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

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

•	the direct or indirect effects on PPL or its subsidiaries or business systems of cyber-based intrusion or the threat of cyber attacks;

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

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

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

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

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

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

•	developments related to ongoing negotiations regarding the U.K.'s intent to withdraw from European Union and any actions in response thereto;

•	the amount of WPD's pension deficit funding recovered in revenues after March 31, 2021, following the next triennial pension review to begin in March 2019;

•	defaults by counterparties or suppliers for energy, capacity, coal, natural gas or key commodities, goods or services;

•	capital market conditions, including the availability of capital or credit, changes in interest rates and certain economic indices, and decisions regarding capital structure;

•	a material decline in the market value of PPL's equity;

•	significant decreases in the fair value of debt and equity securities and its impact on the value of assets in defined benefit plans, and the potential cash funding requirements if fair value declines;

•	interest rates and their effect on pension and retiree medical liabilities, ARO liabilities and interest payable on certain debt securities;

•	volatility in or the impact of other changes in financial markets and economic conditions;

•	the potential impact of any unrecorded commitments and liabilities of the Registrants and their subsidiaries;

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

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

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

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

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

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

•	catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health events or other similar occurrences;

•	war, armed conflicts, terrorist attacks, or similar disruptive events;

•	changes in political, regulatory or economic conditions in states, regions or countries where the Registrants or their subsidiaries conduct business;

•	receipt of necessary governmental permits and approvals;

•	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;

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•	collective labor bargaining negotiations; and

•	the outcome of litigation against the Registrants and their subsidiaries.

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(a)	Represents RAV for U.K. Regulated, capitalization for Kentucky Regulated and rate base for Pennsylvania Regulated.

•	U.K. Regulated Segment (PPL)

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(a)	WPD’s Operating Revenues are translated from GBP to U.S. dollars using the average GBP to U.S. dollar exchange rates in effect each month. The annual weighted average of the monthly GBP to U.S. dollar exchange rates used for the years ended December 31, 2018, 2017 and 2016 were $1.34 per GBP, $1.28 per GBP and $1.37 per GBP.

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•	Totex - £8.5 billion (£6.8 billion recovered as additions to RAV over time ("Slow pot"); £1.7 billion recovered in the year spent in the plan ("Fast pot"));

•	Pension deficit funding - £1.2 billion;

•	Cost of debt recovery - £1.0 billion;

•	Pass Through Charges - £1.6 billion (Property taxes, Ofgem fees and National Grid transmissions charges); and

•	Corporate income taxes recovery - £0.5 billion.

(a)	Primarily pension deficit funding, pass through costs, profiling adjustments and legacy price control adjustments.

(b)	Primarily pass through true-ups and £5 per residential customer reduction completed in the regulatory year ended March 31, 2017.

(c)	Reference Form 8-K filed February 14, 2019 for U.K. Regulated Segment GAAP Statement of Income component values.

(d)	Includes the service cost component of GAAP pension costs/income. See “Defined Benefits, Net periodic defined benefit costs (credits)” in Note 11 to the Financial Statements.

(e)	Primarily property taxes.

(f)	Primarily includes the non-service cost (credit) components of GAAP pension costs/income and gains and losses on foreign currency hedges.

(g)	Includes WPD interest and $32 million of allocated interest expense to finance the acquisition of WPD Midlands.

(h)	GAAP income taxes represent an effective tax rate of 17% for 2018, 19% for 2017, 16% for 2016 and approximately 17% going forward.

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•	a return on capital from RAV;

•	a return of capital from RAV (i.e., depreciation);

•	the Fast pot recovery, see discussion “(4) Expenditure efficiency mechanisms” below;

•	an allowance for cash taxes paid less a potential reduction for tax benefits from excess leverage if a DNO is levered more than 65% Debt/RAV;

•	pension deficit funding;

•	certain pass-through costs over which the DNO has no control;

•	profiling adjustments, see discussion “(6) Other revenue included in base revenue” below;

•	certain legacy price control adjustments from preceding price control periods, including the information quality incentive (also known as the rolling RAV incentive); and

•	fast-track incentive - because WPD's four DNOs were fast-tracked through the price control review process for RIIO-ED1, their base revenue also includes the fast-track incentive.

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•	an annual fast-track revenue incentive worth 2.5% of Totex (approximately £25 million annually for WPD);

•	a real cost of equity rate of 6.4% compared to 6.0% for slow-tracked DNOs; and,

•	cost savings retention was established at 70% for WPD compared to approximately 55% for slow-tracked DNOs.

•	The MOD provided by Ofgem in November 2016 included the TIM for the 2015/16 regulatory year, as well as the cost of debt calculation based on the 10-year trailing average to October 2016. This MOD of £12 million reduced base revenue in calendar years 2017 and 2018 by £8 million and £4 million.

•	The MOD provided by Ofgem in November 2017 for the 2016/17 regulatory year is a £39 million reduction to revenue and reduced base revenue in calendar year 2018 by £26 million and will reduce base revenue in calendar year 2019 by £13 million.

•	The MOD provided by Ofgem in November 2018 for the 2017/18 regulatory year is a £42 million reduction to revenue and will reduce base revenue in calendar years 2019 and 2020 by £28 million and £14 million.

•	The projected MOD for the 2018/19 regulatory year is a £87 million reduction to revenue and is expected to reduce base revenue in calendar years 2020 and 2021 by £58 million and £29 million.

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•	The TRU for the 2015/16 regulatory year was a £31 million reduction to revenue and reduced base revenue in calendar years 2017 and 2018 by £21 million and £10 million.

•	The TRU for the 2016/17 regulatory year was a £6 million reduction to revenue and reduced base revenue in calendar year 2018 by £4 million and will reduce base revenue in calendar year 2019 by £2 million.

•	The TRU for the 2017/18 regulatory year was a £4 million increase to revenue and will increase base revenue in calendar years 2019 and 2020 by £3 million and £1 million.

•	The projected TRU for the 2018/19 regulatory year is a £3 million increase to revenue and is expected to increase base revenue in calendar years 2020 and 2021 by £2 million and £1 million.

•	The IIS has two major components: (1) Customer interruptions (CIs) and (2) Customer minutes lost (CMLs), and both are designed to incentivize the DNOs to invest in and operate their networks to manage and reduce both the frequency and duration of power outages.

•	The BMCS encompasses customer satisfaction in supply interruptions, connections and general inquiries, complaints, stakeholder engagement and delivery of social obligations.

•	The TTC incentive rewards DNOs for reducing connection times for minor connections against an Ofgem set target.

(a)	Reflects projected incentive revenues.

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•	The K-factor for the 2015/16 regulatory year was a £4 million under-recovery and increased allowed revenue in calendar years 2017 and 2018 by £3 million and £1 million.

•	The K-factor for the 2016/17 regulatory year was a £23 million over-recovery and reduced allowed revenue in calendar year 2018 by £15 million and will reduce allowed revenue in calendar year 2019 by £8 million.

•	The K-factor for the 2017/18 regulatory year was a £3 million over-recovery and will reduce allowed revenue in calendar years 2019 and 2020 by £2 million and £1 million.

•	The projected K-factor for the 2018/19 regulatory year is a £31 million over-recovery and is expected to reduce allowed revenue in calendar years 2020 and 2021 by £21 million and £10 million.

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

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

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

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

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

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

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

•	Kentucky Regulated Segment (PPL)

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(a)	Primarily includes revenues from street lighting and other public authorities.

(b)	Includes wholesale power and transmission revenues.

(a)	Primarily includes revenues from street lighting and other public authorities.

(b)	Includes wholesale power and transmission revenues. Also includes intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE.

(a)	Primarily includes revenues from street lighting and other public authorities.

(b)	Includes wholesale power and transmission revenues. Also includes intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE.

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(a)	Includes 859 GWh of power generated by and purchased from OVEC for LKE, 594 GWh for LG&E and 265 GWh for KU.

(b)	This generation represents increases for LKE, LG&E and KU of 5.7%, 5% and 6.2% from 2017 output.

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•	Pennsylvania Regulated Segment (PPL)

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(a)	Includes regulatory over- or under-recovery reconciliation mechanisms, pole attachment revenues and street lighting, offset by contra revenue associated with the network integration transmission service expense.

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•	Corporate and Other

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•	changes in laws or regulations relating to U.K. operations, including rate regulations beginning in April 2023 under RIIO-ED2, operational performance and tax laws and regulations;

•	changes in government policies, personnel or approval requirements;

•	changes in general economic conditions affecting the U.K.;

•	regulatory reviews of tariffs for DNOs;

•	changes in labor relations;

•	limitations on foreign investment or ownership of projects and returns or distributions to foreign investors;

•	limitations on the ability of foreign companies to borrow money from foreign lenders and lack of local capital or loans;

•	changes in U.S. tax law applicable to taxation of foreign earnings;

•	compliance with U.S. foreign corrupt practices laws; and

•	prolonged periods of low inflation or deflation.

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•	the terms and conditions of our service and operations;

•	financial and capital structure matters;

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•	siting, construction and operation of facilities;

•	mandatory reliability and safety standards under the Energy Policy Act of 2005 and other standards of conduct;

•	accounting, depreciation and cost allocation methodologies;

•	tax matters;

•	affiliate transactions;

•	acquisition and disposal of utility assets and issuance of securities; and

•	various other matters, including energy efficiency.

•	approval, licensing and permitting;

•	land acquisition and the availability of suitable land;

•	skilled labor or equipment shortages;

•	construction problems or delays, including disputes with third-party intervenors;

•	increases in commodity prices or labor rates; and

•	contractor performance.

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(a)	Trimble County Unit 1 and Trimble County Unit 2 are jointly owned with Illinois Municipal Electric Agency and Indiana Municipal Power Agency. Each owner is entitled to its proportionate share of the units' total output and funds its proportionate share of capital, fuel and other operating costs. See Note 12 to the Financial Statements for additional information.

(b)

These units are owned by OVEC. LG&E and KU have a power purchase agreement that entitles LG&E and KU to their proportionate share of these units' total output and LG&E and KU fund their proportionate share of fuel and other operating costs, including debt service. Clifty Creek is located in Indiana and Kyger Creek is located in Ohio. See Note 13 to the Financial Statements for additional information.

(c)	There is an inlet air cooling system attributable to these units. This inlet air cooling system is not jointly owned; however, it is used to increase production on the units to which it relates, resulting in an additional 12 MW of capacity for LG&E and an additional 86 MW of capacity for KU.

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(d)	In 2019, LKE completed upgrades to the Ohio Falls Hydroelectric Generating Station (Units 1-8), expanding the total generating capacity to 100 megawatts.

(e)	This unit is a 10 MW facility and achieves such production. The 8 MW solar facility summer capacity rating is reflective of an average expected output across the peak hours during the summer period based on average weather conditions at the solar facility.

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(a)

The earnings each year were affected by several items that management considers special. See "Results of Operations - Segment Earnings" in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" for a description of special items in 2018, 2017 and 2016. The earnings for 2015 and 2014 were also affected by the spinoff of PPL Energy Supply and the sale of the Montana hydroelectric generating facilities.

(b)	See "Item 1A. Risk Factors" and Notes 1, 7 and 13 to the Financial Statements for a discussion of uncertainties that could affect PPL's future financial condition.

(c)	2014 through 2017 reflect the retrospective application of new accounting guidance related to the income statement presentation of net periodic benefit costs adopted by PPL in January 2018. See Note 1 to the Financial Statements for additional information on the adoption of this guidance.

(d)	2015 reflects the impact of the spinoff of PPL Energy Supply and a $3.2 billion related dividend.

(e)	Based on diluted EPS.

(f)	2015 includes an $879 million loss on the spinoff of PPL Energy Supply, reflecting the difference between PPL's recorded value for the Supply segment and the estimated fair value determined in accordance with GAAP. 2015 also includes five months of Supply segment earnings, compared to 12 months in 2014.

(g)	Based on year-end market prices.

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

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"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 2018 with 2017 and 2017 with 2016. For PPL, "Results of Operations" also includes "Segment Earnings" and "Adjusted Gross Margins" which provide a detailed analysis of earnings by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Adjusted Gross Margins" and provide explanations of the non-GAAP financial measures and a reconciliation of the non-GAAP financial measures to the most comparable GAAP measure. The "2019 Outlook" discussion identifies key factors expected to impact 2019 earnings. For PPL Electric, LKE, LG&E and KU, a summary of earnings and adjusted gross margins is also provided.

•	"Financial Condition - Liquidity and Capital Resources" provides an analysis of the Registrants' liquidity positions and credit profiles. This section also includes a discussion of forecasted sources and uses of cash and rating agency actions.

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

•	"Application of Critical Accounting Policies" provides an overview of the accounting policies that are particularly important to the results of operations and financial condition of the Registrants and that require their management to make significant estimates, assumptions and other judgments of inherently uncertain matters.

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

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

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

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

•

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

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

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

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(a)	Distribution rider prices resulted in an increase of $47 million in 2017 compared with 2016.

(b)	Increase in 2018 compared with 2017 was primarily due to favorable weather in 2018. Decrease in 2017 compared with 2016 was primarily due to milder weather in 2017.

(c)	Increase in 2018 compared with 2017 was primarily due to higher energy purchase volumes.

(d)	Transmission Formula Rate revenues increased primarily from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability and includes the impacts of the TCJA which reduced the new revenue requirement that went into effect June 1, 2018.

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

(f)	Increase primarily due to new base rates approved by the KPSC effective July 1, 2017.

(g)	These revenues are offset by costs reflected in "Other operation and maintenance" on the Statement of Income.

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(a)	The increase in 2018 compared with 2017 primarily represents the other operation and maintenance expense of Safari Energy, which was acquired on June 1, 2018.

(b)	These costs are offset by revenues reflected in "Operating Revenues" on the Statement of Income.

(a)	Higher depreciation rates were effective July 1, 2017 at LG&E and KU.

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(a)	Interest expense increased in 2018 compared with 2017, primarily due to debt issuances by PPL Electric in June 2018 and May 2017 and by PPL Capital Funding in September 2017.

(a)	The decrease in 2018 compared with 2017 is related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

(b)	During 2017, PPL recorded an increase in valuation allowances of $23 million primarily related to foreign tax credits recorded in 2016. The future utilization of these credits is expected to be lower as a result of the TCJA.

(c)	During 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to UK pension contributions.

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(d)	The U.K. Finance Act 2016, enacted in September 2016, reduced the U.K. statutory income tax rate effective April 1, 2020 to 17%. As a result, PPL reduced its net deferred tax liabilities and recognized a $42 million deferred income tax benefit during 2016.

(e)	The reduction in the U.S. federal corporate income tax rate from 35% to 21% significantly reduced the difference between the U.K. and U.S. income tax rates in 2018 compared with 2017.

(f)	During 2018, PPL recorded lower income tax expense for the amortization of excess deferred income taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

(g)	During 2017, PPL recorded deferred income tax expense for the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

(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 increase in 2018 compared with 2017 was primarily due to lower income tax expense of $82 million, partially offset by higher interest expense of $15 million, Talen Montana litigation costs of $9 million and higher charitable contributions of $6 million. 2017 includes $97 million of additional income tax expense related to the enactment of the TCJA. See Note 6 to the Financial Statements for additional information.

•	Unrealized gains or losses on foreign currency economic hedges (as discussed below).

•	Spinoff of the Supply segment.

•	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.

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(a)	Represents unrealized gains (losses) on contracts that economically hedge anticipated GBP-denominated earnings. 2016 includes the reversal of $310 million ($202 million after-tax) of unrealized gains related to the settlement of 2017 and 2018 contracts.

(b)	During 2018, PPL recorded adjustments to certain provisional amounts recognized in the December 31, 2017 Statement of Income relating to the enactment of the TCJA.

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(c)	In 2016, PPL settled 2017 and 2018 foreign currency contracts, resulting in $310 million of cash received ($202 million after-tax). The settlement did not have a material impact on net income as the contracts were previously marked to fair value and recognized in "Other Income (Expense) - net" on the Statement of Income. See Note 17 to the Financial Statements for additional information.

(d)	The U.K. Finance Act of 2016 reduced the U.K.'s statutory income tax rate. As a result, PPL reduced its net deferred tax liability and recognized a deferred tax benefit in 2016. See Note 6 to the Financial Statements for additional information.

(e)	Primarily a payment related to the death of the WPD Chief Executive.

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

•	Higher depreciation expense in 2017 compared with 2016 primarily due to additions to PP&E, net of retirements.

•	Higher other income (expense) - net in 2018 compared with 2017 primarily due to higher pension income due to an increase in expected returns on higher asset balances.

•	Higher other income (expense) - net in 2017 compared with 2016 primarily due to higher pension income due to an increase in expected returns on higher asset balances and lower interest costs due to a lower discount rate.

•	Higher interest expense in 2017 compared with 2016 primarily due to higher interest expense on indexed linked bonds.

•	Higher income taxes in 2018 compared with 2017 primarily due to higher pre-tax income.

•	Lower income taxes in 2017 compared with 2016 primarily due to decreases of $10 million related to accelerated tax deductions and $7 million from lower U.K. tax rates, partially offset by an increase of $11 million from higher pre-tax income.

•	Higher income taxes in 2018 compared with 2017 primarily due to a $35 million tax benefit on accelerated pension contributions in the first quarter of 2017 and a $16 million increase from a reduction in tax benefits on interest deductibility due to the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018.

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•	Higher income taxes in 2017 compared with 2016 primarily due to a $37 million benefit related to foreign tax credit carryforwards in 2016, partially offset by a $29 million tax benefit on accelerated pension contributions made in the first quarter of 2017.

(a)	During 2018, LKE recorded adjustments to certain provisional amounts associated with LKE's non-regulated entities recognized in the December 31, 2017 Statement of Income relating to the enactment of the TCJA.

(b)	During 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

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

(d)	Recorded at LKE and represents the settlement of a WKE indemnification. See Note 13 to the financial statements for additional information.

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

•

Higher other operation and maintenance expense in 2018 compared with 2017 primarily due to an $8 million increase in vegetation management, an $8 million increase in timing and scope of generation maintenance outages, a $7 million increase in gas distribution maintenance and compliance, a $7 million increase in electricity distribution outage and repairs and increases in other costs that were not individually significant in comparison to the prior year.

•	Higher depreciation expense in 2018 compared with 2017 primarily due to a $16 million increase related to additional assets placed into service, net of retirements, and a $12 million increase related to higher depreciation rates effective July 1, 2017.

•	Higher depreciation expense in 2017 compared with 2016 primarily due to a $15 million increase related to additional assets placed into service, net of retirements, and a $12 million increase related to higher depreciation rates effective July 1, 2017.

•	Higher interest expense in 2018 compared with 2017 primarily due to increased borrowings under LG&E's term loan credit facility and from affiliates.

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Lower income taxes in 2018 compared with 2017 primarily due to a $74 million decrease related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018, a $42 million decrease related to lower pre-tax income and an $18 million decrease primarily related to higher amortization of excess deferred income taxes as a result of the TCJA.

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(a)	In June 2018, PPL EU Services' IT department announced an internal reorganization. As a result, $5 million of after-tax costs, which includes separation benefits as well as outside services for strategic consulting to establish the new IT organization, were incurred. See Note 13 to the Financial Statements for additional information.

(b)	During 2017, PPL recorded a deferred income tax benefit for the enactment of the TCJA. See Note 6 to the Financial Statements for additional information.

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

•	Lower other operation and maintenance expense in 2018 compared with 2017 primarily due to $36 million of lower corporate service costs allocated to PPL Electric, partially offset by $11 million of higher non-recoverable storm expenses and $11 million of higher bad debt expense.

•	Lower other operation and maintenance expense in 2017 compared with 2016 primarily due to $17 million of lower bad debt expense, $17 million of lower vegetation management expenses and $14 million of lower payroll expenses, partially offset by $19 million of higher corporate service costs allocated to PPL Electric.

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•	Higher depreciation expense in 2018 compared with 2017 and 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, net of retirements.

•	Higher interest expense in 2018 compared with 2017 primarily due to the May 2017 issuance of $475 million of 3.95% First Mortgage Bonds and the June 2018 issuance of $400 million of 4.15% First Mortgage Bonds.

•	Higher interest expense in 2017 compared with 2016 primarily due to the issuance of $475 million of 3.95% First Mortgage Bonds in May 2017.

•	Lower income taxes in 2018 compared with 2017 primarily due to the impact of the U.S federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018 of $71 million and $18 million of lower income taxes due to amortization of excess deferred income taxes.

•	Higher income taxes in 2017 compared with 2016 primarily due to higher pre-tax income at current period tax rates.

(a)	During 2018, PPL recorded adjustments to certain provisional amounts recognized in the December 31, 2017 Statement of Income relating to the enactment of the TCJA. See Note 6 to the Financial Statements for additional information.

(b)	During 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

(c)	During 2018, PPL incurred legal expenses related to litigation with its former affiliate, Talen Montana. See Note 13 to the Financial Statements for additional information.

(a)	During 2017, PPL recorded deferred income tax (expense) benefit related to the enactment of the TCJA. See Note 6 to the Financial Statements for additional information.

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•

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

•

"Kentucky Adjusted Gross Margins" is a single financial performance measure of the electricity generation, transmission and distribution operations of the Kentucky Regulated segment, LKE, LG&E and KU, as well as the Kentucky Regulated segment's, LKE's and LG&E's distribution and sale of natural gas. In calculating this measure, fuel, energy purchases and certain variable costs of production (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues. In addition, certain other expenses, recorded in "Other operation and maintenance", "Depreciation" and "Taxes, other than income" on the Statements of Income, associated with approved cost recovery mechanisms are offset against the recovery of those expenses, which are included in revenues. These mechanisms allow for direct recovery of these expenses and, in some cases, returns on capital investments and performance incentives. As a result, this measure represents the net revenues from electricity and gas operations.

•

"Pennsylvania Adjusted Gross Margins" is a single financial performance measure of the electricity transmission and distribution operations of the Pennsylvania Regulated segment and PPL Electric. In calculating this measure, utility revenues and expenses associated with approved recovery mechanisms, including energy provided as a PLR, are offset with minimal impact on earnings. Costs associated with these mechanisms are recorded in "Energy purchases," "Other operation and maintenance," (which are primarily Act 129, Storm Damage and Universal Service program costs), "Depreciation" (which is primarily related to the Act 129 Smart Meter program) and "Taxes, other than income," (which is primarily gross receipts tax) on the Statements of Income. This measure represents the net revenues from the Pennsylvania Regulated segment's and PPL Electric's electricity delivery operations.

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(a)	Represents amounts excluded from Adjusted Gross Margins.

(b)	As reported on the Statements of Income.

(c)	2018, 2017 and 2016 exclude $38 million, $41 million and $42 million of ancillary revenues.

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(a)	Distribution rider prices resulted in an increase of $47 million in 2017 as compared with 2016.

(b)	Increase in 2018 compared with 2017 was primarily due to favorable weather in 2018. Decrease in 2017 compared with 2016 was primarily due to milder weather in 2017.

(c)	Increase in 2018 compared with 2017 was primarily due to higher energy purchase volumes.

(d)	Transmission Formula Rate revenues increased primarily from returns on additional transmission capital investments focused on replacing aging infrastructure and improving reliability and includes the impacts of the TCJA which reduced the new revenue requirement that went into effect June 1, 2018.

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

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

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(b)	During 2017, PPL Electric recorded a deferred income tax benefit related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

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(a)	Represents amounts excluded from Adjusted Gross Margins.

(b)	As reported on the Statements of Income.

(a)	Increase in 2018 compared with 2017 primarily due to favorable weather in 2018. Decrease in 2017 compared with 2016 primarily due to milder weather in 2017.

(b)	Increases primarily due to new base rates approved by the KPSC effective July 1, 2017.

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

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(a)	During 2017, LKE recorded deferred tax expense related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA associated with LKE's non-regulated entities.

(b)	The decrease is related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

(c)	The decrease is related to the impact of the Kentucky state corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

(d)	During 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

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

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(a)	Represents amounts excluded from Adjusted Gross Margins.

(b)	As reported on the Statements of Income.

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(a)	Increase in 2018 compared with 2017 primarily due to favorable weather in 2018. Decrease in 2017 compared with 2016 primarily due to milder weather in 2017.

(b)	Increases primarily due to new base rates approved by the KPSC effective July 1, 2017.

(c)	Represents income tax savings owed to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

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

(b)	The decrease is related to the impact of the Kentucky state corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

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

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(a)	Represents amounts excluded from Adjusted Gross Margins.

(b)	As reported on the Statements of Income.

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(a)	Increase in 2018 compared with 2017 primarily due to favorable weather in 2018. Decrease in 2017 compared with 2016 primarily due to milder weather in 2017.

(b)	Increases primarily due to new base rates approved by the KPSC effective July 1, 2017.

(c)	Represents income tax savings owed to customers related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21%, as enacted by the TCJA, effective January 1, 2018. See Note 6 to the Financial Statements for additional information.

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

(b)	The decrease is related to the impact of the Kentucky state corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

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

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(a)	Represents amounts excluded from Adjusted Gross Margins.

(b)	As reported on the Statements of Income.

(a)	At December 31, 2018, $3 million of cash and cash equivalents were denominated in GBP. If these amounts would be remitted as dividends, PPL would not anticipate an incremental U.S. tax cost. See Note 6 to the Financial Statements for additional information on undistributed earnings of WPD.

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•	Net income increased $699 million between periods and included a decrease in net non-cash charges of $752 million. The decrease in net non-cash charges was primarily due to an increase in unrealized gains on hedging activities, a decrease in deferred income taxes (primarily due to the unfavorable adjustments recorded in 2017 for the tax changes

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The $199 million increase in cash from changes in working capital was primarily due to a decrease in unbilled revenue (primarily due to lower volumes due to milder temperatures in December 2018 versus December 2017), an increase in accounts payable (primarily due to timing of payments), a decrease in accounts receivable (primarily due to timing of receipts) and a decrease in net regulatory assets and liabilities (primarily due to the impact of the TCJA and timing of rate recovery mechanisms), partially offset by a decrease in customer deposits and an increase in fuel, materials and supplies (primarily due to higher generation driven by weather in 2018 compared with 2017).

•	Defined benefit plan funding was $204 million lower in 2018. The decrease was primarily due to the acceleration of WPD's contributions to its U.K. pension plans in 2017.

•

Net income declined $774 million between periods and included net non-cash benefits of $363 million. The increase in net non-cash benefits was primarily due to an increase in unrealized losses on hedging activities, an increase in deferred income taxes (primarily due to the impact of the TCJA) and an increase in depreciation expense (primarily due to additional assets placed into service, net of retirements, and higher depreciation rates at LG&E and KU effective July 1, 2017, partially offset by the impact of foreign currency at WPD), partially offset by an increase in the U.K. net periodic defined benefit credits (primarily due to a decrease in the U.K. pension plan discount rates used to calculate the interest cost component of the net periodic defined benefit costs (credits) and increase in expected returns).

•

The $38 million increase in cash from changes in working capital was primarily due a decrease in net regulatory assets and liabilities (due to timing of rate recovery mechanisms), a decrease in fuel, materials and supplies (primarily due to a decrease in fuel purchases due to lower generation driven by milder weather in 2017 compared to 2016) and a decrease in unbilled revenue (primarily due to lower growth in volumes in 2017 compared to 2016), partially offset by a decrease in accounts payable (due to timing of payments), a decrease in taxes payable (primarily due to the timing of payments) and an increase in accounts receivable.

•	Defined benefit plan funding was $138 million higher in 2017. The increase was primarily due to the acceleration of WPD's contributions to its U.K. pension plans.

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Net income improved by $68 million between the periods. This included a decrease of $106 million of net non-cash charges primarily due to a $133 million decrease in deferred income tax expense (primarily due to book versus tax plant timing differences) partially offset by a $43 million increase in depreciation expense (primarily due to additional assets placed into service, net of retirements, related to the ongoing efforts to ensure the reliability of the delivery system, the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter Program).

•	The $134 million increase in cash from changes in working capital was primarily due to a decrease in accounts receivable (primarily due to the timing of receipts including the 2017 federal income tax benefit refund received in 2018) and a decrease in unbilled revenues (primarily due to colder weather in December 2017).

•

Net income improved by $22 million between the periods. This included an additional $100 million of net non-cash benefits primarily due to a $56 million increase in depreciation expense (primarily due to additional assets placed into service, related to the ongoing efforts to ensure the reliability of the delivery system and the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program, net of retirements) and a $37 million increase in deferred income taxes (primarily due to book versus tax plant timing differences).

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The $87 million decrease in cash from changes in working capital was primarily due to an increase in accounts receivable (primarily due to a 2017 federal income tax benefit refund, not yet received), a decrease in accounts payable (primarily due to timing of payments) and an increase in prepayments (primarily due to an increase in the 2017 gross receipts tax prepayment compared to 2016), partially offset by an decrease in net regulatory assets and liabilities (due to timing of rate recovery mechanisms) and a decrease in unbilled revenue (primarily due to lower growth in volumes in 2017 compared to 2016).

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•	Pension funding was $24 million higher in 2017 due to contributions made in 2017 to the PPL Retirement Plan.

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Net income increased $129 million between the periods and included a decrease in net non-cash charges of $182 million. The decrease in net non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and the impacts of federal and state tax reform), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements).

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The increase in cash from changes in working capital was primarily driven by a decrease in unbilled revenues (primarily due to milder weather in December 2018 compared to 2017), an increase in accounts payable (primarily due to timing of payments) and a decrease in net regulatory assets and liabilities (primarily due to the impact of the TJCA and the timing of rate recovery mechanisms), partially offset by a decrease in other current liabilities and accrued taxes (primarily due to timing of payments) and an increase in fuel purchases (primarily due to higher generation driven by weather in 2018 compared with 2017).

•	Defined benefit plan funding was $96 million higher in 2018.

•	The decrease in cash from LKE's other operating activities was driven primarily by an increase in ARO expenditures and an increase in other assets (primarily due to non-current regulatory asset increases as a result of significant storm activity).

•	Net income decreased $113 million between the periods and included an increase in net non-cash charges of $31 million. The increase in net non-cash charges was primarily driven by increases in depreciation expense and deferred income taxes (primarily due to the impact of the TCJA).

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The increase in cash from changes in working capital was driven primarily by an increase in other current liabilities (due to customer advances and the timing of payments), a decrease in fuel purchases (primarily due to lower generation driven by milder weather in 2017 compared to 2016), an increase in taxes payable (primarily due to the timing of payments), partially offset by a decrease in accounts payable (primarily due to the timing of payments).

•	Defined benefit plan funding was $50 million lower in 2017.

•

Net income increased $20 million between the periods and included a decrease in net non-cash charges of $59 million. The decrease in net non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences and the impacts of federal and state tax reform), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements).

•

The increase in cash from changes in working capital was primarily driven by a decrease in unbilled revenues (primarily due to milder weather in December 2018 compared to 2017), an increase in accounts payable and accrued taxes (primarily due to timing of payments) and a decrease in net regulatory assets and liabilities (primarily due to the impact of the TJCA and the timing of rate recovery mechanisms), partially offset by a decrease in other current liabilities (primarily due to timing of payments).

•	Defined benefit plan funding was $57 million higher in 2018.

•	The decrease in cash from LG&E’s other operating activities was driven primarily by an increase in other assets (primarily due to non-current regulatory asset increases as a result of significant storm activity).

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•	Net income increased $10 million between the periods and included a decrease in net non-cash charges of $8 million. The decrease in net non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences), partially offset by an increase in depreciation expense.

•

The decrease in cash from changes in working capital was driven primarily by decreases in accounts payable and taxes payable (primarily due to the timing of payments), partially offset by a decrease in accounts receivable from affiliates (due to lower intercompany settlements associated with energy sales and inventory) and an increase in other current liabilities (primarily due to customer advances and the timing of payments).

•	Defined benefit plan funding was $42 million lower in 2017.

•	The increase in cash from LG&E's other operating activities was driven primarily by lower payments for the settlement of interest rate swaps.

•

Net income increased $27 million between the periods and included a decrease in net non-cash charges of $94 million. The decrease in net non-cash charges was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences, differences in the utilization of net operating losses and the impacts of federal and state tax reform), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates effective July 1, 2017 and additional assets placed into service, net of retirements).

•

The increase in cash from changes in working capital was primarily driven by a decrease in unbilled revenues (primarily due to milder weather in December 2018 compared to 2017), an increase in accrued taxes and accounts payable (primarily due to timing of payments), and a decrease in net regulatory assets and liabilities (primarily due to the impact of the TJCA and the timing of rate recovery mechanisms), partially offset by an increase in fuel purchases (primarily due to higher generation driven by weather in 2018 compared to 2017) and a decrease in other current liabilities (primarily due to timing of payments).

•	Defined benefit plan funding was $31 million higher in 2018.

•	The decrease in cash from KU’s other operating activities was driven primarily by an increase in ARO expenditures and an increase in other assets (primarily due to noncurrent regulatory asset increases as a result of significant storm activity).

•	Net income decreased $6 million between the periods and included an increase in net non-cash charges of $42 million. The increase in net non-cash charges was primarily driven by an increase in deferred income tax expense (primarily due to the utilization of net operating losses) and an increase in depreciation expense.

•

The decrease in cash from changes in working capital was driven primarily by a decrease in taxes payable (primarily due to the timing of payments) and a decrease in accounts payable to affiliates (due to lower intercompany settlements associated with energy purchases and inventory), partially offset by a decrease in fuel purchases (primarily due to lower generation driven by milder weather in 2017 compared to 2016) and an increase in accounts payable (primarily due to the timing of payments).

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(a)	Issuances are net of pricing discounts, where applicable, and exclude the impact of debt issuance costs. Includes debt issuances with affiliates.

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(a)	The syndicated credit facilities, KU's letter of credit facility and PPL Capital Funding's bilateral facility, each contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LKE, LG&E and KU, as calculated in accordance with the facility, and other customary covenants.

(b)	Each company pays customary fees under its respective syndicated credit facility, as does LG&E under its term loan agreement and KU under its letter of credit facility. Borrowings generally bear interest at LIBOR-based rates plus an applicable margin.

(c)	The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility.

(a)	LG&E and KU participate in an intercompany 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 authorized a maximum aggregate short-term debt limit for each utility at $500 million from all covered sources.

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(a)	Construction expenditures include capitalized interest and AFUDC, which are expected to total approximately $81 million for PPL and $50 million for PPL Electric.

(b)	The 2019 total excludes amounts included in accounts payable as of December 31, 2018.

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(a)	Reflects principal maturities based on stated maturity or earlier put dates. See Note 8 to the Financial Statements for a discussion of variable-rate remarketable bonds issued on behalf of LG&E and KU. The Registrants do not have any significant capital lease obligations.

(b)	Assumes interest payments through stated maturity or earlier put dates. For PPL, LKE, LG&E and KU the payments herein are subject to change, as payments for debt that is or becomes variable-rate debt have been estimated and for PPL, payments denominated in British pounds sterling have been translated to U.S. dollars at a current foreign currency exchange rate.

(c)	See Note 9 to the Financial Statements for additional information.

(d)

The amounts include agreements to purchase goods or services that are enforceable and legally binding and specify all significant terms, including: fixed or minimum quantities to be purchased; fixed, minimum or variable price provisions; and the approximate timing of the transaction. Primarily includes, as applicable, the purchase obligations of electricity, coal, natural gas and limestone, as well as certain construction expenditures, which are also included in the Capital Expenditures table presented above.

(e)

The amounts for PPL include WPD's contractual deficit pension funding requirements arising from actuarial valuations performed in March 2016. The U.K. electricity regulator currently allows a recovery of a substantial portion of the contributions relating to the plan deficit. The amounts also include contributions made or committed to be made in 2019 for PPL's and LKE's U.S. pension plans (for PPL Electric, LG&E and KU includes their share of these amounts). Based on the current funded status of these plans, except for WPD's plans, no cash contributions are required. See Note 11 to the Financial Statements for a discussion of expected contributions.

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(f)	Represents contracts to purchase coal, natural gas and natural gas transportation. See Note 13 to the Financial Statements for additional information.

(g)	Represents future minimum payments under OVEC power purchase agreements through June 2040. See Note 13 to the Financial Statements for additional information.

(h)	Represents construction commitments, including commitments for LG&E's and KU's Trimble County landfill construction, CCR Rule Closure and Process Water Program along with Cane Run plant demolition, which are also reflected in the Capital Expenditures table presented above.

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(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.

(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 of expected earnings denominated in GBP.

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

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

•	WPD is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 to the Financial Statements for additional information on revenue recognition under RIIO-ED1.

•	PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases.

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(a)	Does not sponsor or participate in other postretirement benefits plans.

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Discount Rate - The discount rate is used in calculating the present value of benefits, which is based on projections of benefit payments to be made in the future. The objective in selecting the discount rate is to measure the single amount that, if invested at the measurement date in a portfolio of high-quality debt instruments, would provide the necessary future cash flows to pay the accumulated benefits when due.

•	Expected Return on Plan Assets - Management projects the long-term rates of return on plan assets that will be earned over the life of the plan. These projected returns reduce the net benefit costs the Registrants record currently.

•	Rate of Compensation Increase - Management projects employees' annual pay increases, which are used to project employees' pension benefits at retirement.

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(a)

WPD uses individual spot rates from the yield curve used to discount the benefit obligation to measure service cost and interest cost for the calculation of net periodic defined benefit cost. PPL's U.S. plans use a single discount rate derived from an individual bond matching model to measure the benefit obligation, service cost and interest cost. See Note 1 to the Financial Statements for additional details.

(a)	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between pension cost calculated in accordance with LG&E's and KU's pension accounting policy and pension cost calculated using a 15 year amortization period for actuarial gains and losses is

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(a)	1,560,000 shares authorized; 720,323 and 693,398 shares issued and outstanding at December 31, 2018 and December 31, 2017.

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

(b)	Dividends declared per share of common stock at December 31, 2018, 2017 and 2016: $1.64, $1.58 and $1.52.

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(a)	Net income equals comprehensive income.

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

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

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(a)	Net income equals comprehensive income.

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

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(a)	Net income approximates comprehensive income.

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

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

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•	Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring.

•	Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges.

•	Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges.

•	Transactions to hedge the value of a net investment of foreign operations can be designated as net investment hedges.

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Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. These transactions generally include foreign currency forwards and options to hedge GBP-denominated earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates.

•	Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are included in customer rates.

(a)	Represents revenues from cost-based rate-regulated generation, transmission and/or distribution in Pennsylvania, Kentucky and Virginia, including regulated wholesale revenue.

(b)	Primarily represents regulated electricity distribution revenues from the operation of WPD's distribution networks.

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•	Inflation True-Up - The base demand revenue for the RIIO-ED1 period was set based on 2012/13 prices. Therefore an inflation factor as determined by forecasted RPI, provided by HM Treasury, is applied to base demand revenue.

•

Annual Iteration Process (AIP) - The RIIO-ED1 price control period also includes an AIP. This will allow future base demand revenues agreed with the regulator as part of the price control review, to be updated during the price control period for financial adjustments including tax, pensions, cost of debt, legacy price control adjustments from preceding price control periods and adjustments relating to actual and allowed total expenditure together with the Totex Incentive Mechanism (TIM). Under the TIM, WPD's DNOs are able to retain 70% of any amounts not spent against the RIIO-ED1 plan and bear 70% of any over-spends. The AIP calculates an incremental change to base demand revenue, known as the "MOD" adjustment.

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Incentives - Ofgem has established incentives to provide opportunities for DNO's to enhance overall returns by improving network efficiency, reliability and customer service. These incentives can result in an increase or reduction in revenues based on incentives or penalties for actual performance against pre-established targets based on past performance. The annual incentives and penalties are reflected in customers' rates on a two-year lag from the time they are earned and/or assessed. Incentive revenues and penalties are included in revenues when they are billed to customers.

•

Correction Factor - During the current price control period, WPD sets its tariffs to recover allowed revenue. However, in any fiscal period, WPD's revenue could be negatively affected if its tariffs and the volume delivered do not fully recover the revenue allowed for a particular period. Conversely, WPD could also over-recover revenue. Over and under-recoveries are subtracted from or added to allowed revenue in future years when they are billed to customers, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising for the periods beginning with the 2014/15 regulatory year and refunded/recovered under RIIO-ED1 are refunded/recovered on a two year lag (previously one year). Therefore the 2015/16 over/under-recovery adjustment occurred in the 2017/18 regulatory year.

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(a)	Primarily related to uncollectible accounts written off.

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•	Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

•	Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability.

•	Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value.

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•	there is an intent or a requirement to sell the security before recovery, the other-than-temporary impairment is recognized currently in earnings; or

•	there is no intent or requirement to sell the security before recovery, the portion of the other-than-temporary impairment that is considered a credit loss is recognized currently in earnings and the remainder of the other-than-temporary impairment is reported in OCI, net of tax; or

•	there is no intent or requirement to sell the security before recovery and there is no credit loss, the unrealized loss is reported in OCI, net of tax.

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•	the expected use of the asset;

•	the expected useful life of other assets to which the useful life of the intangible asset may relate;

•	legal, regulatory, or contractual provisions that may limit the useful life;

•	the company's historical experience as evidence of its ability to support renewal or extension;

•	the effects of obsolescence, demand, competition, and other economic factors; and,

•	the level of maintenance expenditures required to obtain the expected future cash flows from the asset.

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(a)	Primarily consists of funds received by WPD, which are to be spent on approved initiatives to support a low carbon environment.

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(a)	See Note 1 for additional information on Operating Revenues.

(b)	Represents non-cash expense items that include amortization of regulatory assets, debt discounts and premiums and debt issuance costs.

(c)	Includes unrealized gains and losses from economic activity. See Note 17 for additional information.

(d)	Represents both current and deferred income taxes, including investment tax credits. See Note 6 for additional information on the impact of the TCJA in 2018 and 2017.

(e)	Represents a non-cash expense item that is also included in "Income Taxes."

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

(b)	Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy.

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(a)	PPL includes $2.3 billion for the year ended December 31, 2018 of revenues from external customers reported by the U.K. Regulated segment. PPL Electric and LKE represent revenues from external customers reported by the Pennsylvania Regulated and Kentucky Regulated segments. See Note 2 for additional information.

(b)

Alternative revenue programs for PPL Electric include the over/under-collection of its transmission formula rate. Alternative revenue programs for LKE, LG&E and KU include the over/under collection for the ECR and DSM programs as well as LG&E's over/under collection of its GLT program and KU's over/under collection of its generation formula rate. Over-collections of revenue are shown as positive amounts in the table above; under-collections are shown as negative amounts.

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

(a)	Represents customers of WPD.

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

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

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(a)	The Treasury Stock Method was applied to non-participating share-based payment awards.

(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.

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•	The reduction in the U.S. federal corporate income tax rate from a top marginal rate of 35% to a flat rate of 21%, effective January 1, 2018;

•	The exclusion from U.S. federal taxable income of dividends from foreign subsidiaries and the associated "transition tax;"

•	Limitations on the tax deductibility of interest expense, with an exception to these limitations for regulated public utilities;

•	Full current year expensing of capital expenditures with an exception for regulated public utilities that qualify for the exception to the interest expense limitation; and

•	The continuation of certain rate normalization requirements for accelerated depreciation benefits. For non-regulated businesses, the TCJA generally provides for full expensing of property acquired after September 27, 2017.

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

(b)	The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2018. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income.

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

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(a)	The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained.

(b)	Includes $62 million of foreign tax credits carried forward from 2016 and $156 million of additional foreign tax credits from 2017 related to the taxable deemed dividend associated with the TCJA.

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(a)	Decrease in the valuation allowance of approximately $35 million due to the change in the total foreign tax credits available after finalization of the deemed dividend calculation required by the TCJA in 2017. In addition, the deferred tax assets and corresponding valuation allowances were reduced in 2018 by approximately $19 million due to the effect of foreign currency exchange rates.

(b)	Increase in valuation allowance of approximately $145 million related to expected future utilization of both 2017 foreign tax credits and pre-2017 foreign tax credits carried forward. For additional information, see the "Reconciliation of Income Tax Expense" and associated notes below.

(c)

The reduction of the U.K. statutory income tax rate in 2016 resulted in a $19 million reduction in deferred tax assets and corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for additional information on the impact of the U.K. Finance Act 2016. In addition, deferred tax assets and corresponding valuation allowances were reduced in 2016 by approximately $65 million due to the effect of foreign currency exchange rates.

(a)	Due to the enactment of the TCJA, PPL recorded the following in 2017:

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•	$220 million of deferred income tax expense related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities;

•	$162 million of deferred tax expense related to the utilization of current year losses resulting from the taxable deemed dividend; partially offset by,

•	$60 million of deferred tax benefits related to the $205 million of 2017 foreign tax credits partially offset by $145 million of valuation allowances.

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

(b)	During 2017, PPL recorded an increase in valuation allowances of $23 million primarily related to foreign tax credits recorded in 2016. The future utilization of these credits is expected to be lower as a result of the TCJA.

(c)	The reduction in the U.S. federal corporate income tax rate from 35% to 21% significantly reduced the difference between the U.K. and U.S. income tax rates in 2018 compared with 2017.

(d)	During 2017, PPL recorded a federal income tax benefit of $35 million primarily attributable to U.K. pension contributions.

(e)	The U.K. Finance Act 2016, enacted in September 2016, reduced the U.K. statutory income tax rate effective April 1, 2020 to 17%. As a result, PPL reduced its net deferred tax liabilities and recognized a $42 million deferred income tax benefit during 2016.

(f)	During 2018, PPL recorded lower income tax expense for the amortization of excess deferred income taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

(g)	During 2017, PPL recorded deferred income tax expense related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

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(i)	During 2018, PPL filed its consolidated federal income tax return, which included updates to the TCJA provisional amounts recorded in 2017. The adjustments to the various provisional amounts that are considered complete as of the filed tax return resulted in an immaterial impact to income tax expense and are discussed in the TCJA section above.

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(a)	Due to the enactment of the TCJA in 2017, PPL Electric recorded a $13 million deferred tax benefit related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities.

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

(b)	During 2017, PPL Electric recorded a deferred tax benefit related to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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(a)	The TCJA repealed the corporate alternative minimum tax (AMT) for tax years beginning after December 31, 2017. The existing indefinite carryforward period for AMT credits was retained.

(a)	Federal tax credits expiring in 2021 that are more likely than not to expire before being utilized.

(b)	Federal tax credit expiring.

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(a)	Due to the enactment of the TCJA in 2017, LKE recorded $112 million of deferred income tax expense, of which $108 million related to the impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on deferred tax assets and liabilities and $4 million related to valuation allowances on tax credits expiring in 2021.

(b)	Excludes deferred federal and state tax expense (benefit) recorded to OCI of $5 million in 2018, $(10) million in 2017 and $(16) million in 2016.

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

(b)	During 2018, LKE recorded lower income tax expense for the amortization of excess deferred income taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

(c)	During 2017, LKE recorded deferred income tax expense primarily due to the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

(e)	During 2018, PPL filed its consolidated federal income tax return, which included updates to the TCJA provisional amounts recorded in 2017. The adjustments to the various provisional amounts that are considered complete as of the filed tax return resulted in an immaterial impact to income tax expense and are discussed in the TCJA section above.

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

(b)	During 2018, LG&E recorded lower income tax expense for the amortization of excess deferred income taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

(b)	During 2018, KU recorded lower income tax expense for the amortization of excess deferred income taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA.

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

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(a)	The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility.

(b)

The WPD plc amounts borrowed at December 31, 2018 and 2017 included USD-denominated borrowings of $200 million for both periods, which bore interest at 3.17% and 2.17%. The unused capacity reflects the amount borrowed in GBP of £156 million as of the date borrowed. The WPD (East Midlands) amount borrowed at December 31, 2018 and December 31, 2017 was a GBP-denominated borrowing, which equated to $48 million and $244 million and bore interest at 1.12%. and 0.89%. The WPD (West Midlands) amount borrowed at December 31, 2017 was a GBP-denominated borrowing, which equated to $162 million and bore interest at 0.89%. At December 31, 2018, the unused capacity under the U.K. credit facilities was approximately $1.3 billion.

(c)	Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin.

(d)

The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LKE, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, as it relates to the syndicated and bilateral credit facilities and subject to certain conditions, PPL Capital Funding may request that the capacity of its facility expiring in March 2019 be increased by up to $30 million, LG&E and KU each may request up to a $100 million increase in its facility's capacity.

(e)	LG&E entered into a term loan credit agreement in October 2017 whereby it may borrow up to $200 million. The outstanding borrowings at December 31, 2018 and December 31, 2017 bore interest at an average rate of 2.97% and 2.06%.

(f)	KU's letter of credit facility agreement allows for certain payments under the letter of credit facility to be converted to loans rather than requiring immediate payment.

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(a)	Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all electric distribution plant and certain transmission plant owned by PPL Electric. The carrying value of PPL Electric's property, plant and equipment was approximately $9.4 billion and $8.5 billion at December 31, 2018 and 2017.

(b)

Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. This amount includes $224 million of which PPL Electric is allowed to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, or term rate of at least one year and $90 million that may be redeemed, in whole or in part, at par beginning in October 2020, and are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes.

(c)	Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment

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(d)	Includes £225 million ($287 million at December 31, 2018) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond.

(e)

The principal amount of the notes issued by WPD (South West), WPD (East Midlands) and WPD (South Wales) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the principal amounts from 2017 to 2018 was an increase of approximately £26 million ($33 million) resulting from inflation. In addition, this amount includes £319 million ($407 million at December 31, 2018) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond.

(f)

Includes £5.3 billion ($6.7 billion at December 31, 2018) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructuring event, which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates.

(g)	The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2018.

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(a)	Excludes 45,298 restricted stock units for which restrictions lapsed for former PPL Energy Supply employees as a result of the June 2015 spinoff, but for which distribution will not occur until the end of the original restriction period of the awards.

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(a)	Primarily related to the forfeiture of 2015 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout.

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(a)	WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities.

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(a)	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LKE's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $11 million in 2018 and 2017 and $6 million in 2016.

(b)	Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.

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(a)	As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $2 million in 2018, $7 million in 2017 and $5 million in 2016.

(b)	Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $6 million in 2018 and $5 million in 2017 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.

(a)

PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 14 for additional information on costs allocated to KU from LKS.

(b)

As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in accordance with LKE's, LG&E's and KU's pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charged to Other operation and maintenance, Other Income (Expense) - net or regulatory assets, excluding amounts charged to construction and other non-expense accounts, $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018, $4 million for LG&E and $2 million for KU were recorded as regulatory assets in 2017 and $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2016.

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(a)	The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.

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(a)	In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees.

(b)	WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and as a result, does not record regulatory assets/liabilities.

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(a)

The pension plans were amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plans include lump-sum cash payments made to participants during 2018 and 2017 of $52 million and $50 million in connection with these offerings.

(b)	The actuarial (gain) loss for all pension plans in 2018 and 2017 was primarily related to change in the discount rate used to measure the benefit obligations of those plans.

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(a)

The pension plan was amended in December 2015 to allow active participants and terminated vested participants who had not previously elected a form of payment of their benefit to elect to receive their accrued pension benefit as a one-time lump-sum payment effective January 1, 2016. Gross benefits paid by the plan include lump-sum cash payments made to participants during 2018 and 2017 of $16 million and $19 million in connection with this offering.

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(a)	Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan.

(b)	Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.

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(a)

In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.

(b)	Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.

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(a)	Includes commingled debt funds and debt securities.

(b)	Includes money market funds.

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(a)

In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.

(b)	Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.

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(a)	Includes commingled debt funds.

(a)

In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.

(b)	Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.

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(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.

(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 December 31, 2018, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.

(d)	A third party logistics firm provides inventory procurement and fulfillment services. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold. In January 2018, this agreement was superseded by a new contract which extends the guarantee until 2020.

(e)

LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses 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 $113 million at December 31, 2018, consisting of LG&E's share of $78 million and KU's share of $35 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract.

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(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.

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(a)	Amounts are net of debt issuance costs.

•

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.

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•	PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated domestic utilities and for certain plans at WPD due to the recovery methods in place.

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

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

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

•	WPD is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 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.

•	PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated at the regulated domestic utilities and for certain plans at WPD due to the recovery methods in place.

•	PPL is exposed to equity securities price risk from future stock sales and/or purchases.

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

(b)	Excludes accrued interest, if applicable.

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

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(a)	There were no accumulated impairment losses related to goodwill.

(b)	Recognized as a result of the acquisition of Safari Energy.

(a)	Gross carrying amount in 2018 and 2017 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL.

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(a)	Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.

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(a)	Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.

(a)	Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.

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•	For existing leases, the Registrants did not re-assess whether those contracts contain leases, retained existing lease classifications and did not reassess initial direct costs.

•	The Registrants did not evaluate land easements that were not previously accounted for as leases under this new guidance. Land easements are evaluated under this new guidance beginning January 1, 2019.

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(a)	Quarterly results can vary depending on, among other things, weather. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

(b)	The sum of the quarterly amounts may not equal annual earnings per share due to changes in the number of common shares outstanding during the year or rounding.

(c)	2017 reflects the retrospective application of new accounting guidance related to the income statement presentation of net periodic benefit costs adopted by PPL in January 2018. See Note 1 to the Financial Statements for additional information on the adoption of this guidance.

(d)	PPL has paid quarterly cash dividends on its common stock in every year since 1946. Future dividends, declared at the discretion of the Board of Directors, will be dependent upon future earnings, cash flows, financial requirements and other factors.

(e)

Increases in net income for the quarter ended June 30, 2018 compared with June 30, 2017 were primarily due to the favorable impact of foreign currency economic hedges. Increases in net income for the quarter ended December 31, 2018 compared with December 31, 2017 were primarily due to the favorable impact of foreign currency economic hedges in 2018 and the unfavorable impact of U.S. tax reform in 2017.

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(a)	PPL Electric's business is seasonal in nature, with peak sales periods generally occurring in the winter and summer months. Accordingly, comparisons among quarters of a year may not be indicative of overall trends and changes in operations.

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(a)	Evaluation of disclosure controls and procedures.

(b)	Changes in internal control over financial reporting.

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(a)	Effective January 25, 2019, Joanne H. Raphael was promoted to Executive Vice President, General Counsel and Corporate Secretary and Vincent Sorgi to Executive Vice President and Chief Financial Officer.

(b)	Designated an executive officer of PPL by virtue of their respective positions at a PPL subsidiary.

(c)	Effective March 1, 2019, Marlene C. Beers will become Vice President and Controller of PPL Corporation and Stephen K. Breininger will become Vice President-Finance and Regulatory Affairs and Controller of PPL Electric Utilities Corporation.

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(1)

Includes (a) the ICP, under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards were awarded to executive officers of PPL and no awards remain for issuance under this plan; (b) the ICPKE, under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards may be awarded to non-executive key employees of PPL and its subsidiaries; (c) the PPL 2012 SIP approved by shareowners in 2012 under which stock options, restricted stock, restricted stock units, performance units, dividend equivalents and other stock-based awards may be awarded to executive officers of PPL and its subsidiaries; and (d) the DDCP, under which stock units may be awarded to directors of PPL. See Note 10 to the Financial Statements for additional information.

(2)	All of PPL's current compensation plans under which equity securities of PPL are authorized for issuance have been approved by PPL's shareowners.

(3)

Relates to common stock issuable upon the exercise of stock options awarded under the ICP, SIP and ICPKE as of December 31, 2018. In addition, as of December 31, 2018, the following other securities had been awarded and are outstanding under the ICP, SIP, ICPKE and DDCP:  460,095 restricted stock units, 586,383 TSR performance awards and 226,260 ROE performance awards under the SIP; 638,109 restricted stock units 253,741 TSR performance awards and 102,698 ROE performance awards under the ICPKE; and 518,539 stock units under the DDCP.

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(4)

Based upon the following aggregate award limitations under the ICP, SIP, ICPKE and DDCP: (a) under the ICP, 15,769,431 awards (i.e., 5% of the total PPL common stock outstanding as of April 23, 1999) granted after April 23, 1999; (b) under the SIP, 15,000,000 awards; (c) under the ICPKE, 16,573,608 awards (i.e., 5% of the total PPL common stock outstanding as of January 1, 2003) granted after April 25, 2003, reduced by outstanding awards for which common stock was not yet issued as of such date of 2,373,812 resulting in a limit of 14,199,796; and (d) under the DDCP, the number of stock units available for issuance was reduced to 2,000,000 stock units in March 2012. In addition, each of the ICP and ICPKE includes an annual award limitation of 2% of total PPL common stock outstanding as of January 1 of each year.

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(a)	Includes estimated fees for audit of annual financial statements and review of financial statements included in PPL Electric's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.

(b)	Includes fees for agreed upon procedures related to Annual EPA filings.

(c)	Fees for services related to Puerto Rico hurricane recovery efforts.

(d)	Fees for a systems portfolio analysis.

(a)	Includes estimated fees for audit of annual financial statements and review of financial statements included in LKE's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.

(b)	Includes fees for agreed upon procedures related to Kentucky Energy and Environment Cabinet forms.

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(a)	Includes estimated fees for audit of annual financial statements and review of financial statements included in LG&E's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.

(b)	Includes fees for agreed upon procedures related to Kentucky Energy and Environment Cabinet forms.

(a)	Includes estimated fees for audit of annual financial statements and review of financial statements included in KU's Quarterly Reports on Form 10-Q and for services in connection with statutory and regulatory filings or engagements, including comfort letters and consents for financings and filings made with the SEC.

(b)	Includes fees for agreed upon procedures related to Kentucky Energy and Environment Cabinet forms.

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1.	Financial Statements - Refer to the "Table of Contents" for an index of the financial statements included in this report.

2.	Supplementary Data and Supplemental Financial Statement Schedule - included in response to Item 8.

3.	Exhibits

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