PPL Corporation and its subsidiaries

Other terms and abbreviations

 

Statements contained in this Annual Report concerning expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are other than statements of historical fact are "forward-looking statements" within the meaning of the federal securities laws. Although the Registrants believe that the expectations and assumptions reflected in these statements are reasonable, there can be no assurance that these expectations will prove to be correct. Forward-looking statements are subject to many risks and uncertainties, and actual results may differ materially from the results discussed in forward-looking statements. In addition to the specific factors discussed in "Item 1A. Risk Factors" and in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in this Annual Report, the following are among the important factors that could cause actual results to differ materially and adversely from the forward-looking statements:

New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time to time, and it is not possible for the Registrants to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those contained in any forward-looking statement. Any forward-looking statement speaks only as of the date on which such statement is made, and the Registrants undertake no obligation to update the information contained in the statement to reflect subsequent developments or information.

 

 

PPL's principal subsidiaries at December 31, 20172019 are shown below (* denotes a Registrant).

 

 

PPL Global is not a registrant. Unaudited annual consolidated financial statements for the U.K. Regulated Segment are furnished contemporaneously with this report on a Form 8-K with the SEC.

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

 

 

 

 

Segment Information

 

 

PPL is organized into three reportable segments as depicted in the chart above: U.K. Regulated, Kentucky Regulated, and Pennsylvania Regulated. The U.K. Regulated segment has no related subsidiary Registrants. PPL's other reportable segments' results primarily represent the results of its related subsidiary Registrants, except that the reportable segments are also allocated certain corporate level financing and other costs that are not included in the results of the applicable subsidiary Registrants. PPL also has corporate and other costs, which primarily includeincluding financing costs incurred at the corporate level that have not been allocated or assigned to the segments, as well as certain other unallocated costs. As a resultThe financial results of the June 1, 2015 spinoff of PPLSafari Energy Supply, PPL no longer has a Supply segment. The operations of the Supply segment are included in "Loss from Discontinued Operations (net of income taxes)" on the Statements of Income.also reported within Corporate and Other.

A comparison of PPL's three regulated segments is shown below.

See Note 2 to the Financial Statements for additional financial information about the segments.by segment.

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

WPD operates four of the 14 Ofgem regulated DNOs providing electricity service in the U.K. through indirect wholly owned subsidiaries: WPD (South West), WPD (South Wales), WPD (East Midlands) and WPD (West Midlands). The number of network customers (end-users) served by WPD totals 7.9 million across 21,600 square miles in south Wales and southwest and central England. See Note 3 to the Financial Statements for revenue information. WPD's operating revenues are translated from GBP to U.S. dollars using the average 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 are shown below. 2019, 2018 and 2017 were $1.28 per GBP, $1.34 per GBP, and $1.28 per GBP.

WPD’s operations are regulated by Ofgem under the direction of the Gas and Electricity Markets Authority. Ofgem is a non-ministerial government department and an independent National Regulatory Authority that is responsible for protecting the interests of existing and future electricity and natural gas consumers. The Electricity Act 1989 provides the fundamental framework for electricity companies and established licenses that require each of the DNOsDNO to develop, maintain and operate efficient distribution networks. WPD’s operations are regulated under these licenses which set the outputs WPD needs to deliver for theirto customers and associated revenues WPD is allowed to earn. WPD operates under a regulatory year that begins April 1 and ends March 31 of each year.

Ofgem has the formal power to propose modifications to each distribution license; however, licensees can appeal such changes to the U.K.’s Competition and Markets Authority in the event of a disagreement with the regulator.Authority. Generally, any potential changes to these licenses are reviewed with stakeholders in a formal regulatory consultation process prior to a formal change proposal.

Although WPD operates in non-exclusive concession areas in the U.K., it currently faces little competition with respect to end-users connected to its network. WPD's four distribution businessesDNOs are, therefore, regulated monopolies, which operateoperating under regulatory price controls.

WPD provides regulated electricity distribution services to licensed third partythird-party energy suppliers who use WPD's networks to transfer electricity to their customers, the end-users. WPD bills energy suppliers for this service and the supplier is responsible for billing its end-users. Ofgem requires that all licensed electricity distributors and suppliers become parties to the Distribution Connection and Use of System Agreement. This agreement specifies how creditworthiness will be determined and, as a result, whether thea supplier needs to collateralize its payment obligations.

WPD’s costs make up approximately 16%17% of a U.K. end-user customer’sresidential end-user's electricity bill.

Ofgem has adopted a price control regulatory framework with a balanced objective of enhancing and developing future electricity networks, for the future, controlling costs to customers and allowing DNOs, such as WPD's DNOs, to earn a fair return on their investments. This regulatory structure is focused on outputs and performance in contrast to traditional U.S. utility ratemaking that operates under a cost recovery model. Price controls are established based on long-term business plans developed by each DNO with substantial input from its stakeholders. To measure the outputs and performance, each DNO business plan includes incentive targets that allow for increases and/or reductions in revenues based on operational performance, which are intended to align returns with quality of service, innovation and customer satisfaction.

For comparative purposes, amounts listed below are in British pounds sterling, nominal prices and in calendar years unless otherwise noted.

PPL believes the U.K. electricity utility model is a premium jurisdiction in which to do business due to its significant stakeholder engagement, incentive-based structure and high-quality ratemaking mechanisms.

WPD is currently operatingoperates under an eight-year price control period called RIIO-ED1, which commenced for electricity distribution companies on April 1, 2015. The regulatory framework is based on an updated approach for sustainable network regulation known as the "RIIO" model where Revenue = Incentives + Innovation + Outputs.

WPD's combined RIIO-ED1 business plans includeas accepted by Ofgem included funding for total expenditures of approximately £12.8 billion (nominal) over the eight-year period, broken down as follows:

The chart below illustrates the building blocks of allowed revenue and GAAP net income for the U.K. Regulated Segment. The revenue components are shown in either 2012/13 prices or nominal prices, consistent with the formulas Ofgem established for RIIO-ED1. The reference numbers includedshaded in each block correspond with the descriptions that follow.

(1) Base Revenue

The base revenue that a DNO can collect in each year of the current price control period is the sum of the following, which are discussed further below:

In addition, WPD recovers approximately 80% of pension deficit funding for certain of WPD's defined benefit pension plans in conjunction with actual costs similar to the Fast pot mechanism. The pension deficit is determined by the pension trustees on a triennial basis in accordance with their funding requirements. Pension deficit funding recovered in revenues was £151 million, £147 million and £142 million in 2019, 2018 and £139 million2017. WPD expects similar amounts to be collected in 2017revenues through March 31, 2021, but cannot predict amounts that will be collected in revenues beyond then as the plans are approaching a fully funded status. The current triennial pension review commenced in March 2019 and 2016.is expected to conclude by the end of 2020.

See Note 11 to the Financial Statements for additional information on pension costs/income recognized under GAAP.

Base revenues are adjusted annually during RIIO-ED1 to arrive at allowed revenues. These adjustments are discussed in sections (9) through (13) below.

(9) MOD and Inflation True-Up (TRU)

As both MOD and TRU are changes to future base revenues as determined by Ofgem, these adjustments are recognized as a component of revenues in future years in which service is provided and revenues are collected or returned to customers. PPL's projected earnings per share growth rate through 2020 includes both the TRU and MOD for regulatory years 2015/16 and 2016/17 and the estimated TRU and MOD for 2017/18.

The annual incentives and penalties are reflected in customer rates on a two-year lag from the time they are earned and/or assessed. Based on applicable GAAP, incentive revenues and penalties are recorded in revenues when they are billed to customers. The following table shows the amount of incentive revenues (in total), primarily from IIS, BMCS and TTC that WPD has received and is projected to receive on a calendar year basis:

Historically, tariffs have been set a minimum of three months prior to the beginning of the regulatory year (April 1). In February 2015, Ofgem determined that, beginning with the 2017/18 regulatory year, tariffs would be established a minimum of fifteen months in advance. Therefore, in December 2015, WPD was required to establish tariffs for the 2016/17 and 2017/18 regulatory years. This change will potentially increase volatility in future revenue forecasts due to the need to forecast components of allowed revenue including MOD, TRU, K-factor and incentive revenues.

In the 2016/17 regulatory year, WPD recovered a £5 per residential network customer reduction given through reduced tariffs in 2014/15. As a result, revenues were positively affected in calendar yearsyear 2017 and 2016 by £13 million and £25 million.

As the regulatory model in the U.K. is incentive based rather than a cost recovery model, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. Therefore, the accounting treatment for the accelerated recovery ofdifferences in the amounts collected in revenues and the amounts recorded for expenses related to depreciation, pension deficit funding,pensions, cost of debt recovery,and income tax recoverytaxes, and the adjustments to base revenue and/or allowed revenue isare evaluated primarily based on revenue recognition guidance.

See "Revenue Recognition" in Note 1 to the Financial Statements for additional information.

See "Overview - Financial and Operational Developments - RIIO-2 Framework" in "Item 1A. Risk Factors - Risks related to our U.K. Regulated Segment"7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" for additional information on the risks associated with the U.K. Regulated Segment.RIIO-2 Framework which will commence on April 1, 2023.

 

LG&E and KU, direct subsidiaries of LKE, are engaged in the regulated generation, transmission, distribution and sale of electricity in Kentucky and, in KU's case, Virginia and Tennessee.also Virginia. LG&E also engages in the distribution and sale of natural gas in Kentucky. LG&E provides electricelectricity service to approximately 411,000418,000 customers in Louisville and adjacent areas in Kentucky,

covering approximately 700 square miles in nine counties and provides natural gas service to approximately 326,000329,000 customers in its electricelectricity service area and eight additional counties in Kentucky. KU provides electric service to approximately 525,000530,000 customers in 77 counties in central, southeastern and western Kentucky and approximately 28,000 customers in five counties in southwestern Virginia, and three customers in Tennessee, covering approximately 4,800 non-contiguous square miles. KU also sells wholesale electricity to 10two municipalities in Kentucky under load following contracts. See Note 3 to the Financial Statements for revenue information.

 

 

LG&E and KU provide electricity delivery service, and LG&E provides natural gas distribution service, in their respective service territories pursuant to certain franchises, licenses, statutory service areas, easements and other rights or permissions granted by state legislatures, cities or municipalities or other entities. 

 

There are currently no other electric public utilities operating within the electricelectricity service areas of LKE. From time to time, bills are introduced into the Kentucky General Assembly which seek to authorize, promote or mandate increased distributed generation, customer choice or other developments. Neither the Kentucky General Assembly nor the KPSC has adopted or approved a plan or timetable for retail electric industry competition in Kentucky. The nature or timing of legislative or regulatory actions, if any, regarding industry restructuring and their impact on LKE, which may be significant, cannot currently

 

Alternative energy sources such as electricity, oil, propane and other fuels indirectly impact LG&E's natural gas revenues. Marketers may also compete to sell natural gas to certain large end-users. LG&E's natural gas tariffs include gas price pass-through mechanisms relating to its sale of natural gas as a commodity; therefore,commodity. Therefore, customer natural gas purchases from alternative suppliers do not generally impact LG&E's profitability. Some large industrial and commercial customers, however, may physically bypass LG&E's facilities and seek delivery service directly from interstate pipelines or other natural gas distribution systems.

 

At December 31, 2017,2019, LKE owned controlled or had a minority ownership interest in generating capacity of 8,0177,561 MW, of which 2,9202,786 MW related to LG&E and 5,0974,775 MW related to KU, in Kentucky, Indiana, and Ohio.KU. See "Item 2. Properties - Kentucky Regulated Segment" for a complete list of LKE's generating facilities.

 

The system capacity of LKE's owned or controlled generation is based upon a number of factors, including the operating experience and physical condition of the units, and may be revised periodically to reflect changes in circumstances.

 

During 2017,2019, LKE's power plants generated the following amounts of electricity.electricity: