XML

Goodwill

6 Months Ended

Jun. 30, 2017

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

14. Goodwill and Other Intangible Assets

(PPL)

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

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

XML

Asset Retirement Obligations

6 Months Ended

Jun. 30, 2017

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

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)

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

Louisville Gas And Electric Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

Kentucky Utilities Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

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

	PPL			LKE			LG&E			KU
Balance at December 31, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 9 for information on the final CCR rule. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with approved ECR projects for CCRs are amortized to expense over a period of 10 to 25 years based on retirement expenditures made related to the obligation. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

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

XML

Accumulated Other Comprehensive Income (Loss)

6 Months Ended

Jun. 30, 2017

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, 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	)
March 31, 2016	$	(984	)	$	(5	)	$	—		$	(6	)	$	(2,164	)	$	(3,159	)
Amounts arising during the period	268			(85		)	—			—			2			185
Reclassifications from AOCI	—			85			(1		)	1			32			117
Net OCI during the period	268			—			(1		)	1			34			302
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
December 31, 2015	$	(520	)	$	(7	)	$	—		$	(6	)	$	(2,195	)	$	(2,728	)
Amounts arising during the period	(196		)	(5		)	—			—			2			(199		)
Reclassifications from AOCI	—			7			(1		)	1			63			70
Net OCI during the period	(196		)	2			(1		)	1			65			(129		)
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
LKE
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	)
March 31, 2016							$	—		$	(10	)	$	(35	)	$	(45	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							(1		)	1			1			1
Net OCI during the period							(1		)	1			2			2
June 30, 2016							$	(1	)	$	(9	)	$	(33	)	$	(43	)

	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, 2015			$	—		$	(10	)	$	(36	)	$	(46	)
Amounts arising during the period			—			—			1			1
Reclassifications from AOCI			(1		)	1			2			2
Net OCI during the period			(1		)	1			3			3
June 30, 2016			$	(1	)	$	(9	)	$	(33	)	$	(43	)

(PPL)

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

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2017			2016			2017			2016			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(5	)	$	(3	)	Interest Expense
Cross-currency swaps	(29		)	(103		)	(26		)	(6		)	Other Income (Expense) - net
	(1		)	(1		)	—			—			Interest Expense
Total Pre-tax	(32		)	(106		)	(31		)	(9		)
Income Taxes	7			21			7			2
Total After-tax	(25		)	(85		)	(24		)	(7		)
Equity investees' AOCI	(1		)	1			(1		)	1			Other Income (Expense) - net
Total Pre-tax	(1		)	1			(1		)	1
Income Taxes	—			—			—			—
Total After-tax	(1		)	1			(1		)	1
Defined benefit plans
Prior service costs	(1		)	(1		)	(1		)	(1		)
Net actuarial loss	(40		)	(40		)	(81		)	(80		)
Total Pre-tax	(41		)	(41		)	(82		)	(81		)
Income Taxes	9			8			18			17
Total After-tax	(32		)	(33		)	(64		)	(64		)
Total reclassifications during the period	$	(58	)	$	(117	)	$	(89	)	$	(70	)

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, 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	)
March 31, 2016	$	(984	)	$	(5	)	$	—		$	(6	)	$	(2,164	)	$	(3,159	)
Amounts arising during the period	268			(85		)	—			—			2			185
Reclassifications from AOCI	—			85			(1		)	1			32			117
Net OCI during the period	268			—			(1		)	1			34			302
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
December 31, 2015	$	(520	)	$	(7	)	$	—		$	(6	)	$	(2,195	)	$	(2,728	)
Amounts arising during the period	(196		)	(5		)	—			—			2			(199		)
Reclassifications from AOCI	—			7			(1		)	1			63			70
Net OCI during the period	(196		)	2			(1		)	1			65			(129		)
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
LKE
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	)
March 31, 2016							$	—		$	(10	)	$	(35	)	$	(45	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							(1		)	1			1			1
Net OCI during the period							(1		)	1			2			2
June 30, 2016							$	(1	)	$	(9	)	$	(33	)	$	(43	)

	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, 2015			$	—		$	(10	)	$	(36	)	$	(46	)
Amounts arising during the period			—			—			1			1
Reclassifications from AOCI			(1		)	1			2			2
Net OCI during the period			(1		)	1			3			3
June 30, 2016			$	(1	)	$	(9	)	$	(33	)	$	(43	)

(PPL)

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

	Three Months						Six Months						Affected Line Item on the
Details about AOCI	2017			2016			2017			2016			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(5	)	$	(3	)	Interest Expense
Cross-currency swaps	(29		)	(103		)	(26		)	(6		)	Other Income (Expense) - net
	(1		)	(1		)	—			—			Interest Expense
Total Pre-tax	(32		)	(106		)	(31		)	(9		)
Income Taxes	7			21			7			2
Total After-tax	(25		)	(85		)	(24		)	(7		)
Equity investees' AOCI	(1		)	1			(1		)	1			Other Income (Expense) - net
Total Pre-tax	(1		)	1			(1		)	1
Income Taxes	—			—			—			—
Total After-tax	(1		)	1			(1		)	1
Defined benefit plans
Prior service costs	(1		)	(1		)	(1		)	(1		)
Net actuarial loss	(40		)	(40		)	(81		)	(80		)
Total Pre-tax	(41		)	(41		)	(82		)	(81		)
Income Taxes	9			8			18			17
Total After-tax	(32		)	(33		)	(64		)	(64		)
Total reclassifications during the period	$	(58	)	$	(117	)	$	(89	)	$	(70	)

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New Accounting Guidance Pending Adoption

6 Months Ended

Jun. 30, 2017

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 Revenue from Contracts with Customers

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

For public business entities, this guidance can be applied using either a full retrospective or modified retrospective transition method, beginning in annual reporting periods after December 15, 2017 and interim periods within those years. The Registrants will adopt this guidance effective January 1, 2018.

The Registrants have performed an assessment of a significant portion of their revenue under this new guidance to determine its effect on their current revenue recognition policies, and at this time they do not believe it will have a material impact. However, the Registrants will continue to monitor the development of industry specific application guidance which could have an impact on their assessments. The Registrants are currently assessing the disclosure requirements included in the standard, which will result in increased information being provided to enable the users of the financial statements to understand the nature, amount, timing and uncertainty of revenue arising from contracts with customers. The Registrants will determine the transition method they will apply after the industry specific application guidance is final and the implications of using either the full retrospective or modified retrospective transition methods are known.

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 lines.

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 companies for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted. The new standard must be adopted using a modified retrospective transition, and provides for certain practical expedients. Transition will require application of the new guidance at the beginning of the earliest comparative period presented.

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

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 in annual reporting periods beginning after December 15, 2018, including interim periods within those years.

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

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

In March 2017, the FASB issued accounting guidance that changes the income statement presentation of net periodic benefit cost. This new guidance requires the service cost component to be disaggregated from other components of net benefit cost and presented in the same income statement line items as other employee compensation costs arising from services rendered during the period. The other components of net periodic benefits will be presented separately from the line items that include the service cost and outside of any subtotal of operating income. Only the service cost component is eligible for capitalization.

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

The Registrants are currently assessing the impact of adopting this guidance and will adopt this guidance effective January 1, 2018.

(PPL, LKE, LG&E and KU)

Simplifying the Test for Goodwill Impairment

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

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

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

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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2017

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

Receivables, Policy

Accounts Receivable(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.

Fair Value Transfer, Policy

Transfers between levels are recognized at end-of-reporting-period values.

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.

PPL Electric Utilities Corp [Member]

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

Receivables, Policy

Accounts Receivable(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.

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Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2017

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
	2017			2016			2017			2016
Income Statement Data
Revenues from external customers
U.K. Regulated	$	502		$	563		$	1,070		$	1,158
Kentucky Regulated	723			721			1,532			1,547
Pennsylvania Regulated	500			495			1,073			1,080
Corporate and Other	—			6			1			11
Total	$	1,725		$	1,785		$	3,676		$	3,796
Net Income
U.K. Regulated (a)	$	148		$	345		$	434		$	634
Kentucky Regulated	79			76			174			188
Pennsylvania Regulated	77			78			156			172
Corporate and Other	(12		)	(16		)	(69		)	(30		)
Total	$	292		$	483		$	695		$	964

(a) Includes unrealized gains and losses from hedging foreign-currency related economic activity. See Note 13 for additional information.

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

	June 30, 2017			December 31, 2016
Balance Sheet Data
Assets
U.K. Regulated (a)	$	15,798		$	14,537
Kentucky Regulated	14,043			14,037
Pennsylvania Regulated	10,175			9,426
Corporate and Other (b)	(52		)	315
Total	$	39,964		$	38,315

(a) Includes $11.5 billion and $10.8 billion of net PP&E as of June 30, 2017 and December 31, 2016. 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 and the elimination of inter-segment transactions.

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2017

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
	2017		2016		2017		2016
Income (Numerator)
Net income	$	292	$	483	$	695	$	964
Less amounts allocated to participating securities	—		1		1		3
Net income available to PPL common shareowners - Basic and Diluted	$	292	$	482	$	694	$	961
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	683,841		677,145		682,370		676,293
Add incremental non-participating securities:
Share-based payment awards	2,510		3,584		2,355		3,480
Weighted-average shares - Diluted EPS	686,351		680,729		684,725		679,773
Basic EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.02	$	1.42
Diluted EPS
Net Income available to PPL common shareowners	$	0.43	$	0.71	$	1.01	$	1.41

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
	2017	2016	2017	2016
Stock-based compensation plans (a)	564	795	1,451	2,920
DRIP	369	370	814	772

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

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
	2017	2016	2017	2016
Stock options	696	696	696	696
Performance units	—	78	—	39

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2017

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
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	129		$	236		$	315		$	467
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	10			9			23			22
Valuation allowance adjustments	—			3			5			9
Impact of lower U.K. income tax rates	(40		)	(45		)	(88		)	(99		)
U.S. income tax on foreign earnings - net of foreign tax credit (a)	(7		)	—			(16		)	(2		)
Impact of the U.K. Finance Acts	(6		)	(2		)	(9		)	(2		)
Depreciation not normalized	(2		)	(3		)	(5		)	(4		)
Interest benefit on U.K. financing entities	(4		)	(4		)	(8		)	(9		)
Stock-based compensation	(4		)	(3		)	(7		)	(11		)
Other	—			1			(5		)	—
Total increase (decrease)	(53		)	(44		)	(110		)	(96		)
Total income taxes	$	76		$	192		$	205		$	371

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

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
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	44		$	44		$	88		$	97
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	9			8			17			18
Depreciation not normalized	(2		)	(2		)	(4		)	(3		)
Stock-based compensation	(3		)	(2		)	(5		)	(7		)
Other	(1		)	—			(1		)	(1		)
Total increase (decrease)	3			4			7			7
Total income taxes	$	47		$	48		$	95		$	104

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
	2017			2016			2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	49		$	47		$	107		$	114
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5			5			11			12
Other	(1		)	(1		)	(2		)	(3		)
Total increase (decrease)	4			4			9			9
Total income taxes	$	53		$	51		$	116		$	123

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
	2017		2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	24	$	22	$	55		$	54
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3		2		6			6
Other	—		—		(1		)	(1		)
Total increase (decrease)	3		2		5			5
Total income taxes	$	27	$	24	$	60		$	59

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
	2017			2016		2017			2016
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$	32		$	31	$	67		$	73
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	3			3		7			7
Other	(1		)	—		(1		)	—
Total increase (decrease)	2			3		6			7
Total income taxes	$	34		$	34	$	73		$	80

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Utility Rate Regulation (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	—	$	—
Generation formula rate	10		11		—		—
Transmission service charge	—		7		—		7
Gas supply clause	7		3		—		—
Smart meter rider	10		6		10		6
Storm costs	3		5		3		5
Other	1		1		1		1
Total current regulatory assets (a)	$	37	$	39	$	14	$	19
Noncurrent Regulatory Assets:
Defined benefit plans	$	920	$	947	$	537	$	549
Taxes recoverable through future rates	345		340		345		340
Storm costs	40		58		—		10
Unamortized loss on debt	57		61		32		36
Interest rate swaps	124		129		—		—
Accumulated cost of removal of utility plant	162		159		162		159
AROs	245		211		—		—
Other	13		13		—		—
Total noncurrent regulatory assets	$	1,906	$	1,918	$	1,076	$	1,094

	PPL				PPL Electric
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Generation supply charge	$	19	$	23	$	19	$	23
Transmission service charge	6		—		6		—
Universal service rider	14		14		14		14
Transmission formula rate	3		15		3		15
Fuel adjustment clause	13		11		—		—
Act 129 compliance rider	11		17		11		17
Storm damage expense	4		13		4		13
Other	1		8		—		1
Total current regulatory liabilities	$	71	$	101	$	57	$	83
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	—	$	—
Power purchase agreement - OVEC (b)	72		75		—		—
Net deferred tax assets	21		23		—		—
Defined benefit plans	27		23		—		—
Interest rate swaps	76		78		—		—
Other	3		—		—		—
Total noncurrent regulatory liabilities	$	902	$	899	$	—	$	—

	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Assets:
Environmental cost recovery	$	6	$	6	$	4	$	6	$	2	$	—
Generation formula rate	10		11		—		—		10		11
Gas supply clause	7		3		7		3		—		—
Total current regulatory assets	$	23	$	20	$	11	$	9	$	12	$	11
Noncurrent Regulatory Assets:
Defined benefit plans	$	383	$	398	$	238	$	246	$	145	$	152
Storm costs	40		48		22		26		18		22
Unamortized loss on debt	25		25		16		16		9		9
Interest rate swaps	124		129		85		88		39		41
AROs	245		211		84		70		161		141
Plant retirement costs	3		4		—		—		3		4
Other	10		9		4		4		6		5
Total noncurrent regulatory assets	$	830	$	824	$	449	$	450	$	381	$	374

	LKE				LG&E				KU
	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016
Current Regulatory Liabilities:
Demand side management	$	—	$	3	$	—	$	2	$	—	$	1
Fuel adjustment clause	13		11		4		2		9		9
Other	1		4		—		1		1		3
Total current regulatory liabilities	$	14	$	18	$	4	$	5	$	10	$	13
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	703	$	700	$	308	$	305	$	395	$	395
Power purchase agreement - OVEC (b)	72		75		50		52		22		23
Net deferred tax assets	21		23		21		23		—		—
Defined benefit plans	27		23		—		—		27		23
Interest rate swaps	76		78		38		39		38		39
Other	3		—		1		—		2		—
Total noncurrent regulatory liabilities	$	902	$	899	$	418	$	419	$	484	$	480

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

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

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Financing Activities (Tables)

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The following credit facilities were in place at: 

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2022	£	210	£	155	£	—	£	56	£	160	£	—
Term Loan Facility (b)	Dec. 2017	230		230		—		—		—		—
WPD (South West)
Syndicated Credit Facility (c)	July 2021	245		80		—		165		110		—
WPD (East Midlands)
Syndicated Credit Facility (d)	July 2021	300		116		—		184		9		—
WPD (West Midlands)
Syndicated Credit Facility	July 2021	300		—		—		300		—		—
Uncommitted Credit Facilities (e)		90		50		4		36		60		4
Total U.K. Credit Facilities (f)		£	1,375	£	631	£	4	£	741	£	339	£	4

	June 30, 2017									December 31, 2016
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
U.S.
PPL Capital Funding
Syndicated Credit Facility	Jan. 2022	$	950	$	—	$	424	$	526	$	—	$	20
Syndicated Credit Facility	Nov. 2018	300		—		—		300		—		—
Bilateral Credit Facility	Mar. 2018	150		—		17		133		—		17
Total PPL Capital Funding Credit Facilities		$	1,400	$	—	$	441	$	959	$	—	$	37
PPL Electric
Syndicated Credit Facility	Jan. 2022	$	650	$	—	$	1	$	649	$	—	$	296
LKE
Syndicated Credit Facility	Oct. 2018	$	75	$	—	$	—	$	75	$	—	$	—
LG&E
Syndicated Credit Facility	Jan. 2022	$	500	$	—	$	207	$	293	$	—	$	169
KU
Syndicated Credit Facility	Jan. 2022	$	400	$	—	$	51	$	349	$	—	$	16
Letter of Credit Facility	Oct. 2017	198		—		198		—		—		198
Total KU Credit Facilities		$	598	$	—	$	249	$	349	$	—	$	214

(a) The amounts borrowed at June 30, 2017 and December 31, 2016 were USD-denominated borrowings of $200 million for both periods, which bore interest at 1.87% and 1.43%. The unused capacity reflects the amount borrowed in GBP of £154 million as of the date borrowed.

(b) The amount borrowed at June 30, 2017 was a GBP-denominated borrowing which equated to $297 million and bore interest at 1.50%.

(c) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $103 million and $137 million and bore interest at 0.65% and 0.66%.

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

(e) The amounts borrowed at June 30, 2017 and December 31, 2016 were GBP-denominated borrowings which equated to $65 million and $75 million and bore interest at 1.07% and 1.26%.

(f) At June 30, 2017, the unused capacity under the U.K. credit facilities was $956 million.

Schedule of Short-term Debt

The following commercial paper programs were in place at: 

	June 30, 2017							December 31, 2016
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	1.46%	$	1,000	$	424	$	576	1.10%	$	20
PPL Electric		650		—		650		1.05%	295
LG&E	1.35%	350		207		143		0.94%	169
KU	1.40%	350		51		299		0.87%	16
Total		$	2,350	$	682	$	1,668		$	500

Schedule Of Stock Offering Program

For the periods ended June 30, PPL issued the following:

	Three Months				Six Months
	2017		2016		2017		2016
Number of shares (in thousands)	2,113		—		3,477		—
Average share price	$	39.15	$	—	$	38.17	$	—
Net Proceeds	$	82	$	—	$	132	$	—

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Defined Benefits (Tables)

6 Months Ended

Jun. 30, 2017

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 LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2017			2016			2017			2016			2017			2016			2017			2016
PPL
Service cost	$	15		$	16		$	18		$	18		$	32		$	33		$	37		$	36
Interest cost	42			44			44			62			84			87			87			124
Expected return on plan assets	(58		)	(58		)	(127		)	(132		)	(115		)	(114		)	(252		)	(265		)
Amortization of:
Prior service cost	3			3			—			—			5			4			—			—
Actuarial loss	14			10			36			36			34			25			71			73
Net periodic defined benefit costs (credits) before special termination benefits	16			15			(29		)	(16		)	40			35			(57		)	(32		)
Special termination benefits (a)	(1		)	—			—			—			1			—			—			—
Net periodic defined benefit costs (credits)	$	15		$	15		$	(29	)	$	(16	)	$	41		$	35		$	(57	)	$	(32	)

(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
	2017			2016			2017			2016
LKE
Service cost	$	5		$	6		$	12		$	12
Interest cost	18			18			34			35
Expected return on plan assets	(24		)	(24		)	(46		)	(45		)
Amortization of:
Prior service cost	2			3			4			4
Actuarial loss	4			5			15			10
Net periodic defined benefit costs	$	5		$	8		$	19		$	16

	Pension Benefits
	Three Months						Six Months
	2017			2016			2017			2016
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			4			$	6		$	7
Expected return on plan assets	(6		)	(5		)	(11		)	(10		)
Amortization of:
Prior service cost	1			1			2			2
Actuarial loss	1			1			4			3
Net periodic defined benefit costs	$	—		$	2		$	2		$	3

	Other Postretirement Benefits
	Three Months						Six Months
	2017			2016			2017			2016
PPL
Service cost	$	2		$	2		$	4		$	4
Interest cost	6			7			12			13
Expected return on plan assets	(5		)	(6		)	(11		)	(11		)
Amortization of prior service cost	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	2		$	3		$	4		$	6
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			3			4			5
Expected return on plan assets	(2		)	(1		)	(3		)	(3		)
Amortization of prior service cost	—			—			—			1
Net periodic defined benefit costs	$	1		$	3		$	3		$	5

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
	2017		2016		2017		2016
PPL Electric	$	5	$	5	$	13	$	11
LG&E	2		3		5		5
KU	1		3		5		6

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 LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2017			2016			2017			2016			2017			2016			2017			2016
PPL
Service cost	$	15		$	16		$	18		$	18		$	32		$	33		$	37		$	36
Interest cost	42			44			44			62			84			87			87			124
Expected return on plan assets	(58		)	(58		)	(127		)	(132		)	(115		)	(114		)	(252		)	(265		)
Amortization of:
Prior service cost	3			3			—			—			5			4			—			—
Actuarial loss	14			10			36			36			34			25			71			73
Net periodic defined benefit costs (credits) before special termination benefits	16			15			(29		)	(16		)	40			35			(57		)	(32		)
Special termination benefits (a)	(1		)	—			—			—			1			—			—			—
Net periodic defined benefit costs (credits)	$	15		$	15		$	(29	)	$	(16	)	$	41		$	35		$	(57	)	$	(32	)

(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
	2017			2016			2017			2016
LKE
Service cost	$	5		$	6		$	12		$	12
Interest cost	18			18			34			35
Expected return on plan assets	(24		)	(24		)	(46		)	(45		)
Amortization of:
Prior service cost	2			3			4			4
Actuarial loss	4			5			15			10
Net periodic defined benefit costs	$	5		$	8		$	19		$	16

	Pension Benefits
	Three Months						Six Months
	2017			2016			2017			2016
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			4			$	6		$	7
Expected return on plan assets	(6		)	(5		)	(11		)	(10		)
Amortization of:
Prior service cost	1			1			2			2
Actuarial loss	1			1			4			3
Net periodic defined benefit costs	$	—		$	2		$	2		$	3

	Other Postretirement Benefits
	Three Months						Six Months
	2017			2016			2017			2016
PPL
Service cost	$	2		$	2		$	4		$	4
Interest cost	6			7			12			13
Expected return on plan assets	(5		)	(6		)	(11		)	(11		)
Amortization of prior service cost	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	2		$	3		$	4		$	6
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			3			4			5
Expected return on plan assets	(2		)	(1		)	(3		)	(3		)
Amortization of prior service cost	—			—			—			1
Net periodic defined benefit costs	$	1		$	3		$	3		$	5

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 LG&E for the periods ended June 30:

	Pension Benefits
	Three Months												Six Months
	U.S.						U.K.						U.S.						U.K.
	2017			2016			2017			2016			2017			2016			2017			2016
PPL
Service cost	$	15		$	16		$	18		$	18		$	32		$	33		$	37		$	36
Interest cost	42			44			44			62			84			87			87			124
Expected return on plan assets	(58		)	(58		)	(127		)	(132		)	(115		)	(114		)	(252		)	(265		)
Amortization of:
Prior service cost	3			3			—			—			5			4			—			—
Actuarial loss	14			10			36			36			34			25			71			73
Net periodic defined benefit costs (credits) before special termination benefits	16			15			(29		)	(16		)	40			35			(57		)	(32		)
Special termination benefits (a)	(1		)	—			—			—			1			—			—			—
Net periodic defined benefit costs (credits)	$	15		$	15		$	(29	)	$	(16	)	$	41		$	35		$	(57	)	$	(32	)

(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
	2017			2016			2017			2016
LKE
Service cost	$	5		$	6		$	12		$	12
Interest cost	18			18			34			35
Expected return on plan assets	(24		)	(24		)	(46		)	(45		)
Amortization of:
Prior service cost	2			3			4			4
Actuarial loss	4			5			15			10
Net periodic defined benefit costs	$	5		$	8		$	19		$	16

	Pension Benefits
	Three Months						Six Months
	2017			2016			2017			2016
LG&E
Service cost	$	1		$	1		$	1		$	1
Interest cost	3			4			$	6		$	7
Expected return on plan assets	(6		)	(5		)	(11		)	(10		)
Amortization of:
Prior service cost	1			1			2			2
Actuarial loss	1			1			4			3
Net periodic defined benefit costs	$	—		$	2		$	2		$	3

	Other Postretirement Benefits
	Three Months						Six Months
	2017			2016			2017			2016
PPL
Service cost	$	2		$	2		$	4		$	4
Interest cost	6			7			12			13
Expected return on plan assets	(5		)	(6		)	(11		)	(11		)
Amortization of prior service cost	(1		)	—			(1		)	—
Net periodic defined benefit costs	$	2		$	3		$	4		$	6
LKE
Service cost	$	1		$	1		$	2		$	2
Interest cost	2			3			4			5
Expected return on plan assets	(2		)	(1		)	(3		)	(3		)
Amortization of prior service cost	—			—			—			1
Net periodic defined benefit costs	$	1		$	3		$	3		$	5

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
	2017		2016		2017		2016
PPL Electric	$	5	$	5	$	13	$	11
LG&E	2		3		5		5
KU	1		3		5		6

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
	2017		2016		2017		2016
PPL Electric	$	5	$	5	$	13	$	11
LG&E	2		3		5		5
KU	1		3		5		6

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Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Guarantees

The table below details guarantees provided as of June 30, 2017.

	Exposure at June 30, 2017			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2019
WPD guarantee of pension and other obligations of unconsolidated entities	92		(c)
PPL Electric
Guarantee of inventory value	15		(d)	2018
LKE
Indemnification of lease termination and other divestitures	301		(e)	2021 - 2023
LG&E and KU
LG&E and KU guarantee of shortfall related to OVEC			(f)

(a)

(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, 2017, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.

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

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

(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 $120 million at June 30, 2017, consisting of LG&E's share of $83 million and KU's share of $37 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LKE's, LG&E's and KU's 2016 Form 10-K for additional information on the OVEC power purchase contract. In connection with recent credit market related developments at OVEC or certain of its sponsors, such parties, including LG&E and KU, are analyzing certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including increased interest costs and accelerated maturities of OVEC's existing short and long-term debt. The ultimate outcome of these matters, including any potential impact on LG&E's and KU's obligations relating to OVEC debt under the power purchase contract cannot be predicted.

XML

Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2017

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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

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
	2017		2016		2017		2016
PPL Electric from PPL Services	$	44	$	28	$	95	$	65
LKE from PPL Services	5		4		11		9
PPL Electric from PPL EU Services	15		16		33		33
LG&E from LKS	38		41		82		88
KU from LKS	47		49		91		105

XML

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	467	$	467	$	—	$	—	$	341	$	341	$	—	$	—
Restricted cash and cash equivalents (a)	25		25		—		—		26		26		—		—
Price risk management assets (b):
Foreign currency contracts	156		—		156		—		211		—		211		—
Cross-currency swaps	158		—		158		—		188		—		188		—
Total price risk management assets	314		—		314		—		399		—		399		—
Total assets	$	806	$	492	$	314	$	—	$	766	$	367	$	399	$	—
Liabilities
Price risk management liabilities (b):
Interest rate swaps	$	31	$	—	$	31	$	—	$	31	$	—	$	31	$	—
Foreign currency contracts	104		—		104		—		27		—		27		—
Total price risk management liabilities	$	135	$	—	$	135	$	—	$	58	$	—	$	58	$	—
PPL Electric
Assets
Cash and cash equivalents	$	59	$	59	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	2		2		—		—		2		2		—		—
Total assets	$	61	$	61	$	—	$	—	$	15	$	15	$	—	$	—
LKE
Assets
Cash and cash equivalents	$	19	$	19	$	—	$	—	$	13	$	13	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	21	$	21	$	—	$	—	$	16	$	16	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
LG&E
Assets
Cash and cash equivalents	$	7	$	7	$	—	$	—	$	5	$	5	$	—	$	—
Cash collateral posted to counterparties (c)	2		2		—		—		3		3		—		—
Total assets	$	9	$	9	$	—	$	—	$	8	$	8	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—
Total price risk management liabilities	$	30	$	—	$	30	$	—	$	31	$	—	$	31	$	—

	June 30, 2017								December 31, 2016
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
KU
Assets
Cash and cash equivalents	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—
Total assets	$	12	$	12	$	—	$	—	$	7	$	7	$	—	$	—

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

(b) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

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

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, 2017				December 31, 2016
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	19,068	$	22,791	$	18,326	$	21,355
PPL Electric	3,298		3,705		2,831		3,148
LKE	5,067		5,535		5,065		5,439
LG&E	1,619		1,749		1,617		1,710
KU	2,327		2,572		2,327		2,514

(a) Amounts are net of debt issuance costs.

XML

Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017								December 31, 2016
	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)	$	—	$	1	$	—	$	5	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	28		—		—		—		32		—		—		—
Foreign currency contracts	—		—		41		60		—		—		31		21
Total current	28		1		41		65		32		—		31		25
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		25		—		—		—		27
Cross-currency swaps (b)	130		—		—		—		156		—		—		—
Foreign currency contracts	—		—		115		44		—		—		180		6
Total noncurrent	130		—		115		69		156		—		180		33
Total derivatives	$	158	$	1	$	156	$	134	$	188	$	—	$	211	$	58

(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, 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

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, 2016.

								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	$	(3	)	$	(21	)	Interest expense	$	(2	)	$	—	$	(3	)	$	—
Cross-currency swaps	(104		)	9			Interest expense	(1		)	—		—			—
							Other income (expense) - net	(103		)	—		(6		)	—
Total	$	(107	)	$	(12	)		$	(106	)	$	—	$	(9	)	$	—
Net Investment Hedges:
Foreign currency contracts	$	1		$	4

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	$	171		$	231
Interest rate swaps	Interest expense	(2		)	(4		)
	Total	$	169		$	227
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	$	(3	)	$	(9	)

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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

Credit Risk-Related Contingent Features

At June 30, 2017, 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	$	23	$	12	$	12
Aggregate fair value of collateral posted on these derivative instruments	2		2		2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	21		10		10

(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, 2017				December 31, 2016
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4
Total current	—		5		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		25		—		27
Total noncurrent	—		25		—		27
Total derivatives	$	—	$	30	$	—	$	31

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, 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

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, 2016. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(4	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(3	)	$	(9	)

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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

Credit Risk-Related Contingent Features

At June 30, 2017, 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	$	23	$	12	$	12
Aggregate fair value of collateral posted on these derivative instruments	2		2		2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	21		10		10

(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, 2017				December 31, 2016
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4
Total current	—		5		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		25		—		27
Total noncurrent	—		25		—		27
Total derivatives	$	—	$	30	$	—	$	31

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, 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

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, 2016. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Six Months
Interest rate swaps	Interest expense	$	(2	)	$	(4	)
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Six Months
Interest rate swaps	Regulatory assets - noncurrent	$	(3	)	$	(9	)

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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

Credit Risk-Related Contingent Features

At June 30, 2017, 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	$	23	$	12	$	12
Aggregate fair value of collateral posted on these derivative instruments	2		2		2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	21		10		10

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

Kentucky Utilities Co [Member]

Derivative Instruments And Hedging Activities [Line Items]

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, 2017
Treasury Derivatives
PPL	$	314	$	93	$	27	$	194	$	135	$	93	$	2	$	40
LKE	—		—		—		—		30		—		2		28
LG&E	—		—		—		—		30		—		2		28

December 31, 2016
Treasury Derivatives
PPL	$	399	$	27	$	19	$	353	$	58	$	27	$	3	$	28
LKE	—		—		—		—		31		—		3		28
LG&E	—		—		—		—		31		—		3		28

XML

Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2017

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, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

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, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

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, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

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, 2016	$	488		$	433		$	145		$	288
Accretion	11			10			4			6
Effect of foreign exchange rates	2			—			—			—
Changes in estimated timing or cost	(73		)	(66		)	(10		)	(56		)
Obligations settled	(12		)	(12		)	(7		)	(5		)
Balance at June 30, 2017	$	416		$	365		$	132		$	233

XML

Accumulated Other Comprehensive Income (Loss) (Tables)

6 Months Ended

Jun. 30, 2017

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, 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	)
March 31, 2016	$	(984	)	$	(5	)	$	—		$	(6	)	$	(2,164	)	$	(3,159	)
Amounts arising during the period	268			(85		)	—			—			2			185
Reclassifications from AOCI	—			85			(1		)	1			32			117
Net OCI during the period	268			—			(1		)	1			34			302
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
December 31, 2015	$	(520	)	$	(7	)	$	—		$	(6	)	$	(2,195	)	$	(2,728	)
Amounts arising during the period	(196		)	(5		)	—			—			2			(199		)
Reclassifications from AOCI	—			7			(1		)	1			63			70
Net OCI during the period	(196		)	2			(1		)	1			65			(129		)
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
LKE
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	)
March 31, 2016							$	—		$	(10	)	$	(35	)	$	(45	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							(1		)	1			1			1
Net OCI during the period							(1		)	1			2			2
June 30, 2016							$	(1	)	$	(9	)	$	(33	)	$	(43	)

	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, 2015			$	—		$	(10	)	$	(36	)	$	(46	)
Amounts arising during the period			—			—			1			1
Reclassifications from AOCI			(1		)	1			2			2
Net OCI during the period			(1		)	1			3			3
June 30, 2016			$	(1	)	$	(9	)	$	(33	)	$	(43	)

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	2017			2016			2017			2016			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(5	)	$	(3	)	Interest Expense
Cross-currency swaps	(29		)	(103		)	(26		)	(6		)	Other Income (Expense) - net
	(1		)	(1		)	—			—			Interest Expense
Total Pre-tax	(32		)	(106		)	(31		)	(9		)
Income Taxes	7			21			7			2
Total After-tax	(25		)	(85		)	(24		)	(7		)
Equity investees' AOCI	(1		)	1			(1		)	1			Other Income (Expense) - net
Total Pre-tax	(1		)	1			(1		)	1
Income Taxes	—			—			—			—
Total After-tax	(1		)	1			(1		)	1
Defined benefit plans
Prior service costs	(1		)	(1		)	(1		)	(1		)
Net actuarial loss	(40		)	(40		)	(81		)	(80		)
Total Pre-tax	(41		)	(41		)	(82		)	(81		)
Income Taxes	9			8			18			17
Total After-tax	(32		)	(33		)	(64		)	(64		)
Total reclassifications during the period	$	(58	)	$	(117	)	$	(89	)	$	(70	)

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.

	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, 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	)
March 31, 2016	$	(984	)	$	(5	)	$	—		$	(6	)	$	(2,164	)	$	(3,159	)
Amounts arising during the period	268			(85		)	—			—			2			185
Reclassifications from AOCI	—			85			(1		)	1			32			117
Net OCI during the period	268			—			(1		)	1			34			302
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
December 31, 2015	$	(520	)	$	(7	)	$	—		$	(6	)	$	(2,195	)	$	(2,728	)
Amounts arising during the period	(196		)	(5		)	—			—			2			(199		)
Reclassifications from AOCI	—			7			(1		)	1			63			70
Net OCI during the period	(196		)	2			(1		)	1			65			(129		)
June 30, 2016	$	(716	)	$	(5	)	$	(1	)	$	(5	)	$	(2,130	)	$	(2,857	)
LKE
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	)
March 31, 2016							$	—		$	(10	)	$	(35	)	$	(45	)
Amounts arising during the period							—			—			1			1
Reclassifications from AOCI							(1		)	1			1			1
Net OCI during the period							(1		)	1			2			2
June 30, 2016							$	(1	)	$	(9	)	$	(33	)	$	(43	)

	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, 2015			$	—		$	(10	)	$	(36	)	$	(46	)
Amounts arising during the period			—			—			1			1
Reclassifications from AOCI			(1		)	1			2			2
Net OCI during the period			(1		)	1			3			3
June 30, 2016			$	(1	)	$	(9	)	$	(33	)	$	(43	)

XML

Summary of Significant Accounting Policies (Details) - Alternative Electricity Suppliers [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable	$ 288	$ 297	$ 644	$ 679
PPL Electric Utilities Corp [Member]
Accounts Receivable (Numeric) [Abstract]
Purchases of accounts receivable	$ 288	$ 297	$ 644	$ 679

XML

Segment and Related Information (Details) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($) Integer	Jun. 30, 2016 USD ($)	Dec. 31, 2016 USD ($)
Income Statement Data [Abstract]
Revenues from external customers		$ 1,725	$ 1,785	$ 3,676	$ 3,796
Net Income		292	483	695	964
Balance Sheet Data [Abstract]
Assets		39,964		39,964		$ 38,315
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Revenues from external customers		500	495	1,073	1,080
Net Income	[1]	77	79	156	173
Balance Sheet Data [Abstract]
Assets		10,175		$ 10,175		9,426
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]
Revenues from external customers		723	721	$ 1,532	1,547
Net Income		87	84	190	204
Balance Sheet Data [Abstract]
Assets		14,377		$ 14,377		14,371
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]
Revenues from external customers		324	323	$ 715	709
Net Income	[1]	42	40	96	96
Balance Sheet Data [Abstract]
Assets		6,294		$ 6,294		6,300
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Revenues from external customers		406	407	$ 843	860
Net Income	[2]	56	54	119	129
Balance Sheet Data [Abstract]
Assets		8,086		$ 8,086		8,085
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer				1
Number of Operating Segments | Integer				1
United Kingdom Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		502	563	$ 1,070	1,158
Net Income		148	345	434	634
Balance Sheet Data [Abstract]
Assets		15,798		15,798		14,537
Segment (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		11,500		11,500		10,800
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		723	721	1,532	1,547
Net Income		79	76	174	188
Balance Sheet Data [Abstract]
Assets		14,043		14,043		14,037
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Revenues from external customers		500	495	1,073	1,080
Net Income		77	78	156	172
Balance Sheet Data [Abstract]
Assets		10,175		10,175		9,426
Corporate And Other [Member]
Income Statement Data [Abstract]
Revenues from external customers		0	6	1	11
Net Income		(12)	$ (16)	(69)	$ (30)
Balance Sheet Data [Abstract]
Assets		$ (52)		$ (52)		$ 315

[1] Net income equals comprehensive income.

[2] Net income approximates comprehensive income.

XML

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income (Numerator) [Abstract]
Net Income	$ 292	$ 483	$ 695	$ 964
Less amounts allocated to participating securities	0	1	1	3
Net income available to PPL common shareowners - Basic	292	482	694	961
Net income available to PPL common shareowners - Diluted	$ 292	$ 482	$ 694	$ 961
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	683,841	677,145	682,370	676,293
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	2,510	3,584	2,355	3,480
Weighted-average shares - Diluted EPS (in shares)	686,351	680,729	684,725	679,773
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.43	$ 0.71	$ 1.02	$ 1.42
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.43	$ 0.71	$ 1.01	$ 1.41
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	564	795	1,451	2,920
Common stock issued under dividend reinvestment plan (in shares)	369	370	814	772
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	696	696	696	696
Performance units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	78	0	39

XML

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 129	$ 236	$ 315	$ 467
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 10	$ 9	$ 23	$ 22
Valuation allowance adjustments	0	3	5	9
Impact of lower U.K. income tax rates	(40)	(45)	(88)	(99)
U.S. income tax on foreign earnings - net of foreign tax credit	(7)	0	(16)	(2)
Impact of the U.K. Finance Acts	(6)	(2)	(9)	(2)
Depreciation not normalized	(2)	(3)	(5)	(4)
Interest benefit on U.K. financing entities	(4)	(4)	(8)	(9)
Stock-based compensation	(4)	(3)	(7)	(11)
Other	0	1	(5)	0
Total increase (decrease)	(53)	(44)	(110)	(96)
Total income taxes	76	192	205	371
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 44	$ 44	$ 88	$ 97
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 9	$ 8	$ 17	$ 18
Depreciation not normalized	(2)	(2)	(4)	(3)
Stock-based compensation	(3)	(2)	(5)	(7)
Other	(1)	0	(1)	(1)
Total increase (decrease)	3	4	7	7
Total income taxes	47	48	95	104
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 - 35%	$ 49	$ 47	$ 107	$ 114
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 5	$ 5	$ 11	$ 12
Other	(1)	(1)	(2)	(3)
Total increase (decrease)	4	4	9	9
Total income taxes	53	51	116	123
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 24	$ 22	$ 55	$ 54
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 3	$ 2	$ 6	$ 6
Other	0	0	(1)	(1)
Total increase (decrease)	3	2	5	5
Total income taxes	27	24	60	59
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate - 35%	$ 32	$ 31	$ 67	$ 73
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	$ 3	$ 3	$ 7	$ 7
Other	(1)	0	(1)	0
Total increase (decrease)	2	3	6	7
Total income taxes	$ 34	$ 34	$ 73	$ 80

XML

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Current regulatory assets	$ 37	$ 39
Noncurrent regulatory assets	1,906	1,918
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	7
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	6
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	920	947
Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	345	340
Storm Costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	5
Noncurrent regulatory assets	40	58
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	57	61
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	124	129
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	162	159
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	245	211
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	13	13
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	14	19
Noncurrent regulatory assets	1,076	1,094
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] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	7
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	6
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	537	549
PPL Electric Utilities Corp [Member] | Taxes Recoverable Through Future Rates [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	345	340
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	5
Noncurrent regulatory assets	0	10
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	32	36
PPL Electric Utilities Corp [Member] | 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	162	159
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent 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	23	20
Noncurrent regulatory assets	830	824
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
LG And E And KU Energy LLC [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	383	398
LG And E And KU Energy LLC [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	40	48
LG And E And KU Energy LLC [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	25	25
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	124	129
LG And E And KU Energy LLC [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	245	211
LG And E And KU Energy LLC [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	4
LG And E And KU Energy LLC [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	10	9
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	11	9
Noncurrent regulatory assets	449	450
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	6
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] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	238	246
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	26
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	16	16
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	85	88
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	84	70
Louisville Gas And Electric Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	4	4
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	12	11
Noncurrent regulatory assets	381	374
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Current regulatory assets	2	0
Kentucky Utilities Co [Member] | Generation Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	11
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	145	152
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	18	22
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	39	41
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	161	141
Kentucky Utilities Co [Member] | Plant Retirement Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	4
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 6	$ 5

XML

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 71	$ 101
Noncurrent regulatory liabilities	902	899
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	19	23
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	14
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	15
Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	13	11
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	17
Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	13
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	703	700
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	75
Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	76	78
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	8
Noncurrent regulatory liabilities	3	0
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	57	83
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	19	23
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	14
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	15
PPL Electric Utilities Corp [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	17
PPL Electric Utilities Corp [Member] | Storm Damage Expense [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	13
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 Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Noncurrent regulatory liabilities	0	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	18
Noncurrent regulatory liabilities	902	899
LG And E And KU Energy LLC [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	3
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	13	11
LG And E And KU Energy LLC [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	703	700
LG And E And KU Energy LLC [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	72	75
LG And E And KU Energy LLC [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
LG And E And KU Energy LLC [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	76	78
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	4
Noncurrent regulatory liabilities	3	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	5
Noncurrent regulatory liabilities	418	419
Louisville Gas And Electric Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	2
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	2
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	308	305
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	50	52
Louisville Gas And Electric Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	23
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] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	38	39
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Noncurrent regulatory liabilities	1	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	10	13
Noncurrent regulatory liabilities	484	480
Kentucky Utilities Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	9	9
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	395	395
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	22	23
Kentucky Utilities Co [Member] | Net Deferred Tax Assets [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	23
Kentucky Utilities Co [Member] | Interest Rate Swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	38	39
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	3
Noncurrent regulatory liabilities	$ 2	$ 0

XML

Utility Rate Regulation - Regulatory Matters (Details) - USD ($) $ in Millions				1 Months Ended
	Jun. 29, 2017	Jun. 23, 2017	Apr. 19, 2017	Aug. 31, 2016
LKE [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 15
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
LGE [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 4
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
KU [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 11
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 15
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]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
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%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 59
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 57
Public Utilities, Approved Rate Increase (Decrease), Percentage	5.20%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 8
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 7
Public Utilities, Approved Rate Increase (Decrease), Percentage	2.10%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 4
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Return on Equity Increase (Decrease), Percentage			9.75%
Public Utilities, Approved Return on Equity, Percentage	9.70%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Proposed Rate Increase (Decrease), Amount			$ 55
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 52
Public Utilities, Approved Rate Increase (Decrease), Percentage	3.20%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Depreciation Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Depreciation Rate Increase (Decrease), Amount	$ 11
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity All Existing Approved Environmental Cost Recovery Plans And Projects Increase (Decrease), Percentage		9.70%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery All Other Projects, Percentage		10.00%
Public Utilities, Prior Approved Return on Equity Approved Environmental Cost Recovery CCRs, Percentage		9.80%

XML

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	1 Months Ended	6 Months Ended
	Aug. 31, 2017	Jun. 30, 2017 USD ($)	Jun. 30, 2017 GBP (£)	Dec. 31, 2016 USD ($)	Dec. 31, 2016 GBP (£)
UNITED KINGDOM
Line of Credit Facility [Line Items]
Capacity | £			£ 1,375
Borrowed | £			631		£ 339
Letters of Credit and Commercial Paper Issued | £			4		4
Unused Capacity		$ 956	741
UNITED KINGDOM | Uncommitted Credit Facilities [Member]
Line of Credit Facility [Line Items]
Capacity | £			90
Borrowed		$ 65	50	$ 75	60
Letters of Credit and Commercial Paper Issued | £			4		£ 4
Unused Capacity | £			£ 36
Interest rate on outstanding borrowing		1.07%	1.07%	1.26%	1.26%
WPD PLC [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 13, 2022
Capacity | £			£ 210
Borrowed		$ 200	155	$ 200	£ 160
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 56
Interest rate on outstanding borrowing		1.87%	1.87%	1.43%	1.43%
Borrowed | £			£ 154
WPD PLC [Member] | UNITED KINGDOM | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Dec. 28, 2017
Capacity | £			230
Borrowed		$ 297	230		£ 0
Letters of Credit and Commercial Paper Issued | £			0		0
Unused Capacity | £			£ 0
Interest rate on outstanding borrowing		1.50%	1.50%
WPD South West [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 245
Borrowed		$ 103	80	$ 137	110
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 165
Interest rate on outstanding borrowing		0.65%	0.65%	0.66%	0.66%
WPD East Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 300
Borrowed		$ 150	116	$ 11	£ 9
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 184
Interest rate on outstanding borrowing		0.65%	0.65%	0.66%	0.66%
WPD West Midlands [Member] | UNITED KINGDOM | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jul. 29, 2021
Capacity | £			£ 300
Borrowed | £			0		£ 0
Letters of Credit and Commercial Paper Issued | £			0		£ 0
Unused Capacity | £			£ 300
PPL Capital Funding [Member] | UNITED STATES
Line of Credit Facility [Line Items]
Capacity		$ 1,400
Borrowed		0		$ 0
Letters of Credit and Commercial Paper Issued		441		37
Unused Capacity		$ 959
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 950
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		424		20
Unused Capacity		$ 526
PPL Capital Funding [Member] | UNITED STATES | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Nov. 12, 2018
Capacity		$ 300
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		0		0
Unused Capacity		$ 300
PPL Capital Funding [Member] | UNITED STATES | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Mar. 16, 2018
Capacity		$ 150
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		17		17
Unused Capacity		$ 133
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 650
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		1		296
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] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
KU [Member]
Line of Credit Facility [Line Items]
Capacity		598
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		249		214
Unused Capacity		$ 349
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 01, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		198
Unused Capacity		$ 0
KU [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 01, 2020
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 27, 2022
Capacity		$ 650
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		1		296
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] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
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		249		214
Unused Capacity		$ 349
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 01, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		198
Unused Capacity		$ 0
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 01, 2020
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 500
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		207		169
Unused Capacity		293
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity		598
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		249		214
Unused Capacity		$ 349
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Jan. 31, 2022
Capacity		$ 400
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		51		16
Unused Capacity		$ 349
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Line of Credit Facility [Line Items]
Expiration Date		Oct. 01, 2017
Capacity		$ 198
Borrowed		0		0
Letters of Credit and Commercial Paper Issued		198		$ 198
Unused Capacity		$ 0
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Expiration Date	Oct. 01, 2020

XML

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Capacity	$ 2,350
Commercial Paper Issuances	682	$ 500
Unused Capacity	$ 1,668
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.46%	1.10%
Capacity	$ 1,000
Commercial Paper Issuances	424	$ 20
Unused Capacity	$ 576
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		1.05%
Capacity	$ 650
Commercial Paper Issuances	0	$ 295
Unused Capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		1.05%
Capacity	$ 650
Commercial Paper Issuances	0	$ 295
Unused Capacity	$ 650
LG And E And KU Energy LLC [Member] | LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.35%	0.94%
Capacity	$ 350
Commercial Paper Issuances	207	$ 169
Unused Capacity	$ 143
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	1.40%	0.87%
Capacity	$ 350
Commercial Paper Issuances	51	$ 16
Unused Capacity	$ 299

XML

Financing Activities - Long-term Debt and ATM Program (Details) $ / shares in Units, shares in Thousands, £ in Millions, $ in Millions	1 Months Ended						3 Months Ended		6 Months Ended
	Jun. 30, 2017 USD ($)	May 31, 2017 USD ($)	Apr. 30, 2017 USD ($)	Mar. 31, 2017 USD ($)	Mar. 31, 2017 GBP (£)	Feb. 28, 2015 USD ($) Integer	Jun. 30, 2017 USD ($) $ / shares shares	Jun. 30, 2016 USD ($) $ / shares shares	Jun. 30, 2017 USD ($) $ / shares shares	Jun. 30, 2016 USD ($) $ / shares shares
At-the-Market Stock Offering Program (Numeric) [Abstract]
Net proceeds from issuance of common stock									$ 177	$ 76
WPD South Wales PLC [Member] | Index Linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £					£ 50
Stated interest rate					0.01%
Proceeds from debt, net of issuance costs | £					£ 53
Maturity date				Mar. 14, 2029	Mar. 14, 2029
Proceeds from debt, including premium net of debt issuance costs				$ 64
PPL Electric [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 475
Stated interest rate		3.95%
Proceeds from debt, net of issuance costs		$ 466
Maturity date		Jun. 01, 2047
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 01, 2027
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 01, 2033
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 01, 2033
Repurchase date of debt instruments			Apr. 01, 2019
PPL Electric Utilities Corp [Member] | First Mortgage [Member] | Mortgage Indenture 2001 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 475
Stated interest rate		3.95%
Proceeds from debt, net of issuance costs		$ 466
Maturity date		Jun. 01, 2047
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 01, 2027
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 01, 2033
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
Louisville Gas And Electric Co [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 01, 2033
Repurchase date of debt instruments			Apr. 01, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2017 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Stated interest rate	3.75%						3.75%		3.75%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 01, 2027
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 60						$ 60		$ 60
Maturity date	Jun. 01, 2033
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 31						$ 31		$ 31
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Environmental Facilities Revenue Refunding Bonds 2007 Series B [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 35						$ 35		$ 35
Stated interest rate	1.25%						1.25%		1.25%
Maturity date	Jun. 01, 2033
Repurchase date of debt instruments	Jun. 03, 2019
LG And E And KU Energy LLC [Member] | Louisville Gas And Electric Company [Member] | Senior Debt Obligations [Member] | Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 128
Stated interest rate			1.50%
Maturity date			Oct. 01, 2033
Repurchase date of debt instruments			Apr. 01, 2019
At The Market Stock Offering Program [Member]
Equity Programs [Line Items]
Stock Issued During Period, Shares, New Issues | shares							2,113	0	3,477	0
At-the-Market Stock Offering Program (Numeric) [Abstract]
Number of distribution agreements | Integer						2
Aggregate sales price of common stock based on two separate equity distribution agreements						$ 500
Average share price | $ / shares							$ 39.15	$ 0.00	$ 38.17	$ 0.00
Net proceeds from issuance of common stock							$ 82	$ 0	$ 132	$ 0

XML

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Distributions (Numeric) [Abstract]
Dividend payable date of quarterly common stock dividend	Jul. 03, 2017
Current quarterly common stock dividend (in dollars per share)	$ 0.395	$ 0.3950	$ 0.38	$ 0.79	$ 0.76
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.58

XML

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	$ 15	$ 16	$ 32	$ 33
Interest cost	42	44	84	87
Expected return on plan assets	(58)	(58)	(115)	(114)
Amortization of: [Abstract]
Prior service cost	3	3	5	4
Actuarial loss	14	10	34	25
Net periodic defined benefit costs (credits) before special termination benefits	16	15	40	35
Special termination benefits	(1)	0	1	0
Net periodic defined benefit costs (credits)	15	15	41	35
Pension Benefits United Kingdom [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	18	18	37	36
Interest cost	44	62	87	124
Expected return on plan assets	(127)	(132)	(252)	(265)
Amortization of: [Abstract]
Prior service cost	0	0	0	0
Actuarial loss	36	36	71	73
Net periodic defined benefit costs (credits) before special termination benefits	(29)	(16)	(57)	(32)
Special termination benefits	0	0	0	0
Net periodic defined benefit costs (credits)	(29)	(16)	(57)	(32)
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Employer contributions			485
Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	2	2	4	4
Interest cost	6	7	12	13
Expected return on plan assets	(5)	(6)	(11)	(11)
Amortization of: [Abstract]
Prior service cost	(1)	0	(1)	0
Net periodic defined benefit costs (credits)	2	3	4	6
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	5	5	13	11
LG And E And KU Energy LLC [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	5	6	12	12
Interest cost	18	18	34	35
Expected return on plan assets	(24)	(24)	(46)	(45)
Amortization of: [Abstract]
Prior service cost	2	3	4	4
Actuarial loss	4	5	15	10
Net periodic defined benefit costs (credits)	5	8	19	16
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	2	2
Interest cost	2	3	4	5
Expected return on plan assets	(2)	(1)	(3)	(3)
Amortization of: [Abstract]
Prior service cost	0	0	0	1
Net periodic defined benefit costs (credits)	1	3	3	5
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	3	5	5
Louisville Gas And Electric Co [Member] | Pension Benefits United States [Member]
Net Periodic Defined Benefit Costs (Credits) (Details) [Abstract]
Service cost	1	1	1	1
Interest cost	3	4	6	7
Expected return on plan assets	(6)	(5)	(11)	(10)
Amortization of: [Abstract]
Prior service cost	1	1	2	2
Actuarial loss	1	1	4	3
Net periodic defined benefit costs (credits)	0	2	2	3
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	$ 3	$ 5	$ 6

XML

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details)	6 Months Ended
	Jun. 30, 2017 coal-fired_unit resident claim 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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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	1
Additional generating units retired at the Cane Run plant | coal-fired_unit	2
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	1 Months Ended
	Aug. 31, 2017 employees	Mar. 31, 2017 employees	Jun. 30, 2017 USD ($)	Dec. 31, 2016 USD ($)
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term		5 years
Number Of Union Employees		1,400
PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $			$ 10	$ 10
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term		5 years
Number Of Union Employees		1,400
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund and Other Remediation (Numeric) [Abstract]
Environmental site accrual | $			$ 10	$ 10
LG And E And KU Energy LLC [Member] | KU [Member] | Subsequent Event [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees	53
Collective Bargaining Expiration Date	2020-08
Kentucky Utilities Co [Member] | Subsequent Event [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Number Of Union Employees	53
Collective Bargaining Expiration Date	2020-08

XML

Commitments and Contingencies - Guarantees and Other Assurances (Details) - USD ($)
$ in Millions

6 Months Ended

Jun. 30, 2017

Dec. 31, 2016

Guarantor Obligations [Line Items]

Recorded liability for all guarantees

$ 22

$ 22

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 inestimable

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

2019

PPL Guarantee [Member] | Financial Guarantee [Member] | WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]

Guarantor Obligations [Line Items]

Maximum exposure

$ 92

PPL Electric Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]

Guarantor Obligations [Line Items]

Maximum exposure

$ 15

Expiration date

2018

LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]

Guarantor Obligations [Line Items]

Maximum exposure

$ 301

Term of guarantee (in years)

12

Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues

$ 200

Maximum exposure of other indemnifications related to the purchase price of excess power

$ 100

LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Minimum [Member]

Guarantor Obligations [Line Items]

Expiration date

2021

LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Maximum [Member]

Guarantor Obligations [Line Items]

Expiration date

2023

LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Guarantor Obligations [Line Items]

Maximum exposure inestimable

The maximum exposure and the expiration date of these potential obligations are not presently determinable.

Contingent proportionate share of OVEC's outstanding debt

$ 120

PPL Electric Utilities Corp [Member] | Indemnification Guarantee [Member] | Guarantee Of Inventory Value [Member]

Guarantor Obligations [Line Items]

Maximum exposure

$ 15

Expiration date

2018

LG And E And KU Energy LLC [Member]

Guarantor Obligations [Line Items]

Recorded liability for all guarantees

$ 17

$ 17

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

$ 301

Term of guarantee (in years)

12

Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues

$ 200

Maximum exposure of other indemnifications related to the purchase price of excess power

$ 100

LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Minimum [Member]

Guarantor Obligations [Line Items]

Expiration date

2021

LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member] | Maximum [Member]

Guarantor Obligations [Line Items]

Expiration date

2023

LG And E And KU Energy LLC [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Guarantor Obligations [Line Items]

Maximum exposure inestimable

The maximum exposure and the expiration date of these potential obligations are not presently determinable.

Contingent proportionate share of OVEC's outstanding debt

$ 120

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 inestimable

The maximum exposure and the expiration date of these potential obligations are not presently determinable.

Contingent proportionate share of OVEC's outstanding debt

$ 83

Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]

Guarantor Obligations [Line Items]

Maximum exposure inestimable

The maximum exposure and the expiration date of these potential obligations are not presently determinable.

Contingent proportionate share of OVEC's outstanding debt

$ 37

XML

Related Party Transactions (Details) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes receivable from affiliate	$ 270,000,000		$ 270,000,000		$ 0
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	44,000,000	$ 28,000,000	95,000,000	$ 65,000,000
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	15,000,000	16,000,000	$ 33,000,000	33,000,000
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing			2.81%
Notes receivable from affiliate	270,000,000		$ 270,000,000		0
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	159,000,000		159,000,000		163,000,000
Long-term debt to affiliate	400,000,000		400,000,000		400,000,000
Interest Expense with Affiliate	4,000,000	4,000,000	8,000,000	8,000,000
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Support cost allocations from subsidiary of parent to registrant	5,000,000	4,000,000	11,000,000	9,000,000
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	225,000,000		$ 225,000,000		$ 225,000,000
Intercompany borrowings demand note rate on outstanding borrowing			2.56%		2.12%
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					$ 400,000,000
Interest rate on ten-year note					3.50%
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	$ 400,000,000		$ 400,000,000
Interest rate on ten-year note	3.50%		3.50%
Louisville Gas And Electric Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	$ 38,000,000	41,000,000	$ 82,000,000	88,000,000
Kentucky Utilities Co [Member] | LKS [Member]
Intercompany Billings by LKS (Details) [Abstract]
Intercompany billings between affiliates	$ 47,000,000	$ 49,000,000	$ 91,000,000	$ 105,000,000

XML

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents	$ 467	$ 341
Restricted cash and cash equivalents	25	26
Price risk management assets:
Foreign currency contracts	156	211
Cross-currency swaps	158	188
Total price risk management assets	314	399
Total assets	806	766
Price risk management liabilities:
Interest rate swaps	31	31
Foreign currency contracts	104	27
Total price risk management liabilities	135	58
Level 1 [Member]
Assets
Cash and cash equivalents	467	341
Restricted cash and cash equivalents	25	26
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total assets	492	367
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
Price risk management assets:
Foreign currency contracts	156	211
Cross-currency swaps	158	188
Total price risk management assets	314	399
Total assets	314	399
Price risk management liabilities:
Interest rate swaps	31	31
Foreign currency contracts	104	27
Total price risk management liabilities	135	58
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	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	59	13
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	61	15
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	59	13
Restricted cash and cash equivalents	2	2
Price risk management assets:
Total assets	61	15
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	19	13
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	21	16
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	19	13
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	21	16
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
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
LG And E And KU Energy LLC [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Cash collateral posted to counterparties	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	7	5
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	9	8
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	7	5
Cash collateral posted to counterparties	2	3
Price risk management assets:
Total assets	9	8
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
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	30	31
Total price risk management liabilities	30	31
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Cash collateral posted to counterparties	0	0
Price risk management assets:
Total assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	12	7
Price risk management assets:
Total assets	12	7
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	12	7
Price risk management assets:
Total assets	12	7
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, 2017	Dec. 31, 2016
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 19,068	$ 18,326
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	22,791	21,355
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,298	2,831
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	3,705	3,148
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	5,067	5,065
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	5,535	5,439
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,619	1,617
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	1,749	1,710
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	2,327	2,327
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Long-term debt	$ 2,572	$ 2,514

XML

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 27	$ 19
Cash collateral posted under master netting arrangements	2	3
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	2	3
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	$ 2	$ 3

XML

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) £ in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 GBP (£)
Cash Flow Hedges [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, 2017, PPL had an insignificant amount of cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net		$ 0		$ 0
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
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swap Contracts [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Notional amount	$ 802		$ 802
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Earliest maturity date of cross-currency cash flow hedge contracts			2017
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 And Foreign Currency Risk [Line Items]
Notional amount	187		$ 187		£ 145
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Maturity date of interest rate swap cash flow hedge contracts			2027
Mandatory Redemption Date of Interest Rate Swap Cash Flow Hedge			Nov. 30, 2017
Gain (Loss) on Interest Rate Cash Flow Hedge Ineffectiveness	0		$ 0
Interest Rate Cash Flow Hedge Ineffectiveness is Immaterial			For the three and six months ended June 30, 2016, PPL had an insignificant amount of hedge ineffectiveness associated with interest rate derivatives.
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			$ 21	$ 21
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
Economic Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity	3,700		$ 3,700		£ 2,800
Earliest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			July 2017
Latest termination date of foreign currency contracts for anticipated earnings hedges classified as economic activity			December 2019
LG And E And KU Energy LLC [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

XML

Derivative Instruments and Hedging Activities - Fair Values (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 158	$ 188
Liability value	1	0
Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	28	32
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	28	32
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	130	156
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	130	156
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	1	0
Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	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	156	211
Liability value	134	58
Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	41	31
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	41	31
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	115	180
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	115	180
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	65	25
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	5	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	60	21
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	69	33
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	25	27
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	44	6
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	30	31
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	5	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	5	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	25	27
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	25	27
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	30	31
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	5	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	5	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	25	27
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	$ 25	$ 27

XML

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Cash Flow Hedges [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income (Effective Portion)	$ (32)	$ (106)	$ (30)	$ (9)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	(1)	0
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)	(29)	(107)	(37)	(12)
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)	(2)	(3)	(2)	(21)
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)	(3)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	(1)	0
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)	(27)	(104)	(35)	9
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)	(1)	0	0
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion and Amount Excluded from Effectiveness Testing)	0	0	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)	(29)	(103)	(26)	(6)
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)	0	1	0	4
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(114)	169	(159)	227
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	(113)	171	(156)	231
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)	(3)	1	(9)
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	(1)	(2)	(3)	(4)
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)	(3)	1	(9)
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	(1)	(2)	(3)	(4)
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)	(3)	1	(9)
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	$ (1)	$ (2)	$ (3)	$ (4)

XML

Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$ 23
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	21
Treasury Derivatives [Member]
Assets [Abstract]
Gross	314	$ 399
Derivative instruments - eligible for offset	93	27
Cash collateral received - eligible for offset	27	19
Net	194	353
Liabilities [Abstract]
Gross	135	58
Derivative instruments - eligible for offset	93	27
Cash collateral pledged - eligible for offset	2	3
Net	40	28
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	12
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	10
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	30	31
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	2	3
Net	28	28
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	12
Aggregate fair value of collateral posted on these derivative instruments	2
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	10
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	30	31
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	2	3
Net	$ 28	$ 28

XML

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2017
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 488
Accretion		11
Effect of foreign exchange rates		2
Changes in estimated timing or cost		(73)
Obligations settled		(12)
Balance at End of Period	$ 416	$ 416
Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 433
Accretion		10
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(66)
Obligations settled		(12)
Balance at End of Period	365	365
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	(66)	$ (66)
LG And E And KU Energy LLC [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
LG And E And KU Energy LLC [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 145
Accretion		4
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(10)
Obligations settled		(7)
Balance at End of Period	132	132
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	(56)	$ (10)
Louisville Gas And Electric Co [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Louisville Gas And Electric Co [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period		$ 288
Accretion		6
Effect of foreign exchange rates		0
Changes in estimated timing or cost		(56)
Obligations settled		(5)
Balance at End of Period	233	233
Increase (Decrease) to the asset retirement obligations due to revisions in the amounts and timing of future expected costs related to the closure of CCR impoundments	$ (10)	$ (56)
Kentucky Utilities Co [Member] | Minimum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		10 years
Kentucky Utilities Co [Member] | Maximum [Member]
Asset Retirement Obligation [Roll Forward]
Regulatory Asset Amortization Period		25 years

XML

Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (3,777)	$ (3,159)	$ (3,778)	$ (2,728)
Amounts arising during the period	196	185	166	(199)
Reclassifications from accumulated other comprehensive income	58	117	89	70
Net other comprehensive income during the period	254	302	255	(129)
Balance at end of period	(3,523)	(2,857)	(3,523)	(2,857)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(1,651)	(984)	(1,627)	(520)
Amounts arising during the period	231	268	207	(196)
Reclassifications from accumulated other comprehensive income	0	0	0	0
Net other comprehensive income during the period	231	268	207	(196)
Balance at end of period	(1,420)	(716)	(1,420)	(716)
Qualifying Derivatives Unrealized Gains (Losses) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(14)	(5)	(7)	(7)
Amounts arising during the period	(24)	(85)	(30)	(5)
Reclassifications from accumulated other comprehensive income	25	85	24	7
Net other comprehensive income during the period	1	0	(6)	2
Balance at end of period	(13)	(5)	(13)	(5)
Equity Investees Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(1)	0	(1)	0
Amounts arising during the period	0	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	0	(1)	0	(1)
Defined Benefit Plans Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(8)	(6)	(8)	(6)
Amounts arising during the period	0	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	(7)	(5)	(7)	(5)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(2,103)	(2,164)	(2,135)	(2,195)
Amounts arising during the period	(11)	2	(11)	2
Reclassifications from accumulated other comprehensive income	31	32	63	63
Net other comprehensive income during the period	20	34	52	65
Balance at end of period	(2,083)	(2,130)	(2,083)	(2,130)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(68)	(45)	(70)	(46)
Amounts arising during the period	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income	2	1	4	2
Net other comprehensive income during the period	(9)	2	(7)	3
Balance at end of period	(77)	(43)	(77)	(43)
LG And E And KU Energy LLC [Member] | Equity Investees Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	0	0	(1)	0
Amounts arising during the period	0	0	0	0
Reclassifications from accumulated other comprehensive income	0	(1)	1	(1)
Net other comprehensive income during the period	0	(1)	1	(1)
Balance at end of period	0	(1)	0	(1)
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	(8)	(10)	(8)	(10)
Amounts arising during the period	0	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	(7)	(9)	(7)	(9)
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	(60)	(35)	(61)	(36)
Amounts arising during the period	(11)	1	(11)	1
Reclassifications from accumulated other comprehensive income	1	1	2	2
Net other comprehensive income during the period	(10)	2	(9)	3
Balance at end of period	$ (70)	$ (33)	$ (70)	$ (33)

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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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Affected Line Item on the Statements of Income [Line Items]
Other Income (Expense) - net	$ (112)	$ 174	$ (159)	$ 235
Interest Expense	(222)	(224)	(439)	(448)
Income Taxes	(76)	(192)	(205)	(371)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(58)	(117)	(89)	(70)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total Pre-tax	(32)	(106)	(31)	(9)
Income Taxes	7	21	7	2
Total After-tax	(25)	(85)	(24)	(7)
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)	(5)	(3)
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	(29)	(103)	(26)	(6)
Interest Expense	(1)	(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	(1)	1	(1)	1
Total Pre-tax	(1)	1	(1)	1
Income Taxes	0	0	0	0
Total After-tax	(1)	1	(1)	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	(41)	(41)	(82)	(81)
Income Taxes	9	8	18	17
Total After-tax	(32)	(33)	(64)	(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	$ (40)	$ (40)	$ (81)	$ (80)