Attached files

file filename
EX-32 - EX-32 - TAMPA ELECTRIC COck0000096271-ex32_6.htm
EX-31.2 - EX-31.2 - TAMPA ELECTRIC COck0000096271-ex312_7.htm
EX-31.1 - EX-31.1 - TAMPA ELECTRIC COck0000096271-ex311_8.htm
EX-23 - EX-23 - TAMPA ELECTRIC COck0000096271-ex23_9.htm
EX-10.12 - EX-10.12 - TAMPA ELECTRIC COck0000096271-ex1012_172.htm
EX-10.4 - EX-10.4 - TAMPA ELECTRIC COck0000096271-ex104_171.htm

1

g

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-K

 

Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended December 31, 2019

OR

Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from                      to                     

 

Commission

File No.

  

Exact name of each Registrant as specified in its charter, state of incorporation, address of principal executive offices, telephone number

  

I.R.S. Employer

Identification

Number

1-5007

  

TAMPA ELECTRIC COMPANY

  

59-0475140

 

  

(a Florida corporation)

  

 

 

  

TECO Plaza

  

 

 

  

702 N. Franklin Street

  

 

 

  

Tampa, Florida 33602

  

 

 

  

(813) 228-1111

  

 

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

 

Trading symbol(s)

 

Name of each exchange on which registered

None

 

 

 

 

Securities registered pursuant to Section 12(g) of the Act:

None

 

 

 

 

(Title of class)

 

 

 

 

Indicate by check mark if Tampa Electric Company is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

YES      NO  

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.

YES      NO  

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

YES      NO  

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

YES      NO  

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Indicate by check mark whether Tampa Electric Company is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer

 

  

Accelerated filer

 

 

 

 

 

Non-accelerated filer

 

  

Smaller reporting company

 

 

 

 

 

 

 

 

 

 

 

  

Emerging growth company

 

If an emerging growth company, indicate by check mark whether Tampa Electric Company has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.    

Indicate by check mark whether Tampa Electric Company is a shell company (as defined in Rule 12b-2 of the Act).

YES      NO  

The aggregate market value of Tampa Electric Company’s common stock held by non-affiliates of the registrant as of June 30, 2019 was zero.

As of February 12, 2020, there were 10 shares of Tampa Electric Company’s common stock issued and outstanding, all of which were held, beneficially and of record, by TECO Energy, Inc, an indirect wholly-owned subsidiary of Emera Inc.

 

Tampa Electric Company meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format specified in General Instruction I(2) of Form 10-K.

 

 

 

 

 


DEFINITIONS

Acronyms and defined terms used in this and other filings with the U.S. Securities and Exchange Commission include the following:

 

Term

  

Meaning

 

 

 

AFUDC

 

allowance for funds used during construction

AFUDC-debt

 

debt component of allowance for funds used during construction

AFUDC-equity

 

equity component of allowance for funds used during construction

APBO

 

accumulated postretirement benefit obligation

ARO

 

asset retirement obligation

ASC

 

Accounting Standards Codification

CAD

 

Canadian dollars

CAIR

 

Clean Air Interstate Rule

CCRs

 

coal combustion residuals

CMO

 

collateralized mortgage obligation

CNG

 

compressed natural gas

CPI

 

consumer price index

CSAPR

 

Cross State Air Pollution Rule

CO2

 

carbon dioxide

CT

 

combustion turbine

ECRC

 

environmental cost recovery clause

Emera

 

Emera Inc., a geographically diverse energy and services company headquartered in Nova Scotia, Canada

EPA

 

U.S. Environmental Protection Agency

ERISA

 

Employee Retirement Income Security Act

EROA

 

expected return on plan assets

EUSHI

 

Emera US Holdings Inc., a wholly owned subsidiary of Emera, which is the sole shareholder of TECO Energy’s common stock

FASB

 

Financial Accounting Standards Board

FDEP

 

Florida Department of Environmental Protection

FERC

 

Federal Energy Regulatory Commission

FPSC

 

Florida Public Service Commission

IGCC

 

integrated gasification combined-cycle

IOU

 

investor owned utility

IRS

 

Internal Revenue Service

ITCs

 

investment tax credits

kWac

 

kilowatt on an alternating current basis

LNG

 

liquefied natural gas

MBS

 

mortgage-backed securities

MD&A

 

the section of this report entitled Management’s Discussion and Analysis of Financial Condition and Results of Operations

Merger

 

Merger of Merger Sub Company with and into TECO Energy, with TECO Energy as the surviving corporation

MGP

 

manufactured gas plant

MMBTU

 

one million British Thermal Units

MRV

 

market-related value

MW

 

megawatt(s)

MWH

 

megawatt-hour(s)

NAV

 

net asset value

Note

 

Note to consolidated financial statements

NPNS

 

normal purchase normal sale

O&M expenses

 

operations and maintenance expenses

OCI

 

other comprehensive income

OPC

 

Office of Public Counsel

OPEB

 

other postemployment benefits

Parent

 

TECO Energy, Inc., the direct parent company of Tampa Electric Company

PBGC

 

Pension Benefit Guarantee Corporation

PBO

 

projected benefit obligation

PGA

 

purchased gas adjustment

PGS

 

Peoples Gas System, the gas division of Tampa Electric Company

PPA

 

power purchase agreement

3


Term

  

Meaning

PRP

 

potentially responsible party

R&D

 

research and development

REIT

 

real estate investment trust

RFP

 

request for proposal

ROE

 

return on common equity

Regulatory ROE

 

return on common equity as determined for regulatory purposes

S&P

 

Standard and Poor’s

SCR

 

selective catalytic reduction

SEC

 

U.S. Securities and Exchange Commission

SoBRAs

 

solar base rate adjustments

SERP

 

Supplemental Executive Retirement Plan

STIF

 

short-term investment fund

Tampa Electric

 

Tampa Electric, the electric division of Tampa Electric Company

TEC

 

Tampa Electric Company

TECO Energy

 

TECO Energy, Inc., the direct parent company of Tampa Electric Company

TSI

 

TECO Services, Inc.

U.S. GAAP

 

generally accepted accounting principles in the United States

VIE

 

variable interest entity

 

 

 

4


PART I

 

 

Item 1. BUSINESS

Tampa Electric Company, referred to as TEC, was incorporated in Florida in 1899 and was reincorporated in 1949. TEC is a public utility operating within the State of Florida. TEC has two operating segments. Its electric division, referred to as Tampa Electric, provides retail electric service to approximately 779,000 customers in West Central Florida with a net winter system generating capacity of 5,641 MW at December 31, 2019. The gas division of TEC, referred to as PGS, is engaged in the purchase, distribution and sale of natural gas for residential, commercial, industrial and electric power generation customers in Florida. With approximately 406,000 customers, PGS has operations in Florida’s major metropolitan areas. Annual natural gas throughput (the amount of gas delivered to its customers, including transportation-only service) in 2019 was approximately 2.1 billion therms. TEC had approximately 3,110 employees as of December 31, 2019. All of TEC’s common stock is owned by TECO Energy, a holding company. TECO Energy is an indirect wholly owned subsidiary of Emera. Therefore, TEC is an indirect wholly owned subsidiary of Emera.

TEC makes its SEC filings available free of charge on Tampa Electric’s website (www.tampaelectric.com/company/about/) as soon as reasonably practicable after they are filed with the SEC. TEC’s electronic SEC filings are also available on the SEC’s website (www.sec.gov).

TEC Revenues

TEC’s revenues consist of sales to residential, commercial, industrial and other customers. TEC’s residential load generally comprises of individual homes, apartments and condominiums. Commercial customers include small retail operations, large office and commercial complexes, universities and hospitals. Industrial customers include manufacturing facilities, power generation customers and other large volume operations. Other sales volumes consist primarily of off-system sales to other utilities and revenues from street lighting.

For TEC’s revenue and other financial information by operating segments, see Note 11 to the 2019 Annual TEC Consolidated Financial Statements.

TAMPA ELECTRIC – Electric Operations

TEC’s Tampa Electric division is engaged in the generation, purchase, transmission, distribution and sale of electric energy. The retail territory served comprises an area of about 2,000 square miles in West Central Florida, including Hillsborough County and parts of Polk, Pasco and Pinellas Counties. The principal communities served are Tampa, Temple Terrace, Winter Haven, Plant City and Dade City. Tampa Electric engages in wholesale sales to utilities and other resellers of electricity. It has two generating stations in or near Tampa, one generating station in southwestern Polk County, Florida and twelve photovoltaic power stations, seven in Hillsborough County (of which two were placed in service in early 2020) and five in Polk County, Florida. Tampa Electric had approximately 2,450 employees as of December 31, 2019, of which 740 were represented by the International Brotherhood of Electrical Workers and 200 were represented by the Office and Professional Employees International Union. In December 2019, 370 TSI employees were transferred to Tampa Electric. The transfer of these employees to Tampa Electric is expected to create operational synergies in the organization but is not expected to materially impact shared service costs or the TEC Consolidated Statement of Income.

The sources of Tampa Electric’s operating revenue and MWH sales were as follows:

Tampa Electric Operating Revenue

 

(millions)

 

2019

 

 

2018

 

 

2017

 

Residential

 

$

1,046

 

 

$

1,067

 

 

$

1,006

 

Commercial

 

 

562

 

 

 

582

 

 

 

578

 

Industrial

 

 

156

 

 

 

161

 

 

 

158

 

Other sales of electricity

 

 

183

 

 

 

187

 

 

 

168

 

Regulatory deferrals and unbilled revenue

 

 

(49

)

 

 

(2

)

 

 

78

 

Total energy sales

 

 

1,898

 

 

 

1,995

 

 

 

1,988

 

Off system sales

 

 

6

 

 

 

11

 

 

 

8

 

Other

 

 

61

 

 

 

60

 

 

 

58

 

Total revenues

 

$

1,965

 

 

$

2,066

 

 

$

2,054

 

5


Megawatt-hour Sales

 

(thousands)

 

2019

 

 

2018

 

 

2017

 

Residential

 

 

9,584

 

 

 

9,418

 

 

 

9,029

 

Commercial

 

 

6,240

 

 

 

6,266

 

 

 

6,362

 

Industrial

 

 

2,021

 

 

 

2,014

 

 

 

2,024

 

Other sales of electricity

 

 

1,939

 

 

 

1,933

 

 

 

1,771

 

Total retail

 

 

19,784

 

 

 

19,631

 

 

 

19,186

 

Off system sales

 

 

155

 

 

 

286

 

 

 

239

 

Total energy sold

 

 

19,939

 

 

 

19,917

 

 

 

19,425

 

No significant part of Tampa Electric’s business is dependent upon a single or limited number of customers where the loss of any one or more would have a significant adverse effect on Tampa Electric. Tampa Electric experiences winter peak loads due to electric space heating, fewer daylight hours and colder temperatures and summer peak loads due to the use of air conditioning and other cooling equipment.

Regulation

Base Rates

Tampa Electric’s retail operations are regulated by the FPSC. The FPSC’s objective is to set rates at a level that provides an opportunity for the utility to collect total revenues (revenue requirements) equal to its prudently incurred costs of providing service to customers, plus a reasonable return on invested capital.

The costs of owning, operating and maintaining the utility systems, excluding fuel, conservation costs, purchased power and certain environmental costs, are recovered through base rates. These costs include O&M expenses, depreciation, taxes, and a return on investment in assets providing electric service (rate base). The rate of return on rate base, which is intended to approximate a company’s weighted cost of capital, primarily includes its costs for debt, deferred income taxes (at a zero cost rate) and an allowed ROE. Base rates are determined in FPSC rate setting hearings which occur at the initiative of Tampa Electric, the FPSC or other interested parties.

Tampa Electric’s results for 2017 reflect the stipulation and settlement agreement entered into on September 6, 2013, which resolved all matters in Tampa Electric’s 2013 base rate proceeding. The agreement provided for Tampa Electric’s allowed regulatory ROE to be a mid-point of 10.25% with a range of plus or minus 1%. The agreement stated that Tampa Electric could not file for additional base rate increases to be effective sooner than January 1, 2018, unless its earned ROE were to fall below 9.25% before that time. If its earned ROE were to rise above 11.25%, any party to the agreement other than Tampa Electric could seek a review of its base rates. In addition, Tampa Electric is required to file a depreciation study no fewer than 90 days but no more than one year before filing its next base rate request. Under the agreement, the allowed equity in the capital structure is 54% from investor sources of capital, and Tampa Electric also began using a 15-year amortization period for all computer software.

 

Tampa Electric’s results for 2019 and 2018 reflect an amended and restated settlement agreement, approved by the FPSC on November 6, 2017, that replaced the existing 2013 base rate settlement agreement described above and extended it another four years through 2021.The amended agreement provides for SoBRAs for TEC’s substantial investments in solar generation. Tampa Electric plans to invest approximately $850 million in these solar projects during the period from 2017 to 2021, of which approximately $820 million has been invested through December 31, 2019, and is accruing AFUDC during construction. The agreement includes a sharing provision that allows customers to benefit from 75% of any cost savings for projects below $1,500/kWac. TEC began receiving revenues of $24 million annually for the first tranche of 145 MW in September 2018, $46 million annually for the second tranche of 260 MW in January 2019 and $26 million annually for the third tranche of 149 MW in January 2020. TEC expects to file its final SoBRA petition for the January 1, 2021 tranche in 2020. See Note 3 to the 2019 Annual TEC Consolidated Financial Statements for further information regarding TEC’s SoBRA petitions.

 

The agreement further maintains Tampa Electric’s allowed regulatory ROE and allowed equity in the capital structure and extends the rate freeze date from January 1, 2018 to December 31, 2021, subject to the same ROE thresholds. The agreement further contains a provision related to tax reform (see Note 4 to the 2019 Annual TEC Consolidated Financial Statements for further information on tax reform). Additionally, an asset optimization provision that allows Tampa Electric to share in the savings for optimization of its system once certain thresholds are achieved is also included. Tampa Electric agreed to a financial hedging moratorium for natural gas ending on December 31, 2022 and that it will make no investments in gas reserves.

 

On November 13, 2019, as required by the 2017 settlement agreement, TEC filed its petition to reduce base rates and charges to reflect the impact of the temporary reduction of the state corporate income tax from 5.5% to 4.46%. The tax rate reduction was issued

6


on September 12, 2019 and is effective retroactive from January 1, 2019 through December 31, 2021. The estimated base rate reduction due to customers of $5 million is subject to true-up, and the actual rate reduction may vary from year to year. The base rate reduction was approved on December 10, 2019 for rates effective January 2020.

 

As a result of several named storms in 2017, the amount of costs charged to the storm reserve regulatory liability in 2017 exceeded the balance in the storm reserve by $47 million. On January 30, 2018, Tampa Electric filed an implementation settlement agreement with the FPSC that addressed both the recovery of storm costs and the return of U.S. tax reform benefits to customers while keeping customer rates stable in 2018.  The agreement, which was approved by the FPSC on March 1, 2018, authorized Tampa Electric to net the estimated amount of storm cost recovery, including replenishment of the storm reserve to the $56 million level that existed as of October 31, 2013, against Tampa Electric’s estimated 2018 tax reform benefits. On August 20, 2018, the FPSC approved lowering base rates by $103 million annually beginning on January 1, 2019 as a result of lower tax expense. On May 21, 2019, the FPSC approved a settlement agreement reached by Tampa Electric and consumer parties regarding eligible storm costs, which resulted in Tampa Electric refunding $12 million to customers in January 2020. See Note 3 to the 2019 Annual TEC Consolidated Financial Statements for further information on the settlement agreement.

Other Cost Recovery

Tampa Electric has four cost recovery clauses.

 

(1)

Tampa Electric has a fuel recovery clause allowing recovery of actual fuel costs from customers through annual fuel rate adjustments. Differences between actual prudently incurred fuel costs and amounts recovered from customers in a year are recovered from or returned to customers in a subsequent year.

 

(2)

Tampa Electric has a capacity recovery clause allowing recovery of firm demand payments associated with purchased power agreements.

 

(3)

Tampa Electric has an environmental cost recovery clause which allows it to earn a return on investments in new facilities to comply with new environmental regulations and to recover the costs to operate and maintain these facilities.

 

(4)

Through its conservation cost recovery clause, Tampa Electric offers its customers a comprehensive array of residential and commercial programs that have enabled it to meet its required demand side management goals, reduce weather-sensitive peak demand and conserve energy.

During November 2019, the FPSC approved cost-recovery rates for the above clauses for 2020. On October 3, 2019, the FPSC issued a rule to implement a storm protection plan cost recovery clause. This new clause establishes a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Subject to final approval of a FPSC rule, Tampa Electric expects to file a storm protection plan with the FPSC in the second quarter of 2020.

FERC and Other Regulations

Tampa Electric is subject to regulation by the FERC in various respects, including wholesale power sales, certain wholesale power purchases, transmission and ancillary services and accounting practices.

Tampa Electric is subject to federal, state and local environmental laws and regulations pertaining to air and water quality, land use, power plant, substation and transmission line siting, noise and aesthetics, solid waste and other environmental matters (see the Environmental Compliance section of the MD&A).

Competition

Tampa Electric’s retail electric business is substantially free from direct competition with other electric utilities, municipalities and public agencies. The principal form of competition at the retail level consists of self-generation available to larger users of electric energy. Such users may seek to expand their alternatives through various initiatives, including legislative and/or regulatory changes that would permit competition at the retail level. Tampa Electric intends to retain and expand its retail business by managing costs and providing quality service to retail customers.

Unlike in the retail electric business, Tampa Electric competes in the wholesale power market with other energy providers in Florida, including approximately 30 other utilities and other power generators. Entities compete to provide energy on a short-term basis (i.e., hourly or daily) and on a long-term basis. Tampa Electric is not a major participant in the wholesale market because it uses its lower-cost generation primarily to serve its retail customers rather than the wholesale market.

FPSC rules promote cost-competitiveness in the building of new steam generating capacity or solar capacity by requiring IOUs, such as Tampa Electric, to issue RFPs prior to filing a petition for Determination of Need for construction of a power plant with a

7


steam cycle or solar capacity greater than 75 MWs. These rules allow independent power producers and others to bid to supply the new generating capacity.

In many areas of the country, there is growing use of rooftop solar panels, small wind turbines and other small-scale methods of power generation, known as distributed generation, by individual residential, commercial and industrial customers, or by third-party developers. Distributed generation is encouraged and supported by special interest groups, tax incentives, renewable portfolio standards and special rates designed to support such generation. Developers offer attractive financing and leasing arrangements to encourage project development. In Florida, third parties that are not subject to regulation by the FPSC are currently not permitted to make direct sales of electricity to end-use customers.

Generation Sources

In 2019 and 2018, approximately 90% and 82%, respectively, of Tampa Electric’s generation of electricity was natural gas-fired, with coal representing approximately 6% and 15%, respectively, solar representing 4% and 1%, respectively, and oil/petroleum coke representing 0 and 2%, respectively. As a result of low gas prices in the market in 2019, units 1, 2 and 3 at Big Bend Power Station and unit 1 at Polk Power Station (TEC’s IGCC unit) operated solely on natural gas during 2019, significantly reducing coal generation in 2019. In 2019 and 2018, Tampa Electric used its generating units to meet approximately 93% and 94%, respectively, of the total system load requirements, with the remaining 7% and 6%, respectively, coming from purchased power. Tampa Electric is required to maintain a generation capacity greater than firm peak demand. Tampa Electric meets the planning criteria for reserve capacity established by the FPSC, which is a 20% reserve margin over firm peak demand. See MD&A - Capital Investments for information regarding TEC’s forecasted capital investments in generation sources, including solar projects and the modernization of the Big Bend Power Station.

The table below presents Tampa Electric’s average delivered fuel cost per MMBTU, excluding solar production which has no fuel cost.

 

Average cost per MMBTU

 

2019

 

 

2018

 

 

2017

 

Natural Gas (1)

 

$

3.40

 

 

$

4.07

 

 

$

4.01

 

Coal (2)

 

 

3.66

 

 

 

3.37

 

 

 

3.30

 

Oil/petroleum coke (3)

 

 

22.01

 

 

 

3.10

 

 

 

2.54

 

Composite (4)

 

 

3.43

 

 

 

3.89

 

 

 

3.69

 

 

(1)

Represents the cost of natural gas, transportation, storage, balancing, hedges for the price of natural gas, and fuel losses for delivery to the energy center.

(2)

Represents the cost of coal and transportation.

(3)

In 2019, the cost per MMBTU represents 100% oil.

(4)

Represents the average cost for all fuels listed.

Tampa Electric’s fuel costs are affected by commodity prices and generation mix that is largely dependent on economic dispatch of the generating fleet, dispatching the lowest fuel cost options first (solar renewable energy being zero fuel costs), such that the incremental cost of generation increases as sales volumes increase. Generation mix may also be affected by plant outages, plant performance, availability of lower priced short-term purchased power, compliance with environmental standards and regulations, and availability of solar resources.

Natural Gas. Tampa Electric maintains gas commodity, pipeline transportation and storage contracts. As of December 31, 2019, approximately 81% of Tampa Electric’s 2.0 million BCF gas storage capacity was full. Tampa Electric has contracted for 71% of its expected gas needs for the January through December 2020 period. Tampa Electric expects to issue RFPs to meet its remaining 2020 gas needs and begin contracting for its 2021 requirements. Additional volume requirements are purchased in the short-term spot market.

Coal. Tampa Electric burned approximately 0.6 million tons of coal during 2019 and estimates that its coal consumption will be about 0.4 million tons in 2020. During 2019, Tampa Electric purchased its coal under contracts with two suppliers. Tampa Electric expects to obtain its coal requirements in 2020 under a short-term contract with one supplier. Tampa Electric has coal transportation agreements with a rail provider if spot coal supplies are needed.    

Tampa Electric’s contracts provide for revisions in the base price to reflect changes in several important cost factors and for suspension or reduction of deliveries if environmental regulations should prevent Tampa Electric from burning the coal supplied, provided that a good faith effort has been made to continue burning such coal.

Oil. Tampa Electric purchases low sulfur No. 2 fuel oil and petroleum coke for its Polk Power station on a spot basis.

8


Franchises and Other Rights

Florida utilities must obtain franchises to operate in certain municipalities. Tampa Electric holds franchises and other rights that, together with its charter powers, govern the placement of Tampa Electric’s facilities on the public rights-of-way that it carries for its retail business in the localities it serves. The franchises specify the negotiated terms and conditions governing Tampa Electric’s use of public rights-of-way and other public property within the municipalities it serves during the term of the franchise agreement. The franchises are irrevocable and not subject to amendment without the consent of Tampa Electric (except to the extent certain city ordinances relating to permitting and like matters are modified from time to time), although, in certain events, they are subject to forfeiture. Florida municipalities are prohibited from granting any franchise for a term exceeding 30 years.

Tampa Electric has franchise agreements with 13 incorporated municipalities within its retail service area. These agreements have various expiration dates ranging through 2049 and are expected to be renewed under similar terms and conditions.

Franchise fees expense totaled $45 million and $47 million in 2019 and 2018, respectively. Franchise fees are calculated using a formula based primarily on electric revenues and are recovered from customers.

Utility operations in Hillsborough, Pinellas and Polk Counties outside of incorporated municipalities are conducted in each case under one or more permits granted by the Florida Department of Transportation or the County Commissioners of such counties. There is no law limiting the time for which such permits may be granted. There are no fixed expiration dates for the Hillsborough County, Pinellas County and Polk County agreements.

Environmental Matters

Tampa Electric operates stationary sources with air emissions regulated by the Clean Air Act. Its operations are also impacted by provisions in the Clean Water Act and federal and state legislative initiatives on environmental matters. TEC, through its Tampa Electric and PGS divisions, is a PRP for certain superfund sites and, through its PGS division, for certain former manufactured gas plant sites. See Environmental Compliance section of the MD&A for additional information.

PEOPLES GAS SYSTEM – Gas Operations

PGS is engaged in the purchase, distribution and sale of natural gas for residential, commercial, industrial and electric power generation customers in the state of Florida.

Gas is delivered to the PGS distribution system through three interstate pipelines. PGS does not engage in the exploration for or production of natural gas. PGS operates a natural gas distribution system that serves approximately 406,000 customers. The system includes approximately 13,500 miles of gas mains and 7,500 miles of service lines (see PGS’s Franchises and Other Rights section below).

PGS had approximately 660 employees as of December 31, 2019. Approximately 120 employees in five of PGS’s 14 service areas and call center are represented by various union organizations.

In 2019, the total throughput for PGS was approximately 2.1 billion therms. Of this total throughput, 5% was gas purchased and resold to customers by PGS, 86% was third-party supplied gas that was delivered to transportation-only customers and 9% was gas sold off-system (i.e., to customers not connected to PGS’s distribution system).

PGS provides transportation service to customers utilizing gas-fired technology in the production of electric power. In addition, PGS provides gas transportation service to large LNG facilities located in Jacksonville, Florida. PGS has seen continuing interest and development in natural gas vehicles. There are 54 compressed natural gas filling stations connected to the PGS distribution system. See the PGS Operating Results section of the MD&A for information on the impact of natural gas vehicles on PGS’s operations.

Revenues and therms for PGS for the years ended December 31 were as follows:

 

 

 

Revenues

 

 

Therms

 

(millions)

 

2019

 

 

2018

 

 

2017

 

 

2019

 

 

2018

 

 

2017

 

Residential

 

$

154

 

 

$

157

 

 

$

138

 

 

 

85

 

 

 

87

 

 

 

77

 

Commercial

 

 

146

 

 

 

151

 

 

 

144

 

 

 

517

 

 

 

510

 

 

 

489

 

Industrial

 

 

16

 

 

 

16

 

 

 

15

 

 

 

430

 

 

 

361

 

 

 

330

 

Off-system sales

 

 

55

 

 

 

78

 

 

 

70

 

 

 

188

 

 

 

217

 

 

 

201

 

Power generation

 

 

5

 

 

 

5

 

 

 

5

 

 

 

853

 

 

 

791

 

 

 

750

 

Other revenues

 

 

72

 

 

 

69

 

 

 

54

 

 

 

-

 

 

 

-

 

 

 

-

 

Total

 

$

448

 

 

$

476

 

 

$

426

 

 

 

2,073

 

 

 

1,966

 

 

 

1,847

 

9


No significant part of PGS’s business is dependent upon a single or limited number of customers where the loss of any one would have a significant adverse effect on PGS. PGS experiences winter peak throughputs due to colder temperatures.

Regulation

Base Rates

The operations of PGS are regulated by the FPSC separately from the regulation of Tampa Electric. The FPSC seeks to set rates at a level that provides an opportunity for a utility to collect total revenues (revenue requirements) equal to its prudently incurred costs of providing service to customers, plus a reasonable return on invested capital.

The costs of providing natural gas service, other than the costs of purchased gas and interstate pipeline capacity, are recovered through base rates. Base rates are designed to recover the costs of owning, operating and maintaining the utility system. The rate of return on rate base, which is intended to approximate PGS’s weighted cost of capital, primarily includes its cost for debt, deferred income taxes (at a zero cost rate), and an allowed ROE. Base rates are determined in FPSC rate setting hearings which occur at irregular intervals at the initiative of PGS, the FPSC or other parties.

In May 2009, PGS’s base rates were established with base rates set at 10.75%. The allowed equity in capital structure is 54.7% from all investor sources of capital.

On February 7, 2017, the FPSC approved a settlement agreement filed by PGS and the OPC agreeing to new depreciation rates, accelerate the amortization of the regulatory asset associated with environmental remediation costs as described below, include obsolete plastic pipe replacements through the existing cast iron and bare steel replacement rider, and establish an ROE range of 9.25% to 11.75%. The settlement agreement provided that the bottom of the range will remain until the earlier of new base rates established in PGS’s next general base rate proceeding or December 31, 2020 and the ROE of 10.75% will continue to be used for the calculation of return on investment for clauses and riders.

As part of the 2017 settlement, PGS and the OPC agreed that at least $32 million of PGS’s regulatory asset associated with the environmental liability for current and future remediation costs related to former MGP sites, to the extent expenses are reasonably and prudently incurred, will be amortized over the period 2016 through 2020. At least $21 million of that amount will be amortized over a two-year recovery period beginning in 2016. In 2017 and 2016, PGS recorded $5 million and $16 million, respectively, of this amortization expense.  

The 2017 PGS settlement did not contain a provision for tax reform. In 2018, the FPSC approved a settlement agreement authorizing PGS to accelerate in 2018 the remaining amortization of PGS’s regulatory asset associated with the MGP environmental liability up to the $32 million to net it against the estimated 2018 tax reform benefits. Therefore, PGS recorded amortization expense and a regulatory asset reduction of $11 million in 2018. In January 2019, PGS reduced its base rates by $12 million for the impact of tax reform and reduced depreciation rates by $10 million in accordance with the settlement agreement.

PGS is permitted to initiate a general base rate proceeding during 2020 regardless of its earned ROE at the time, provided the new rates do not become effective before January 1, 2021. As a result of increased forecasted revenue requirements, on February 7, 2020, PGS notified the FPSC that it is planning to file a base rate proceeding in April for new rates effective January 2021.  

Cost Recovery Clauses and Riders

PGS recovers the costs it pays for gas supply and interstate transportation for system supply through a PGA clause. This clause is designed to recover the actual costs incurred by PGS for purchased gas, gas storage services, interstate pipeline capacity, and other related items associated with the purchase, distribution, and sale of natural gas to its customers. These charges may be adjusted monthly based on a cap approved annually in an FPSC hearing. The cap is based on estimated costs of purchased gas and pipeline capacity, and estimated customer usage for a calendar year recovery period, with a true-up adjustment to reflect the variance of actual costs and usage from the projected charges for prior periods. The current PGA cap rate, effective January 2020, was approved by the FPSC in November 2019.

In addition to its base rates and PGA clause charges, PGS customers (except interruptible customers) also pay a per-therm charge for energy conservation and pipeline replacement programs as described above. The conservation charge is intended to permit PGS to recover prudently incurred expenditures in developing and implementing cost effective energy conservation programs which are mandated by Florida law and approved and monitored by the FPSC. PGS is also permitted to recover the return on, depreciation expenses and applicable taxes associated with the replacement of cast iron/bare steel infrastructure. The FPSC approved a replacement program of approximately 5%, or 500 miles, of the PGS system over a 10-year period beginning in 2013. As disclosed above, in February 2017, the FPSC approved an amendment to the cast iron bare steel rider to include certain plastic materials and pipe deemed obsolete by Pipeline and Hazardous Materials Safety Administration, totaling approximately 550 miles. PGS estimates that all cast

10


iron and bare steel pipe will be removed from its system by 2022, with the replacement of obsolete plastic pipe continuing until 2028 under the rider.

FPSC and Other Regulation

The FPSC requires natural gas utilities to offer transportation-only service to all non-residential customers. In addition to economic regulation, PGS is subject to the FPSC’s safety jurisdiction, pursuant to which the FPSC regulates the construction, operation and maintenance of PGS’s distribution system.

PGS is subject to federal, state and local environmental laws and regulations pertaining to air and water quality, land use, noise and aesthetics, solid waste and other environmental matters (see the Environmental Compliance section of the MD&A).

Competition

Although PGS is not in direct competition with any other regulated local distributors of natural gas for customers within its service areas, there are other forms of competition. The principal form of competition for residential and small commercial customers is from companies providing other sources of energy, including electricity, propane and fuel oil. There is also competition from other local distributors of natural gas to establish service territories in unserved areas of Florida. 

Competition is most prevalent in the large commercial and industrial markets. These classes of customers have been approached by companies seeking to sell gas directly by transporting gas through other facilities and thereby bypassing the PGS system. In response to this competition, PGS has developed various programs, including the provision of transportation-only services at discounted rates.

In Florida, gas service is unbundled for all non-residential customers. PGS offers unbundled transportation service to all non-residential customers, and residential customers consuming in excess of 1,999 therms annually, allowing these customers to purchase commodity gas from a third party but continue to pay PGS for the transportation. Because the commodity portion of bundled sales is included in operating revenues at the cost of the gas on a pass-through basis, there is no net earnings effect when a customer shifts to transportation-only sales. As a result, PGS receives its base rate for distribution regardless of whether a customer decides to opt for transportation-only service or continue bundled service. As of December 31, 2019, PGS had approximately 26,100 transportation-only customers out of approximately 39,700 eligible customers.

Gas Supplies

PGS purchases gas from various suppliers depending on the needs of its customers. The gas is delivered to the PGS distribution system through three interstate pipelines on which PGS has reserved firm transportation capacity for delivery by PGS to its customers.

Companies with firm pipeline capacity receive priority in scheduling deliveries during times when the pipeline is operating at its maximum capacity. PGS presently holds sufficient firm capacity to permit it to meet the gas requirements of its system commodity customers, except during certain weather events and localized emergencies affecting the PGS distribution system.

Firm transportation rights on an interstate pipeline represent a right to use the amount of the capacity reserved for transportation of gas on any given day. PGS pays reservation charges on the full amount of the reserved capacity whether or not it actually uses such capacity on any given day. When the capacity is actually used, PGS pays a volumetrically-based usage charge for the amount of the capacity actually used. The levels of the reservation and usage charges are regulated by the FERC. PGS actively markets any excess capacity available to partially offset costs recovered through the PGA clause.

PGS procures natural gas supplies using base-load contracts and swing-supply contracts (i.e., short-term contracts without a specified volume) with various suppliers along with spot market purchases. Pricing generally takes the form of either a variable price based on published indices or a fixed price for the contract term.

Franchises and Other Rights

PGS holds franchise and other rights with 116 municipalities and districts throughout Florida. These franchises govern the placement of PGS’s facilities on the public rights-of-way as it carries on its retail business in the localities it serves. The franchises are irrevocable and are not subject to amendment without the consent of PGS.

Municipalities are prohibited from granting any franchise for a term exceeding 30 years. Several franchises contain purchase options with respect to the purchase of PGS’s property located in the franchise area, if the franchise is not renewed. Otherwise, based on judicial precedent, PGS is able to keep its facilities in place subject to reasonable rules and regulations imposed by the municipalities.

11


PGS’s franchise agreements have various expiration dates through 2049. PGS expects to negotiate 16 franchise renewals in 2020 under similar terms. Franchise fees expense totaled $10 million in 2019 and 2018. Franchise fees are calculated using various formulas which are based principally on natural gas revenues. Franchise fees are recovered on a dollar-for-dollar basis from the respective customers within each franchise area.

Utility operations in areas outside of incorporated municipalities and districts are conducted in each case under one or more permits to use state or county rights-of-way granted by the Florida Department of Transportation or the county commission of such counties. There is no law limiting the time for which such permits may be granted by counties. There are no fixed expiration dates, and these rights are, therefore, considered perpetual.

Environmental Matters

PGS’s operations are subject to federal, state and local statutes, rules and regulations relating to the discharge of materials into the environment and the protection of the environment that generally require monitoring, permitting and ongoing expenditures. TEC is one of several PRPs for certain superfund sites and, through PGS, for former MGP sites. See Note 8 to the 2019 Annual TEC Consolidated Financial Statements and the Environmental Compliance section of the MD&A for additional information.

 

 

Item 1A. RISK FACTORS

 

Risks Relating to TEC’s Business and Strategy

 

Regulatory, Legislative, and Legal Risks

TEC’s electric and gas utilities are regulated; changes in regulation or the regulatory environment could reduce revenues, increase costs or competition.

TEC’s electric and gas utilities operate in regulated industries. Retail operations, including the rates charged, are regulated by the FPSC, and Tampa Electric’s wholesale power sales and transmission services are subject to regulation by the FERC. Changes in regulatory requirements or adverse regulatory actions could have an adverse effect on TEC’s financial performance by, for example, reducing revenues, increasing competition or costs, threatening investment recovery or impacting rate structure.

If Tampa Electric or PGS earn returns on equity above their respective allowed ranges, indicating a trend, those earnings could be subject to review by the FPSC. Ultimately, prolonged returns above their allowed ranges could result in credits or refunds to customers, which could reduce future earnings and cash flow.

Changes in the environmental laws and regulations affecting its businesses could increase TEC’s costs or curtail its activities.

TEC’s businesses are subject to regulation by various governmental authorities dealing with air, water and other environmental matters. Changes in compliance requirements or the interpretation by governmental authorities of existing requirements may impose additional costs on TEC, requiring cost-recovery proceedings and/or requiring it to modify its business model. In addition, environmental laws and regulations may curtail sales of natural gas to new customers, which could reduce PGS’s customer growth in the future.

Federal or state regulation of GHG emissions, depending on how they are enacted, could increase Tampa Electric’s costs or the rates charged to its customers, which could curtail sales.

On June 19, 2019,  the EPA released a final rule named the Affordable Clean Energy (ACE) rule.  The ACE rule, which replaces the Clean Power Plan adopted in 2015, establishes emission guidelines for states to address GHG emissions from existing coal-fired electric generating units.  Tampa Electric has emission units that are subject to the ACE rule and is preparing to engage in the development of a state plan that could be finalized by the end of 2020.

 

The outcome of expected litigation and the EPA rulemaking process and its impact on Tampa Electric’s business is currently uncertain. Tampa Electric is continuing to evaluate the potential impact of the rule, but currently expects prudently incurred related costs for compliance to be recovered through rates. Timing of recovery could impact earnings and cash flows and increases in rates charged to customers could result in reduced sales.

The computation of TEC’s provision for income taxes is impacted by changes in tax legislation.  

12


Any changes in tax legislation could affect TEC’s future cash flows and financial position. The value of TEC’s existing deferred tax assets and liabilities are determined by existing tax laws and could be impacted by changes in laws. See Note 4 of the 2019 Annual TEC Consolidated Financial Statements for further information regarding TEC’s income taxes.

Tampa Electric and PGS may not be able to secure adequate rights-of-way to construct transmission lines, gas interconnection lines and distribution-related facilities and could be required to find alternate ways to provide adequate sources of energy and maintain reliable service for their customers.

Tampa Electric and PGS rely on federal, state and local governmental agencies to secure rights-of-way and siting permits to construct transmission lines, gas interconnection lines and distribution-related facilities. If adequate rights-of-way and siting permits to build new transportation and transmission lines cannot be secured, then Tampa Electric and PGS:

 

 

 

May need to remove or abandon its facilities on the property covered by rights-of-way or franchises and seek alternative

locations for its transmission or distribution facilities;

 

 

 

May need to rely on more costly alternatives to provide energy to their customers;

 

 

 

May not be able to maintain reliability in their service areas; and/or

 

 

 

May experience a negative impact on their ability to provide electric or gas service to new

customers.

The franchise rights held by Tampa Electric and PGS could be lost in the event of a breach by such utilities or could expire and not be renewed.

Tampa Electric and PGS hold franchise agreements with counterparties throughout their service areas. In some cases, these rights could be lost in the event of a breach of these agreements by the applicable utility. These agreements are for set periods and could expire and not be renewed upon expiration of the then-current terms. Some agreements contain provisions allowing municipalities to purchase the portion of the applicable utility’s system located within a given municipality’s boundaries under certain conditions.

 

Operational and Construction Risks

 

TEC’s businesses are sensitive to variations in weather and the effects of extreme weather and have seasonal variations.

TEC’s utility businesses are affected by variations in general weather conditions and severe weather. Energy sales by its electric and gas utilities are particularly sensitive to seasonal variations in weather conditions, including unusually mild summer or winter weather that cause lower energy usage for cooling or heating purposes. PGS typically has a short but significant winter peak period that is dependent on cold weather; Tampa Electric has both summer and winter peak periods that are dependent on weather conditions. Tampa Electric and PGS forecast energy sales based on normal weather, which represents a long-term historical average. If there is unusually mild weather, or if climate change or other factors cause significant variations from normal weather, this could have a material impact on energy sales.

 

TEC is subject to several risks that arise or may arise from climate change.

 

TEC is subject to risks that arise or may arise from the impacts of climate change. There is increasing public concern about climate change and growing support for reducing carbon emissions. City, state, and federal governments have been setting policies and enacting laws and regulations to deal with climate change impacts in a variety of ways, including de-carbonization initiatives and promotion of cleaner energy and renewable energy generation of electricity. Refer to “changes in the environmental laws and regulations” above. Insurance companies have begun to limit their exposure to coal-fired electricity generation, and are evaluating the medium and long-term impacts of climate change which may result in fewer insurers, more restrictive coverage and increased premiums.

 

Climate change may lead to increased frequency and intensity of weather events and related impacts such as storms, ice storms, hurricanes, cyclones, heavy rainfall, extreme winds, wildfires, flooding and storm surge. The potential impacts of climate change, such as rising sea levels and larger storm surges from more intense hurricanes, can combine to produce even greater damage to coastal generation and other facilities. Climate change is also characterized by rising global temperatures. Increased air temperatures may bring increased frequency and severity of wildfires, including within TEC’s service territories. Refer to “variations in weather” above.

 

TEC is subject to physical risks that arise, or may arise, from global climate change, including damage to operating assets from more frequent and intense weather events and from wildfires due to warming air temperatures and increasing drought conditions.

13


Some of TEC’s fossil fueled generation assets are located at coastal, or near coastal, sites and as such are exposed to the separate and combined effects of rising sea levels and increasing storm intensity, including storm surges and flooding. Refer to “variations in weather” above.

 

Failure to address issues related to climate change could affect TEC’s reputation with stakeholders, its ability to operate and grow, and TEC’s access to, and cost of, capital. Refer to “Financial, Economic, and Market Risks” below.

 

Changing carbon-related costs, policy and regulatory changes and shifts in supply and demand factors could lead to more expensive or more scarce products and services that are required by TEC in its operations. This could lead to supply shortages,  delivery delays and the need to source alternate products and services.

 

Given concerns regarding carbon-emitting generation, those assets and businesses may, over time, become difficult (or uneconomic) to insure in commercial insurance markets.

 

Depending on the regulatory response to government legislation and regulations, TEC may be exposed to the risk of reduced recovery through rates in respect of the affected assets. Valuation impairments could result from such regulatory outcomes.

 

TEC could, in the future, face litigation or regulatory action related to environmental harms from carbon emissions or climate change public disclosure issues.

 

For thermal plants requiring cooling water, reduced availability of water resulting from climate change could adversely impact operations or the costs of operations.

The facilities and operations of TEC could be affected by natural disasters or other catastrophic events.

TEC’s facilities and operations are exposed to potential damage and partial or complete loss resulting from environmental disasters (e.g. hurricanes, floods, high winds, fires and earthquakes), equipment failures, terrorist or physical attacks, vandalism, a major accident or incident at one of the sites, and other events beyond the control of TEC. The operation of generation, transmission and distribution systems involves certain risks, including gas leaks, fires, explosions, pipeline ruptures, damage to solar panels and other generation assets, and other hazards and risks that may cause unforeseen interruptions, personal injury, death, or property damage. For example, there have also been physical attacks on critical infrastructure around the world. In the event of a physical attack that disrupts service to customers, revenues would be reduced, and costs would be incurred to repair and restore systems. These types of events, either impacting TEC’s facilities or the industry in general, could also cause TEC to incur additional security and insurance-related costs, and could have adverse effects on its business and financial results. Any costs relating to such events may not be recoverable through insurance or rates.

 

TEC is exposed to potential risks related to cyberattacks and unauthorized access, which could cause system failures, disrupt operations or adversely affect safety.

 

TEC increasingly relies on information technology systems and network infrastructure to manage its business and safely operate its assets; including controls for interconnected systems of generation, distribution and transmission as well as financial, billing and other business systems. TEC also relies on third party service providers in order to conduct business. As TEC operates critical infrastructure, it may be at greater risk of cyberattacks by third parties, which could include nation-state controlled parties.

 

Cyberattacks can reach TEC’s networks with access to critical assets and information via their interfaces with less critical internal networks or via the public internet. Cyberattacks can also occur via personnel with direct access to critical assets or trusted networks. Methods used to attack critical assets could include general purpose or energy-sector-specific malware delivered via network transfer, removable media, viruses, attachments or links in e-mails. The methods used by attackers are continuously evolving and can be difficult to predict and detect.

 

TEC’s systems, assets and information could experience security breaches that could cause system failures, disrupt operations or adversely affect safety. Such breaches could compromise customer, employee-related or other information systems and could result in loss of service to customers or the unavailability, release, destruction or misuse of critical, sensitive or confidential information. These breaches could also delay delivery or result in contamination or degradation of hydrocarbon products TEC transports, stores or distributes.

 

Should such cyberattacks or unauthorized accesses materialize, TEC could suffer costs, losses and damages all, or some of which, may not be recoverable through insurance, legal, regulatory cost recovery or other processes and could materially adversely affect TEC’s business and financial results including its reputation and standing with customers, regulators, governments and financial markets. Resulting costs could include, amongst others, response, recovery and remediation costs, increased protection or insurance

14


costs and costs arising from damages and losses incurred by third parties. If any such security breaches occur, there is no assurance that they can be adequately addressed in a timely manner.

 

With respect to certain of its assets, TEC is required to comply with rules and standards relating to cybersecurity and information technology including, but not limited to, those mandated by bodies such as the North American Electric Reliability Corporation. TEC cannot be assured that its operations will not be negatively impacted by a cyberattack.

  

Financial, Economic, and Market Risks

 

National and local economic conditions can have a significant impact on the results of operations, net income and cash flows at TEC.

The business of TEC is concentrated in Florida. If economic conditions start to decline, retail customer growth rates may stagnate or decline, and customers’ energy usage may decline, adversely affecting TEC’s results of operations, net income and cash flows. A factor in customer growth in Florida is net in migration of new residents, both domestic and non-U.S. A slowdown in the U.S. economy could reduce the number of new residents and slow customer growth.

Potential competitive changes may adversely affect TEC.

There is competition in wholesale power sales across the United States. Some states have mandated or encouraged competition at the retail level and, in some situations, required divestiture of generating assets. While there is active wholesale competition in Florida, the retail electric business has remained substantially free from direct competition. Changes in the competitive environment occasioned by legislation, regulation, market conditions or initiatives of other electric power providers or voters, particularly with respect to retail competition, could adversely affect Tampa Electric’s business and its expected performance.  

 

Deregulation or restructuring of the electric industry may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows. A proposed constitutional amendment initiative relating to electric utilities in Florida was rejected by the Florida Supreme Court as misleading and therefore the constitutional amendment will not be included on ballots for the November 2020 election. The proposed amendment to the Florida Constitution would have limited the business of investor-owned utilities to construction, operation and repair of electrical transmission and distribution systems. It would have also granted customers of investor-owned utilities the right to generate electricity and to choose their electricity provider.

The gas distribution industry has been subject to competitive forces for a number of years. Gas services provided by PGS are unbundled for all non-residential customers. Because PGS earns on the distribution of gas but not on the commodity itself, unbundling has not negatively impacted PGS’s results. However, future structural changes could adversely affect PGS.

TEC relies on some natural gas transmission assets that it does not own or control to deliver natural gas.

TEC depends on transmission facilities owned and operated by other utilities and energy companies to deliver the natural gas it sells to the wholesale and retail markets. If transmission is disrupted, or if capacity is inadequate, its ability to sell and deliver products and satisfy its contractual and service obligations could be adversely affected.

Disruption of fuel supply could have an adverse impact on the financial condition of TEC.

Tampa Electric and PGS depend on third parties to supply fuel, including natural gas, oil and coal. As a result, there are risks of supply interruptions and fuel-price volatility. Disruption of fuel supplies or transportation services for fuel, whether because of weather-related problems, strikes, lock-outs, break-downs of transportation facilities, pipeline failures or other events, could impair the ability to deliver electricity and gas or generate electricity and could adversely affect operations. The loss of fuel suppliers or the inability to renew existing coal and natural gas contracts at favorable terms could significantly affect the ability to serve customers and have an adverse impact on the financial condition and results of operations of TEC.

Commodity price changes may affect the operating costs and competitive positions of TEC’s businesses.

TEC’s businesses are sensitive to changes in gas, coal, oil and other commodity prices. Any changes in the availability of these commodities could affect the prices charged by suppliers as well as suppliers’ operating costs and the competitive positions of their products and services.

In the case of Tampa Electric, fuel costs used for generation are affected primarily by the cost of natural gas and coal. Tampa Electric is able to recover prudently incurred costs of fuel through retail customers’ bills, but increases in fuel costs affect electric prices and, therefore, the competitive position of electricity against other energy sources.

15


The ability to make sales of, and the margins earned on, wholesale power sales are affected by the cost of fuel to Tampa Electric, particularly as it compares to the costs of other power producers.

In the case of PGS, costs for purchased gas and pipeline capacity are recovered through retail customers’ bills, but increases in gas costs affect total retail prices and, therefore, the competitive position of PGS as compared to electricity, other forms of energy and other gas suppliers.

Developments in technology could reduce demand for electricity and gas.

Research and development activities are ongoing for new technologies that produce power or reduce power consumption. These technologies include renewable energy, customer-oriented generation, energy storage, energy efficiency and more energy-efficient appliances and equipment. Advances in these or other technologies could reduce the cost of producing electricity or transporting gas, or otherwise make Tampa Electric’s existing generating facilities uneconomic. In addition, advances in such technologies could reduce demand for electricity or natural gas, which could negatively impact the results of operations, net income and cash flows of TEC.

Results at TEC may be affected by changes in customer energy-usage patterns.

For the past several years, at Tampa Electric and electric utilities across the United States, weather-normalized electricity consumption per residential customer has declined due to the combined effects of voluntary conservation efforts and improvements in equipment efficiency.

Forecasts by TEC are based on normal weather patterns and trends in customer energy-usage patterns. The ability of TEC to increase energy sales and earnings could be negatively impacted if customers further reduce their energy usage in response to increased energy efficiency, economic conditions or other factors.

Increased customer use of distributed generation could adversely affect Tampa Electric.

In many areas of the United States, there is growing use of rooftop solar panels, small wind turbines and other small-scale methods of power generation, known as distributed generation. Distributed generation is encouraged and supported by various constituent groups, tax incentives, renewable portfolio standards and special rates designed to support such generation.

Increased usage of distributed generation can reduce utility electricity sales but does not reduce the need for ongoing investment in infrastructure to maintain or expand the transmission and distribution grid to reliably serve customers. Continued utility investment that is not supported by increased energy sales causes rates to increase for customers, which could further reduce energy sales and reduce future earnings and cash flows.

Failure to attract and retain an appropriately qualified workforce, or workforce disruptions, could adversely affect TEC’s financial results.

Events such as increased retirements due to an aging workforce or the departure of employees for other reasons without appropriate replacements, mismatch of skill sets to future needs, or unavailability of contract resources may lead to operating challenges such as lack of resources, loss of knowledge, and a lengthy time period associated with skill development. Failure to attract and hire employees, including the ability to transfer significant internal historical knowledge and expertise to the new employees, or workforce disruptions due to work stoppages or strikes, or the future availability and cost of contract labor may cause costs to operate TEC’s systems to rise. If TEC is unable to successfully attract and retain an appropriately qualified workforce, results of operations could be negatively impacted.

 

Liquidity, Capital Requirements, and Common Stock Risks

 

TEC’s substantial indebtedness could adversely affect its business, financial condition and results of operations, as well as its ability to meet its payment obligations on its debt.

TEC has a significant amount of indebtedness that it is obligated to pay. It must meet certain financial covenants as defined in the applicable agreements to borrow under its credit facilities. Also, TEC has certain restrictive covenants in specific agreements and debt instruments.  The level of TEC’s indebtedness and restrictive covenants contained in its debt obligations could have significant consequences to its business, could create risk for the holders of its debt, and could limit its ability to obtain additional financing (see Management’s Discussion & Analysis – Significant Financial Covenants section).  Such risks include:

 

making it more difficult for TEC to satisfy its debt obligations and other ongoing business obligations, which may result in defaults;

16


 

events of default if it fails to comply with the financial and other covenants contained in the agreements governing such debt, which could result in all of its debt becoming immediately due and payable or require it to negotiate an amendment to financial or other covenants that could cause it to incur additional fees and expenses;

 

reducing the availability of cash flow to finance its business and limiting its ability to obtain additional financing for these purposes;

 

increasing its vulnerability to the impact of adverse economic and industry conditions;

 

limiting its flexibility in planning for, or reacting to, and increasing its vulnerability to, changes in its business and the overall economy; and increasing its cost of borrowing.

TEC has obligations that do not appear on its balance sheet, such as letters of credit.  To the extent material, these obligations are disclosed in the notes to the financial statements.

Financial market conditions could limit TEC’s access to capital and increase TEC’s costs of borrowing or refinancing, or have other adverse effects on its results.

TEC has debt maturing in subsequent years, which TEC anticipates will need to be refinanced. Future financial market conditions could limit TEC’s ability to raise the capital it needs and could increase its interest costs, which could reduce earnings and cash flows.

Declines in the financial markets or in interest rates used to determine benefit obligations could increase TEC’s pension expense or the required cash contributions to maintain required levels of funding for its plan.

TEC is a participant in the comprehensive retirement plans of TECO Energy. Under calculation requirements of the Pension Protection Act, as of the January 1, 2020 measurement date, TECO Energy’s pension plan was fully funded. Any future declines in the financial markets or interest rates could increase the amount of contributions required to fund its pension plan in the future and could cause pension expense to increase.

TEC’s financial condition and results could be adversely affected if its capital expenditures are greater than forecast or costs are not recoverable through rates.

For 2020, Tampa Electric is forecasting capital expenditures to support the current levels of customer growth, harden transmission and distribution facilities against storm damage, maintain transmission and distribution system reliability, modernize the Big Bend Power Station, invest in solar generation and maintain generating unit reliability and efficiency. For 2020, PGS is forecasting capital expenditures to support customer growth, system reliability, conversion of customers from other fuels to natural gas and to replace bare steel, cast iron and obsolete plastic pipe.

Total costs may be higher than estimated and there can be no assurance that TEC will be able to obtain the necessary project approvals, regulatory outcomes or applicable permits at the federal, state and or local level to recover such expenditures through regulated rates. If TEC’s capital expenditures exceed the forecasted levels or are not recoverable, it may need to draw on credit facilities or access the capital markets on unfavorable terms.

TEC’s financial condition and ability to access capital may be materially adversely affected by multiple ratings downgrades to below investment grade.

The senior unsecured debt of TEC is rated by S&P at ‘BBB+’, by Moody’s at ‘A3’ and by Fitch at ‘A’. A downgrade to below investment grade by the rating agencies, which would require a four-notch downgrade by Moody’s and Fitch and a three-notch downgrade by S&P, may affect TEC’s ability to borrow, may change requirements for future collateral or margin postings, and may increase financing costs, which may decrease earnings. Downgrades could adversely affect TEC’s relationships with customers and counterparties.

 

In the event TEC’s ratings were downgraded to below investment grade, certain agreements could require immediate payment or full collateralization of net liability positions. Counterparties to its derivative instruments could request immediate payment or full collateralization of net liability positions. Credit provisions in long-term gas transportation agreements would give the transportation providers the right to demand collateral, which is estimated to be approximately $110 million. Credit facilities or debt agreements do not have ratings downgrade covenants that would require immediate repayment.

 

 

17


Item 2. PROPERTIES

TEC believes that the physical properties of its operating companies are adequate to carry on their businesses as currently conducted. The properties of Tampa Electric are subject to a first mortgage bond indenture under which no bonds are currently outstanding.

TAMPA ELECTRIC

Tampa Electric has electric generating stations in service, with a December 2019 net winter generating capability of 5,641 MWs. Tampa Electric assets include the Big Bend Power Station (1,693 MWs capacity), the Bayside Power Station (2,083 capacity) and the Polk Power Station (1,420 MWs capacity). Also included in Tampa Electric’s assets at December 31, 2019 are ten solar arrays (445 MWs). In addition, solar arrays totaling 149 MWs were placed in service in early 2020.

Tampa Electric owns 186 substations having an aggregate transformer capacity of 23,200 mega volts amps. The transmission system consists of approximately 1,345 total circuit miles of high voltage transmission lines, including underground and double-circuit lines. The distribution system consists of approximately 6,250 circuit miles of overhead lines and approximately 5,550 circuit miles of underground lines. As of December 31, 2019, there were 787,400 meters in service. All of this property is located in Florida.

Tampa Electric’s property, plant and equipment are owned, except that titles to some of the properties are subject to easements, leases, contracts, covenants and similar encumbrances common to properties of the size and character of those of Tampa Electric.

Tampa Electric has easements or other property rights for rights-of-way adequate for the maintenance and operation of its electrical transmission and distribution lines that are not constructed upon public highways, roads and streets. Transmission and distribution lines located in public ways are maintained under franchises or permits.

Tampa Electric has a long-term lease for the office building in downtown Tampa, which serves as headquarters for TECO Energy, Tampa Electric, PGS and TSI.

PEOPLES GAS SYSTEM

PGS’s distribution system extends throughout the areas it serves in Florida and consists of approximately 21,000 miles of pipe, including approximately 13,500 miles of mains and 7,500 miles of service lines. Mains and service lines are maintained under rights-of-way, franchises or permits.

PGS’s operations are located in 14 service areas throughout Florida. Most of the operations and administrative facilities are owned.

Item 3. LEGAL PROCEEDINGS

From time to time, TEC is involved in various legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies in the ordinary course of business. Where appropriate, accruals are made in accordance with accounting standards for contingencies to provide for matters that are probable of resulting in an estimable loss. For a discussion of legal proceedings and environmental matters, see Note 8 of the 2019 Annual TEC Consolidated Financial Statements.

 

 

 


18


PART II

 

 

Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

All of TEC’s common stock is owned by TECO Energy, which in turn is owned by a subsidiary of Emera and, thus, is not listed on a stock exchange. Therefore, there is no market for such stock.

 

 

Item 6. SELECTED FINANCIAL DATA OF TAMPA ELECTRIC COMPANY

Information required by Item 6 is omitted pursuant to General Instruction I(2) of Form 10-K.

 

 

Item 7. MANAGEMENT’S DISCUSSION & ANALYSIS OF FINANCIAL CONDITIONS & RESULTS OF OPERATIONS

This Management’s Discussion & Analysis contains forward-looking statements, which are subject to the inherent uncertainties in predicting future results and conditions. Actual results may differ materially from those forecasted. Such statements are based on our current expectations as of the date we filed this report, and we do not undertake to update or revise such forward-looking statements, except as may be required by law. These forward-looking statements include references to anticipated capital expenditures, liquidity and financing requirements, projected operating results, future environmental matters, and regulatory and other plans. Important factors that could cause actual results to differ materially from those projected in these forward-looking statements are discussed under “Risk Factors”, and elsewhere in this MD&A.

OVERVIEW

TEC has regulated electric and gas utility operations in Florida. At December 31, 2019, Tampa Electric served approximately 779,000 customers in a 2,000-square-mile service area in West Central Florida and had electric generating plants with a winter peak generating capacity of 5,641 MW. PGS, Florida’s largest gas distribution utility, served approximately 406,000 residential, commercial, industrial and electric power generating customers at December 31, 2019 in all major metropolitan areas of the state, with a total natural gas throughput of approximately 2.1 billion therms in 2019.

TEC is a wholly owned subsidiary of TECO Energy, and TECO Energy is a wholly owned subsidiary of Emera. Therefore, TEC is an indirect, wholly owned subsidiary of Emera. See Note 10 to the 2019 Annual TEC Consolidated Financial Statements for information regarding related party transactions.

2019 PERFORMANCE

All amounts included in this MD&A are pre-tax, except net income and income taxes.

In 2019, TEC’s net income was $370 million, compared with $341 million in 2018. In 2018, as permitted by the FPSC, TEC offset the impact of estimated 2018 tax reform benefits with a $103 million charge to O&M expense related to Tampa Electric storm costs and a $11 million charge to amortization expense related to PGS’s regulatory asset associated with the MGP environmental liability (see Note 3 to the TEC Consolidated Financial Statements). Beginning on January 1, 2019, as approved by the FPSC, base rates were lowered due to the impact of U.S. tax reform by approximately $103 million annually at Tampa Electric and $12 million annually at PGS. Therefore, the decrease in revenue due to lower base rates from tax reform in 2019 was largely offset by lower O&M expense and lower amortization expense from the absence of the offsetting of U.S. tax reform benefits in 2018, resulting in minimal impact to the Consolidated Statements of Income. Excluding the impact of tax reform, storm costs and the MGP regulatory asset, 2019 results were impacted by higher base revenue, primarily related to the in-service of solar generation projects and customer growth, partially offset by higher interest expense and depreciation expense. See below for further detail regarding 2019 results as compared to 2018. For information regarding 2018 results as compared to 2017, see “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of TEC’s Annual Report on Form 10-K for the year ended December 31, 2018.

OUTLOOK

TEC’s earnings are most directly impacted by the allowed rate of return on equity and the capital structures approved by the FPSC, the prudent management of operating costs, the approved recovery of regulatory deferrals, weather and its impact on energy sales, and the timing and amount of capital expenditures.

Tampa Electric anticipates earning within its allowed ROE range in 2020 and expects rate base and earnings to be higher than in 2019. Tampa Electric expects customer growth rates in 2020 to be consistent with 2019, reflecting economic growth in Florida.

19


Assuming normal weather in 2020, Tampa Electric sales volumes are expected to be consistent with 2019 sales volumes (see Customer and Energy Sales Growth Outlook for further details).

 

Driven by customer demand and economic development across the state of Florida along with reliability infrastructure projects, PGS has plans for significant capital investments in 2020. The rate base growth from these investments along with other operating cost increases since the last rate increase, which occurred over 10 years ago in 2009, is expected to cause PGS to earn below its allowed ROE range in 2020. Consistent with its FPSC-approved 2018 tax reform settlement agreement, PGS is permitted to initiate a general base rate proceeding during 2020, regardless of its earned ROE at the time, provided the new rates do not become effective before January 1, 2021. As a result, on February 7, 2020, PGS notified the FPSC that it is planning to file a base rate proceeding in April for new rates effective January 2021.

PGS also expects customer growth rates in 2020 to be consistent with 2019, reflecting economic growth and the optimization of existing opportunities as the utility increases its market penetration in Florida. Assuming normal weather in 2020, PGS sales volumes are expected to increase at a level slightly above customer growth, as 2019 energy sales were negatively impacted by unfavorable winter weather.

 

On December 10, 2019, the FPSC approved Tampa Electric’s petition to reduce base rates and charges reflecting reduction of the state income tax rate from 5.5% to 4.5%. The tax rate reduction is effective retroactive from January 1, 2019 to December 31, 2021. The estimated base rate reduction of $5 million due to customers is subject to true-up, and the actual rate reduction may vary from year to year. The new lower rates were effective January 2020. In addition, in January 2020, Tampa Electric refunded $12 million to customers as a result of the final settlement agreement related to the netting of Hurricane Irma storm costs and 2018 U.S. tax reform benefits. See Note 3 to the 2019 Annual TEC Consolidated Financial Statements for additional information.

 

On October 3, 2019, the FPSC issued a rule to implement a storm protection plan cost recovery clause. This new clause provides a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Subject to final approval of a FPSC rule, Tampa Electric expects to file a storm protection plan with the FPSC in the second quarter of 2020.

As of December 31, 2019, Tampa Electric has invested approximately $820 million in new utility-scale solar photovoltaic projects, which is recoverable through FPSC-approved SoBRAs. Tampa Electric expects to invest a total of approximately $850 million in these projects across its service territory through 2021. AFUDC is being earned on these projects during construction. Tampa Electric began receiving revenues of $24 million annually for the first tranche of its SoBRA in September 2018, $46 million annually for the second tranche in January 2019 and $26 million annually for the third tranche in January 2020. Tampa Electric expects to file its final SoBRA petition for the January 1, 2021 tranche in 2020. See Note 3 to the 2019 Annual TEC Consolidated Financial Statements for additional information. Tampa Electric also intends to invest approximately $800 million in an additional 600 MW of new utility-scale solar photovoltaic projects with targeted in-service dates during 2021 through 2023.

 

In 2020, TEC expects to invest approximately $1.4 billion, including AFUDC, in capital projects compared to $1.3 billion in 2019. Capital projects support normal system reliability and growth at the utilities. AFUDC will be earned on eligible capital projects during the construction periods. Tampa Electric investments include continuation of the modernization of the Big Bend Power Station, which received final state approval on July 25, 2019, solar investments and an AMI (Advanced Meter Infrastructure) project, which includes the installation of smart meters. PGS will make investments to expand its system and support customer growth, including expected investments related to compressed natural gas fueling stations, renewable natural gas and liquefied natural gas facilities, and continued replacement of obsolete plastic, cast iron and bare steel pipe. See Capital Investments below for further information.  

These forecasts are based on our current assumptions described in the operating company discussion, which are subject to risks and uncertainties (see the Risk Factors section).  

 

OPERATING RESULTS

This MD&A utilizes TEC’s consolidated financial statements, which have been prepared in accordance with U.S. GAAP. Our reported operating results are affected by several critical accounting estimates (see the Critical Accounting Policies and Estimates section).

20


The following table shows the revenues and net income of the business segments on a U.S. GAAP basis (see Note 11 to the 2019 Annual TEC Consolidated Financial Statements).  

(millions)

 

 

 

2019

 

 

2018

 

 

2017

 

Revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Tampa Electric

 

$

1,965

 

 

$

2,066

 

 

$

2,054

 

 

 

PGS

 

 

461

 

 

 

488

 

 

 

438

 

 

 

Eliminations

 

 

(22

)

 

 

(30

)

 

 

(22

)

 

 

TEC

 

$

2,404

 

 

$

2,524

 

 

$

2,470

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net income

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Tampa Electric

 

$

316

 

 

$

294

 

 

$

273

 

 

 

PGS

 

 

54

 

 

 

47

 

 

 

43

 

 

 

TEC

 

$

370

 

 

$

341

 

 

$

316

 

TAMPA ELECTRIC

Electric Operations Results

Tampa Electric’s net income in 2019 was $316 million, compared with $294 million in 2018. Excluding the impact of tax reform and storm costs as disclosed in 2019 Performance above, results primarily reflected higher base revenues and lower income taxes, partially offset by higher depreciation expense and higher interest expense. Base revenues are energy sales excluding revenues from clauses, gross receipts taxes and franchise fees. Clauses, gross receipts taxes and franchise fees do not have a material effect on net income as these revenues substantially represent a dollar-for-dollar recovery of clause and other pass-through costs. See the Operating Revenues and Operating Expenses sections below for additional information.

The table below provides a summary of Tampa Electric’s revenue and expenses and energy sales by customer type.

Summary of Operating Results

 

(millions, except customers and total degree days)

 

2019

 

 

% Change

 

 

2018

 

 

% Change

 

 

2017

 

Revenues

 

$

1,965

 

 

 

(5

)

 

$

2,066

 

 

 

1

 

 

$

2,054

 

O&M expense

 

 

408

 

 

 

(19

)

 

 

504

 

 

 

26

 

 

 

399

 

Depreciation and amortization expense

 

 

336

 

 

 

8

 

 

 

312

 

 

 

4

 

 

 

300

 

Taxes, other than income

 

 

165

 

 

 

(2

)

 

 

168

 

 

 

4

 

 

 

162

 

Non-fuel operating expenses

 

 

909

 

 

 

(8

)

 

 

984

 

 

 

14

 

 

 

861

 

Fuel expense

 

 

533

 

 

 

(8

)

 

 

578

 

 

 

(5

)

 

 

608

 

Purchased power expense

 

 

49

 

 

 

(17

)

 

 

59

 

 

 

28

 

 

 

46

 

Total fuel & purchased power expense

 

 

582

 

 

 

(9

)

 

 

637

 

 

 

(3

)

 

 

654

 

Total operating expenses

 

 

1,491

 

 

 

(8

)

 

 

1,621

 

 

 

7

 

 

 

1,515

 

Operating income

 

$

474

 

 

 

7

 

 

$

445

 

 

 

(17

)

 

$

539

 

AFUDC-equity

 

$

11

 

 

 

10

 

 

$

10

 

 

 

400

 

 

$

2

 

Provision for income taxes

 

$

59

 

 

 

(9

)

 

$

65

 

 

 

(62

)

 

$

171

 

Net income

 

$

316

 

 

 

7

 

 

$

294

 

 

 

8

 

 

$

273

 

Megawatt-Hour Sales (thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

 

9,584

 

 

 

2

 

 

 

9,418

 

 

 

4

 

 

 

9,029

 

Commercial

 

 

6,240

 

 

 

(0

)

 

 

6,266

 

 

 

(2

)

 

 

6,362

 

Industrial

 

 

2,021

 

 

 

0

 

 

 

2,014

 

 

 

(0

)

 

 

2,024

 

Other

 

 

1,939

 

 

 

0

 

 

 

1,933

 

 

 

9

 

 

 

1,771

 

Total retail

 

 

19,784

 

 

 

1

 

 

 

19,631

 

 

 

2

 

 

 

19,186

 

Off system sales

 

 

155

 

 

 

(46

)

 

 

286

 

 

 

20

 

 

 

239

 

Total energy sold

 

 

19,939

 

 

 

0

 

 

 

19,917

 

 

 

3

 

 

 

19,425

 

Retail customers—(thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

At December 31

 

 

779

 

 

 

2

 

 

 

764

 

 

 

2

 

 

 

748

 

Retail net energy for load

 

 

20,770

 

 

 

1

 

 

 

20,663

 

 

 

2

 

 

 

20,297

 

Total degree days

 

 

4,568

 

 

 

(3

)

 

 

4,711

 

 

 

4

 

 

 

4,520

 

21


Operating Revenues

Revenues, excluding the impact of tax reform as disclosed above, were $2 million higher than in 2018, primarily due to higher base revenue driven by the in-service of solar generation projects and customer growth, partially offset by lower clause revenue. Total degree days (a measure of heating and cooling demand) in Tampa Electric's service area in 2019 were 7% above normal and 3% below 2018. Total net energy for load, which is a calendar measurement of energy output, increased 1% in 2019 compared with 2018.

Customer and Energy Sales Growth Outlook

The Florida labor market continues to outperform the U.S. labor market. The local Tampa area unemployment rate improved to 3.2% in 2019 compared with 3.4% in 2018, which is below the Florida rate of 3.3% and the U.S. rate of 3.7% for 2019. The Florida and Tampa unemployment rates are expected to increase slightly in 2020. From 2019 to 2022, the economies of Florida’s and Tampa Electric’s service area, as measured by Real Gross State Product, are forecasted to expand at an average annual rate of 2.7%, outpacing the forecasted U.S. rate of 2.2%.

Population growth is forecasted to continue to be a major driver of customer growth for many years. Tampa Electric expects customer growth to be 1.5% to 2.0% annually over the next few years, assuming continued economic growth and business expansion.

For the past several years, weather-normalized energy consumption per residential customer declined due to the combined effects of voluntary conservation efforts, improvements in lighting and appliance efficiency. It is expected to continue to decline annually at an average annual rate of 0.6% over the next few years.

In 2020, retail energy sales are expected to be consistent with 2019 levels as 2019 energy sales benefitted from favorable weather while 2020 projections are based on normal weather. Over the longer-term, energy sales growth is expected to be around 1.0%. Energy sales growth projections reflect the offsetting impacts to customer growth from average energy consumption trends and assume continued local area economic growth, normal weather, and a continuation of the current energy market structure.

Tampa Electric anticipates earnings within the allowed ROE range in 2020 and expects earnings and rate base growth as a result of continued customer growth, increased investment in capital projects, and a focus on cost control.

Operating Expenses

In 2019, operations and maintenance expense, excluding all FPSC-approved cost-recovery clauses and the impact of regulatory agreements related to the recovery of storm costs and tax reform benefits as discussed above and in Note 3 to the TEC Consolidated Financial Statements, was consistent with 2018 primarily reflecting higher transmission and distribution costs as a result of line clearance costs and serving customer growth, offset by lower generation costs as a result of lower outage costs and stronger unit performance. Depreciation and amortization expense increased $24 million in 2019 from normal additions to facilities to reliably serve customers and the in-service of solar generation projects.

Excluding all FPSC-approved cost-recovery clause-related expense, O&M expense in 2020 is expected to be higher than in 2019 reflecting higher costs to safely and reliably serve customers. In 2020, depreciation expense is expected to increase due to solar project timings and normal plant additions.

 

Fuel Prices and Fuel Cost Recovery

In November 2019, the FPSC approved cost-recovery rates for fuel and purchased power, capacity, environmental and conservation costs for 2020. The rates include the expected cost for natural gas and coal in 2020, and a net prior period under-recovery true-up of fuel, purchased power and capacity clause expense. These rates are typically set annually, based on information provided in August of the year prior to the year the rates take effect.

 

Total fuel expense decreased in 2019 primarily due to lower natural gas prices. Delivered natural gas prices decreased 16% in 2019 as domestic natural gas supply and production far outpaced demand from LNG production and gas-fired electric generation. Delivered coal costs increased 9% in 2019. The average natural gas and coal costs were $3.44/MMBTU and $3.66/MMBTU, respectively, in 2019, compared with $4.07/MMBTU and $3.37/MMBTU, respectively, in 2018.

Total 2020 fuel and purchased power costs are expected to be less than incurred during 2019, which will be achieved using low-cost natural gas-fired generation.

PGS

Operating Results

In 2019, PGS reported net income of $54 million, compared with $47 million in 2018. Results reflect a 3.4% increase in number of customers in 2019 compared to 2018. Excluding the impact of tax reform as disclosed above, revenues were $16 million lower than

22


the prior year primarily due to lower off-system sales, partially offset by customer growth. Excluding the impact of tax reform, base revenues were $4 million higher than 2018 primarily due to customer growth, partially offset by unfavorable weather in 2019. Operations and maintenance expense, excluding all FPSC-approved cost-recovery clauses, was $5 million higher than in 2018 primarily due to higher employee benefit costs, increased self-insurance costs, and higher cost to safely and reliably operate and maintain the growing distribution system. Depreciation and amortization decreased $19 million due to accelerated amortization of the regulatory asset associated with MGP environmental remediation costs in 2018 and reduced depreciation rates in 2019 related to the 2018 settlement agreement (see Note 3 to the TEC Consolidated Financial Statements), which were partially offset by normal asset growth. Return on investment in the cast iron and bare steel replacement rider was $4 million higher in the 2019 period. 

In 2019 and 2018, total throughput for PGS was approximately 2.1 billion therms and 2.0 billion therms, respectively. See Business - Peoples Gas System- Gas Operations for information regarding therms by type of customer.

PGS provides transportation service to customers utilizing gas-fired technology in the production of electric power. In addition, PGS provides gas transportation service to large LNG facilities located in Jacksonville, Florida. PGS has also experienced interest in the usage of CNG as an alternative fuel for vehicles, especially refuse trucks and buses. Therms sold to CNG stations have increased steadily to 36 million therms sold in 2019 compared to 33 million therms in 2018. Currently, there are 54 CNG fueling stations connected to the PGS system, with more in progress. PGS owns three CNG filling stations, and the cost of these stations is recovered over time through a special rate approved by the FPSC. CNG conversions add therm sales to the gas system without requiring significant capital investment by PGS.

The actual cost of gas and upstream transportation purchased and resold to end-use customers is recovered through a PGA. Because this charge may be adjusted monthly based on a cap approved by the FPSC annually, PGS normally has a lower percentage of under- or over-recovered fuel cost than Tampa Electric.

The table below provides a summary of PGS’s revenue and expenses and therm sales by customer type.

Summary of Operating Results

 

(millions, except customers)

 

2019

 

 

% Change

 

 

2018

 

 

% Change

 

 

2017

 

Revenues

 

$

461

 

 

 

(6

)

 

$

488

 

 

 

11

 

 

$

438

 

Cost of gas sold

 

 

152

 

 

 

(16

)

 

 

180

 

 

 

18

 

 

 

153

 

Operating expenses

 

 

222

 

 

 

(4

)

 

 

231

 

 

 

15

 

 

 

201

 

Operating income

 

$

87

 

 

 

13

 

 

$

77

 

 

 

(8

)

 

$

84

 

Net income

 

$

54

 

 

 

15

 

 

$

47

 

 

 

9

 

 

$

43

 

Therms sold – by customer segment

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Residential

 

 

85

 

 

 

(2

)

 

 

87

 

 

 

13

 

 

 

77

 

Commercial

 

 

517

 

 

 

1

 

 

 

510

 

 

 

4

 

 

 

489

 

Industrial

 

 

430

 

 

 

19

 

 

 

361

 

 

 

9

 

 

 

330

 

Off-system sales

 

 

188

 

 

 

(13

)

 

 

217

 

 

 

8

 

 

 

201

 

Power generation

 

 

853

 

 

 

8

 

 

 

791

 

 

 

5

 

 

 

750

 

Total

 

 

2,073

 

 

 

5

 

 

 

1,966

 

 

 

6

 

 

 

1,847

 

Therms sold – by sales type

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

System supply

 

 

296

 

 

 

(10

)

 

 

328

 

 

 

8

 

 

 

303

 

Transportation

 

 

1,777

 

 

 

8

 

 

 

1,638

 

 

 

6

 

 

 

1,544

 

Total

 

 

2,073

 

 

 

5

 

 

 

1,966

 

 

 

6

 

 

 

1,847

 

Customer (thousands) – at December 31(1)

 

 

406

 

 

 

4

 

 

 

392

 

 

 

4

 

 

 

378

 

See Business-Peoples Gas System-Competition for information regarding PGS’s transportation-only customers.

PGS Outlook

PGS expects customer growth rates in 2020 to be in line with 2019, reflecting its expectations that the housing markets in many areas of the state will continue to grow, allowing for new and existing gas main opportunities. Assuming normal weather in 2020, PGS sales volumes are expected to increase at a level slightly above customer growth as 2019 energy sales were negatively impacted by unfavorable winter weather. PGS anticipates earnings in 2020 to be consistent with 2019.

In January 2019, a base rate reduction went into effect to return US tax reform benefits to customers in accordance with the FPSC-approved tax reform settlement.  Excluding all FPSC-approved cost-recovery clause-related expenses, O&M expense in 2020 is expected to be higher than in 2019, driven by an increase in technology related costs, initiatives to enhance customer experience, and additional expense necessary to safely and reliably operate and maintain a growing distribution system. Depreciation and amortization expense is expected to increase in 2020 due to normal plant additions.

23


Complementing the strong residential construction market is PGS’s focus on extending the system to serve large commercial or industrial customers that are currently using petroleum or propane as fuel. The current relatively low natural gas prices and the lower emissions levels from using natural gas compared to other fuels make it attractive for these customers to convert from other fuels.

Due to expected growth in rate base in 2020, PGS anticipates earning below its allowed ROE range in 2020. On February 7, 2020, PGS notified the FPSC that it is planning to file a base rate proceeding in April for new rates effective January 2021.

OTHER ITEMS IMPACTING NET INCOME

Other Income, Net

Other income, net was $20 million and $18 million in 2019 and 2018, respectively, and included AFUDC-equity. AFUDC-equity was $11 million and $10 million in 2019 and 2018, respectively. The increase in AFUDC-equity is primarily due to Tampa Electric’s construction of the Big Bend modernization, solar generation and AMI as discussed in the Capital Investments section below. AFUDC is expected to increase in 2020 due to the timing of construction of the Big Bend modernization, solar generation, AMI and PGS expansion projects.

Interest Expense

In 2019, interest expense, excluding AFUDC-debt, was $139 million compared to $123 million in 2018. The increase reflected higher long-term borrowings.

Interest expense is expected to increase in 2020, reflecting higher balances and interest rates.

Income Taxes

The provision for income taxes decreased in 2019 primarily due to higher ITC amortization and lower Florida state tax rate.  Income tax expense as a percentage of income before taxes was 17.2% in 2019 and 19.2% in 2018. TEC expects the 2020 annual effective tax rate to be consistent with 2019.

 

TEC is included in a consolidated U.S. federal income tax return with EUSHI and its subsidiaries. TEC’s income tax expense is based upon a separate return method, modified for the benefits-for-loss allocation in accordance with TECO Energy’s and EUSHI’s respective tax sharing agreements. The cash payments for federal income taxes and state income taxes made under those tax sharing agreements totaled $63 million and $77 million in 2019 and 2018, respectively. The cash payments mainly differ year over year due to pre-tax income and timing of tax depreciation deductions.    

For more information on our income taxes, including a reconciliation between the statutory federal income tax rate, the effective tax rate and impacts of tax reform, see Note 4 to the 2019 Annual TEC Consolidated Financial Statements.

 

LIQUIDITY, CAPITAL RESOURCES

Balances as of December 31, 2019  

 

 

 

 

 

 

(millions)

 

 

 

 

Credit facilities

 

$

550

 

Drawn amounts/LCs

 

 

349

 

Available credit facilities

 

 

201

 

Cash and short-term investments

 

 

14

 

Total liquidity

 

$

215

 

24


Cash from Operating Activities

Cash flows from operating activities in 2019 were $841 million, an increase of $39 million compared to 2018. The increase is primarily due to lower Tampa Electric fuel under-recoveries, higher conservation clause and PGA clause over-recoveries, increases in revenue collected for the in-service of solar generation projects, and the timing of accounts payable, partially offset by lower base rates due to impact of tax reform and lower environmental clause over-recoveries.

Cash from Investing Activities

Cash flows from investing activities in 2019 resulted in a net use of cash of $1.3 billion, which primarily reflects capital expenditures. TEC expects capital spending in 2020 to be approximately $1.4 billion. See the Capital Investments section for additional information.

Cash from Financing Activities

Cash flows from financing activities in 2019 resulted in net cash inflows of $441 million. TEC received $395 million of equity contributions from Parent, $292 million from long-term debt issuances (see Note 7 to the 2019 Annual TEC Consolidated Financial Statements for details) and $127 million from the net increase in short-term debt. These increases in cash flows were partially offset by dividend payments to Parent of $373 million.

Cash and Liquidity Outlook

TEC’s tariff-based gross margins are the principal source of cash from operating activities. A diversified retail customer mix, primarily consisting of rate-regulated residential, commercial, and industrial customers, provides TEC with a reasonably predictable source of cash. In addition to using cash generated from operating activities, TEC uses available cash and credit facility borrowings to support normal operations and capital requirements. TEC may reduce short-term borrowings with cash from operations, long-term borrowings, or capital contributions from Parent. TEC expects to make significant capital expenditures in 2020 as it invests in solar projects, the modernization of the Big Bend power plant, smart meters, gas distribution system expansion and other projects. See Capital Investments section below for further detail on TEC’s projected capital expenditures. TEC intends to fund those capital expenditures with available cash on hand, cash generated from operating activities, cash from equity contributions and debt issuances so that Tampa Electric and PGS maintain their capital structures consistent with the regulatory arrangements. Debt raised is subject to applicable regulatory approvals. Future financial market conditions could increase TEC’s interest costs which could reduce earnings and cash flows.

As noted earlier, cash from operating activities and short-term borrowings are used to fund capital expenditures, which may result in periodic working capital deficits. The working capital deficit as of December 31, 2019 was primarily caused by short-term borrowings and periodic fluctuations in assets and liabilities related to FPSC clauses and riders. At December 31, 2019, TEC’s unused capacity under its credit facilities was $201 million.  

TEC has credit facilities that provide $550 million of credit, including $150 million maturing in 2021 and $400 million available to 2022. See Note 6 to the 2019 Annual TEC Consolidated Financial Statements for additional information regarding the credit facilities. TEC believes that its liquidity is adequate for both the near and long term given its expected operating cash flows, capital expenditures and related financing plans.

TEC expects cash from operations in 2020 to be lower than in 2019 primarily due to lower recoveries of fuel and cost of gas sold, partially offset by increased revenues due to customer growth and solar investments at Tampa Electric (see Note 3 to the 2019 Annual TEC Consolidated Financial Statements). TEC plans to use cash in 2020 to fund capital spending and to pay dividends to its shareholder. Dividends are declared and paid at the discretion of TEC’s Board of Directors.

TEC’s credit facilities contain certain financial covenants (see Covenants in Financing Agreements section). TEC estimates that it could fully utilize the total available capacity under its facilities in 2020 and remain within the covenant restrictions.

Short-Term Borrowings

At December 31, 2019 and 2018, the following credit facilities and related borrowings existed.

 

 

 

December 31, 2019

 

 

December 31, 2018

 

 

 

 

 

 

 

 

 

 

 

Letters of

 

 

 

 

 

 

 

 

 

 

Letters of

 

 

 

Credit

 

 

Borrowings

 

 

Credit

 

 

Credit

 

 

Borrowings

 

 

Credit

 

(millions)

 

Facilities

 

 

Outstanding(1)

 

 

Outstanding

 

 

Facilities

 

 

Outstanding(1)

 

 

Outstanding

 

5-year facility (2)

 

$

400

 

 

$

295

 

 

$

1

 

 

$

325

 

 

$

131

 

 

$

1

 

3-year accounts receivable facility (3)

 

 

150

 

 

 

53

 

 

 

0

 

 

 

150

 

 

 

90

 

 

 

0

 

   Total

 

$

550

 

 

$

348

 

 

$

1

 

 

$

475

 

 

$

221

 

 

$

1

 

25


(1)

Borrowings outstanding are reported as notes payable.

(2)

This 5-year facility matures March 22, 2022.

(3)

This 3-year facility matures on March 22, 2021.

 

These credit facilities require commitment fees ranging from 12.5 to 35.0 basis points.  The weighted average interest rate on outstanding amounts payable under the credit facilities at December 31, 2019 and 2018 was 2.56% and 3.14%, respectively. For a complete description of the credit facilities see Note 6 to the 2019 Annual TEC Consolidated Financial Statements.

 

 

 

Maximum

 

 

Minimum

 

 

Average

 

 

Average

 

 

 

drawn

 

 

drawn

 

 

drawn

 

 

interest

 

(millions)

 

amount

 

 

amount

 

 

amount

 

 

rate

 

2019 credit facility utilization

 

$

396

 

 

$

13

 

 

$