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, 20222023

OR

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

For the transition period from to

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

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

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 disclosurewhether 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 delinquent filers“large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

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 Item 405Section 13(a) 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. ☒Exchange Act. ☐

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officersofficers during the relevant recovery period pursuant to §240.10D-1(b). ☐

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.

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, 20222023 was zero.

As of February 20, 2023,2024, 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:

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CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING INFORMATION

This Form 10-K contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties. The factors that could cause actual results to differ materially from the forward-looking statements made by TEC include those factors discussed herein, including those factors discussed with respect to TEC discussed in (a) Part I, Item 1A. Risk Factors, (b) Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and (c) Part II, Item 8. Financial Statements: Note 8, Commitments and Contingencies; and (d) other factors discussed in filings with the SEC by TEC. Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this Report. TEC does not undertake any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this Form 10-K.

All references to “dollars” and “$” in this and other filings with the U.S. Securities and Exchange Commission are references to U.S. dollars, unless specifically indicated otherwise.

PART I

Item 1. BUSINESS

Tampa Electric Company, referred to as TEC, was incorporated in Florida in 1899 and was reincorporated in 1949. 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 is a public utility operating within the State of Florida. At December 31, 2022 and forTEC is comprised of the year then ended, TEC had two operating segments. Its electric division, referred to as Tampa Electric, and prior to January 1, 2023, also included the natural gas division, referred to as PGS. Tampa Electric provides retail electric service to approximately 826,700839,960 customers in West Central Florida with a net winter system generating capacity of 6,5496,433 MW at December 31, 2022. 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 468,000 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 2022 was approximately 2.0 billion therms.2023.

On January 1, 2023, TEC transferred the assets and liabilities of its PGS division into a separate corporation called Peoples Gas System, Inc. This new corporation is a wholly owned subsidiary of a newly formed gas operations holding company, TECO Gas Operations, Inc., a wholly owned subsidiary of TECO Energy. See Note 1 to the 20222023 Annual TEC Consolidated Financial Statements for information regarding the separation of PGS from TEC.

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 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 20222023 Annual TEC Consolidated Financial Statements.

TEC Human Capital

TECTampa Electric had approximately 3,2362,546 employees as of December 31, 2022,2023, substantially all of whom are located in Florida. Tampa Electric had approximately 2,469Of these employees, as of December 31, 2022, of which 698706 were represented by the International Brotherhood of Electrical Workers and 165143 were represented by the Office and Professional Employees International Union. PGS had approximately 767 employees as of December 31, 2022. Approximately 94 employees in four of PGS’s 14 service areas and call center are represented by various union organizations.

In alignment with our efforts to promote inclusion and diversity, TEC has in place a company-wide Inclusion and Diversity initiative, which provides the organizational blueprint for achieving greater diversity and uniqueness of individuals and cultures and the varied perspectives they provide. Maintaining a robust pipeline of talent is crucial to TEC’s ongoing success and is a key aspect of succession planning efforts across the organization.

TEC is committed to investing in its employees through training and development programs as well as a tuition assistance program to promote continued professional growth. TEC provides a competitive compensation package that includes base pay, annual short-term incentives based on the achievement of corporate goals and performance, long-term incentives (applicable to eligible employee population), and health and retirement benefits.

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. At December 31, 2022,2023, Tampa

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Electric had two generating stations in or near Tampa, one generating station in southwestern Polk County, and 2125 photovoltaic power stations (twelve(thirteen in Hillsborough County, eightten in Polk County, and onetwo in Pasco County).

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

Tampa Electric Operating Revenue

Megawatt-hour Sales

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 several would have a significant adverse effect on Tampa Electric. Tampa Electric experiences summer peak loads due to the use of air conditioning and other cooling equipment and winter peak loads due to electric space heating and fewer daylight hours.

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 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, storm protection plan projects 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 2023 and 2022 base rates reflect a settlement agreement approved by the FPSC on November 10, 2021. Tampa Electric’s 2021 and 2020 results reflect a settlement agreement approved by the FPSC on November 6, 2017. See Note 3 to the 20222023 Annual TEC Consolidated Financial Statements for information regarding Tampa Electric’s base rates, ROE and other regulatory matters.

Other Cost Recovery

Tampa Electric has five cost recovery clauses.

During the fourth quarter of 2022,2023, the FPSC approved cost-recovery rates for the above clauses effective January 1, 2023.2024. See Note 3 to the 20222023 Annual TEC Consolidated Financial Statements for further information. In addition, Tampa Electric’s 2021 rate case settlement agreement established a mechanism to recover the costs of retiring coal generation units and meter assets over a period of 15 years. The recovery started in January 2022 and will survive the term of the settlement agreement.

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.

Generation Sources

In 2023 and 2022, and 2021, approximately 86%88% and 86%, respectively, of Tampa Electric’s gross generation of electricity was natural gas-fired, with solar representing 7%8% and 6%7%, respectively, and coal representing 7%4% and 8%7%, respectively. In 20222023 and 2021,2022, Tampa Electric used its generating units to meet approximately92% and 90% and 89%, respectively, of the total system load requirements, with the remaining 10%8% and 11%10%, 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 information regarding Tampa Electric’s generation costs.

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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, 2022, approximately 80%2023, 69% of Tampa Electric’s 2.0 million BCF of gas storage capacity was full. Tampa Electric has contracted for, 62%on average, 52% of its expected gas needs for the January through December 20232024 period. Tampa Electric expects to issue RFPsrequests for proposals (RFPs) to meet its remaining 20232024 gas needs and begin contracting for its 20242025 requirements. Additional volume requirements are purchased in the short-term spot market.

Coal. Tampa Electric burned less than 0.60.4 million tons of coal during 2022.2023. Coal consumption is expected to decrease in 20232024 compared to 2022.2023. Consistent with 2022,2023, Tampa Electric will be purchasing its coal in 20232024 under a contract with two different commodity suppliers. 100% of Tampa Electric's expected coal need in 2024 is under contract. Tampa Electric takes coal deliveries primarily by water and uses transportation agreements with a rail provider if spot coal supplies are needed.

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. 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. At December 31, 2022,2023, these agreements have various expiration dates ranging through 2052 and are expected to be renewed under similar terms and conditions.

Franchise fees expense totaled $67 million and $56 million in 2023 and $49 million in 2022, and 2021, respectively. Franchise fees are calculated using a formula based primarily on electric revenues and are recovered on a dollar-for-dollar basis 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 division and former PGS divisions,division, is a PRP for certain superfund sites and, through its former PGS division, for certain former manufactured gas plant sites. See Environmental Compliance section of the MD&A for additional information.As a result of the separation of the PGS division, PGS is now the responsible party for those sites (in addition to third party PRPs for certain sites). See Note 1 to the 2023 Annual TEC Consolidated Financial Statements for information regarding the separation of PGS from TEC.

PEOPLES GAS SYSTEM – Gas Operations

On January 1, 2023, TEC transferred the assets and liabilities of its PGS division into a separate corporation called Peoples Gas System, Inc. This new corporation is a wholly owned subsidiary of a newly formed gas operations holding company, TECO Gas Operations, Inc., a wholly owned subsidiary of TECO Energy. See Note 1 to the 2022 Annual TEC Consolidated Financial Statements for information regarding the separation of PGS from TEC. The following is a summary of the PGS division as operated under TEC through December 31, 2022. From and after January 1, 2023, the PGS business is no longer operated by TEC.

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.

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Gas is delivered to the PGS distribution system through three interstate pipelines. PGS operates a natural gas distribution system that serves approximately 468,000 customers. The system includes approximately 15,100 miles of gas mains and 8,400 miles of service lines (see PGS’s Franchises and Other Rights section below).

In 2022, the total throughput for PGS was approximately 2 billion therms. Of this total throughput, 7% was gas purchased and resold to customers by PGS, 88% was third-party supplied gas that was delivered to transportation-only customers and 5% 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 compressed natural gas vehicles and renewable natural gas operations. There are 56 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:

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

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 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.

See Note 31 to the 20222023 Annual TEC Consolidated Financial Statements for further information regarding PGS’s base rates, ROE and other regulatory matters.

Cost Recovery Clauses and Riders

the separation of 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 2023, was approved by the FPSC in November 2022.

In addition to its base rates and PGA clause charges, PGS customers also pay a per-therm charge for energy conservation and pipeline replacement programs. 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

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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. 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. The majority of the cast iron and bare steel pipe has been removed from the system, with the replacement of obsolete plastic pipe continuing under the rider through 2028.

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 the option to contract with companies that 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, 2022, PGS had approximately 26,900 transportation-only customers out of approximately 42,700 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 interstate pipelines on which PGS has reserved firm transportation capacity for delivery by PGS to its customers. In addition, PGS has reserved firm transportation capacity through intrastate pipelines owned by PGS’s affiliate,SeaCoast Gas Transmission, LLC.

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 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 122 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

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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. PGS’s franchise agreements have various expiration dates through 2052. PGS expects to negotiate up to 16 franchise renewals in 2023 under similar terms, in addition to those franchise agreements that have auto renewals effective during 2023. Franchise fees expense totaled $15 million and $13 millionTEC. For information regarding PGS's Business in 2022 and 2021, respectively. Franchise fees are calculated using various formulas which are based principallysee “Item 1. Business” of TEC’s Annual Report 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. See Note 8 to the 2022 Annual TEC Consolidated Financial Statements and the Environmental Compliance section of the MD&AForm 10-K for additional information.the year ended December 31, 2022.

Item 1A. RISK FACTORS

Risks Relating to TEC’s Business and Strategy

Regulatory, Legislative, and Legal Risks

TEC’s electric utilityTampa Electric is regulated; changes in regulation or the regulatory environment could reduce revenues, increase costs or competition.

TEC’s electric utilityTampa Electric operates in a regulated industry. Retail operations, including the rates charged and costs eligible for recovery under clauses, 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 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. Additionally, if regulators deny or delay cost recovery approvals, Tampa Electric’s earnings could be negatively impacted.

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

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

TEC’s business is 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.

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, contained emission guidelines for states to address GHG emissions from existing coal-fired electric generating units. On January 19, 2021, the D.C. Circuit vacated the ACE rule and remanded it to the EPA. A replacement rule is under development.

The outcome of the pending rulemaking process and expected further litigation, and its impact on Tampa Electric’s business, is uncertain at ‎this time; however, it could result in increased operating costs and/or decreased operations at Tampa Electric’s coal-fired plants. Tampa Electric currently expects prudently incurred costs for compliance to be recovered through rates. However, timing of recovery could impact earnings and cash flows, and increases in rates charged to customers could result in reduced sales.

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

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 20222023 Annual TEC Consolidated Financial Statements for further information regarding TEC’s income taxes.

Tampa Electric 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 relies 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:

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

Tampa Electric holds franchise agreements with counterparties throughout its service area. In some cases, these rights could be lost in the event of a breach of these agreements. These agreements are for set periods and could expire and not be renewed upon expiration of the then-current terms. Some agreements containFrom time to time municipalities seek to include provisions allowing municipalitiesthem to purchase the portion of the utility’s system located within a given municipality’s boundaries under certain conditions.

Operational and Construction Risks

TEC’s business is sensitive to variations in weather and the effects of extreme weather and havehas seasonal variations.

TEC’s utility business is affected by variations in general weather conditions including severe weather. Energy sales by its electric utility 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. Tampa Electric has both summer and winter peak periods that are dependent on weather conditions. Tampa Electric forecasts 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 may arise from the impacts of climate change. There is increasing public concern about climate change and growing support for reducing carbon dioxide emissions. Municipal, 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 and land use 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, 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 territory. Refer to “variations in weather” above.

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High winds and lack of precipitation increase the risk of wildfires resulting from TEC’s infrastructure. The risk of wildfires is addressed primarily through asset management, storm hardening, and vegetation management programs for the electric utility. If it is found to be responsible for such a fire, TEC could suffer material costs, losses and damages, which could materially affect TEC’s business, access to capital, financial condition and results of operations including its reputation with customers, regulators, governments and financial markets. Resulting costs could include fire suppression costs, regeneration, timber value, increased insurance costs and costs arising from damages and losses incurred by third parties.

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. Some of Tampa Electric’s fossil fueled generation assets are located at 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.

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 face litigation or regulatory action related to environmental harms from carbon dioxide 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. 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 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 and financial, billing and other business systems. TEC also relies on third party service providers 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. An outbreak of infectious disease, a pandemic or a similar public health threat such as COVID-19, may cause disruption in normal working patterns including wide scale “work from home” policies, which could increase cybersecurity risk as the quantity of both cyberattacks and network interfaces increases. Refer to the “Public Health Risk” section below.risk factor below regarding public health risk. 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. If not recovered through these

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means, they 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 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.

Continued effectsEffects of the COVID-19 pandemic, or an outbreak of infectious disease, another pandemic or a similar public health threat could have a negative impact on TEC’s operations.

An outbreak of infectious disease, a pandemic or a similar public health threat such as the COVID-19 pandemic, or a fear of any of the foregoing, could adversely impact TEC, including by causing operating, supply chain and project development delays and disruptions, labor shortages and shutdowns (including as a result of government regulation and prevention measures), and delays in regulatory decisions and proceedings, which could have a negative impact on TEC’s operations.

Any adverse changes in general economic and market conditions arising as a result of a public health threat could negatively impact demand for electricity, and natural gas, revenue, operating costs, timing and extent of capital expenditures, results of financing efforts, or credit risk, counterparty risk and collection risk, which could result in a material adverse effect on TEC’s business.

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 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.

Florida electric utilities, including Tampa Electric, currently benefit from operating in a regulated environment with limited competition in their market for retail customers. However, the commercial and regulatory frameworks under which Tampa Electric operates can be impacted by changes in government and shifts in government policy. These include initiatives regarding deregulation or restructuring of the energy industry, which may result in increased competition and unrecovered costs that could adversely affect operations, net income and cash flows.

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

Tampa Electric depends 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 business.

TEC’s business is 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.

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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.

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.

Developments in technology could reduce demand for electricity.

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 otherwise make Tampa Electric’s existing generating facilities uneconomic. Advances in such technologies could reduce demand for electricity, 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. TEC 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, including in the markets where TEC operates, 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 and Capital Requirements Risks

TEC’s 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 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 potential inability to meet the requirements of the 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:

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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 or rates of return used to determine benefit assets or 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, 20222023 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.

TEC’s capital plan includes significant investments in generation, infrastructure modernization and customer-focused technologies. Any projects planned or currently in construction, particularly significant capital projects, may be subject to risks including, but not limited to, impact on costs from schedule delays, risk of cost overruns, ensuring compliance with operating and environmental requirements and other events within or beyond TEC’s control. 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. Some of the factors that can affect TEC’s credit ratings are cash flows, liquidity, the amount of debt as a component of total capitalization, political, legislative, and regulatory actions, and changes in Emera’s credit ratings.

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 $129$166 million at December 31, 2022.2023.

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TEC may be subject to risks relating to its separation from PGS.

On January 1, 2023, TEC completed the separation from its former PGS division to PGSI. TEC’s business is less diversified as a result of the separation since its remaining Tampa Electric business serves only electric utility customers and operates in a more narrow geographic area than its former PGS division.

In connection with the separation, TEC and PGSI entered into an intercompany loan agreement. Borrowings under the loan agreement mature on December 29, 2023. TEC expects that PGSI will access the third-party lending market during 2023 to obtain independent financing, and repay the loans on or prior to their maturity date. During 2023, TEC is subject to certain risks in connection with the loan agreement, which risks include that PGSI may default on its obligations under the loan agreement. In addition, under the terms of the loan agreement TEC may be required to use a portion of its existing available liquidity to provide additional revolving loans to PGSI (for which PGSI has agreed to reimburse TEC for all costs and expenses).

The separation is intended to be a tax-free transaction for U.S. federal income tax purposes. The IRS has issued a private letter ruling (IRS Ruling) to the effect that, subject to the limitations specified therein and the accuracy and compliance with certain representations, warranties and covenants, the distribution of the PGSI stock, together with certain related transactions, will qualify as a tax-free “reorganization” for U.S. federal income tax purposes. If any of these items are inaccurate, the separation may not qualify for tax-free treatment, which could result in material tax liabilities for TEC.

Item 1C. CYBERSECURITY

TEC assesses, identifies, and manages material risks from cybersecurity threats under the governance of its Cyber Security Framework and Information Security Policy, as well as several related policies and procedures addressing areas such as threat vulnerability management, cyber risk management, data protection and classification, network security, access control, incident response, security awareness, employee training and asset management. These policies and related standards require identification of all Information Technology (IT) and Operational Technology (OT) critical facilities and/or cyber assets, and sufficient controls for IT and OT asset inventory, including responsibilities for assets, information owners, and asset disposition processes. From a security perspective, TEC’s Information Security group is directed at protecting all aspects of data and how information is stored, transmitted, processed, and used in business processes. TEC’s Corporate Security group is responsible for protecting physical assets including critical facilities, protection of employees, and related physical security risks.

TEC’s Information Security group of the Information Technology department has the direct responsibility for developing, monitoring, and enforcing information security standards and procedures; reviewing and approving all network interconnections for compliance to security standards; and assisting, consulting, and training individuals throughout TEC in the use of appropriate information security practices. This group is responsible for ensuring that all IT and OT cyber systems, assets, and networks are aligned with Emera and affiliate cybersecurity framework. TEC engages independent third party consultants from time to time to assess the adequacy of its cybersecurity measures and assist in implementing any appropriate actions to address any vulnerabilities identified. In addition, TEC participates in an Electric Power Research Institute (EPRI) research project to develop cybersecurity performance metrics. EPRI offers a web-based platform, which supports automated cybersecurity data collection, security metrics calculation, visualization, and analysis. The Vice President of Information Technology and Chief Information Officer (CIO), who reports to the President and Chief Executive Officer, oversees this group and is responsible for managing the program, in collaboration with TEC’s businesses and functions. TEC’s CIO has advanced degrees in computer science and extensive experience in cybersecurity and information technology, including many years of experience at large organizations leading cybersecurity, IT processes and controls, strategy, architecture, delivery and support of IT applications, and overseeing large groups of employees and contractors responsible for carrying out these responsibilities.

TEC’s Vendor Risk Management process includes conducting risk assessments to identify and monitor cybersecurity risks associated with third-party service providers, including threat detection and security event notifications. TEC also has requirements for third-party service providers which include regulatory compliance and meeting the National Institute of Standards and Technology Cybersecurity Framework policy and standards. TEC’s processes also provide for mitigating cybersecurity risk from third parties through seeking to include in its agreements with third-party service providers, as applicable, cybersecurity provisions designed to appropriately address such risks.

TEC’s IT Business Continuity – Emergency Contingency Response Plan is updated periodically and reviewed at least annually. This plan includes guidelines for the escalation and communication of cybersecurity incidents, including a requirement to timely report to TEC’s executive leadership and Board of Directors based on an assessment of the risk and other specified criteria. TEC has established a cyber incident response team to prepare for, mitigate, and remediate cybersecurity incidents, which is integrated within Emera’s enterprise crisis management framework.

Cybersecurity risks are integrated into TEC’s overall risk management process through the collaboration of the cybersecurity professionals and TEC’s and Emera’s risk management functions to assess threat levels on an affiliate and corporate basis and identify steps and resources appropriate to manage such risks. The Board of Directors oversees the management of risks from cybersecurity threats through receiving regular reports from the CIO, which include updates on TEC’s performance with preparing, preventing, detecting, responding to, mitigating, and recovering from cybersecurity incidents. Should a cybersecurity threat or incident pose a significant risk to TEC, TEC's processes provide that the CIO, through the CEO, as appropriate, would promptly inform the Board regarding any such threat or incident. The CIO also provides regular updates on the key elements of its cybersecurity program to the Emera Board’s Risk and Sustainability Committee, which has oversight over Emera’s enterprise risk management framework, including oversight over cybersecurity risk.

While to date TEC has not detected a significant compromise of its cybersecurity systems, significant data loss or any material financial losses related to cybersecurity attacks, it is possible that TEC could experience a significant event in the future. Risks and exposures related to cybersecurity attacks are expected to remain high for the foreseeable future due to the rapidly evolving nature and sophistication of these threats. See Item 1A. Risk Factors, “TEC is exposed to potential risks related to cyberattacks and unauthorized access, which could cause system failures, disrupt operations or adversely affect safety” for a further discussion of risks related to cybersecurity.

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 has electric generating stations in service, with a December 20222023 net winter generating capability of 6,5496,433 MWs. Tampa Electric assets include the Big Bend Power Station (2,023(1,623 MWs capacity), the Bayside Power Station (2,083(2,138 capacity) and the Polk Power Station (1,420 MWs capacity). Also included in Tampa Electric’s assets as of December 31, 20222023 are twenty-onetwenty-five solar arrays (1,023(1,252 MWs).

Tampa Electric owns 20872 transmission substations havingand 138 distribution substations with an aggregate transformer capacity of 25,45316,823 mega volts amps. The Tampa Electric system has an 7,865 mega volts amps of generator step up unit capacity. The transmission system consists of approximately 1,3491,362 total circuit miles of high voltage transmission lines, including underground and double-circuit lines. The distribution system consists of approximately 6,2026,137 circuit miles of overhead lines and approximately 6,1736,476 circuit miles of underground lines. As of December 31, 2022,2023, there were 839,977853,555 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 and PGS.

PEOPLES GAS SYSTEM

PGS’s distribution system extends throughout the areas it serves in Florida and consisted of approximately 23,500 miles of pipe, including approximately 15,100 miles of mains and 8,400 miles of service lines, at December 31, 2022. 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 by PGS. The PGS properties were contributed to PGSI, and from and after January 1, 2023, are no longer properties of TEC.

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

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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 20222023 Annual TEC Consolidated Financial Statements.

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. [RESERVED]

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

OVERVIEW

At December 31, 2023, Tampa Electric served approximately 840,000 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 6,433 MW.

Prior to January 1, 2023, TEC had regulated electric and gas utility operations in Florida. From and after January 1, 2023, the gas utility operations are operated by PGSI, which is no longer a subsidiary of TEC. AtSee Note 1 to the 2023 Annual TEC Consolidated Financial Statements for information regarding the separation of PGS from TEC. For information regarding PGS in 2022 and 2021, 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, 2022, Tampa Electric served approximately 826,700 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 6,549 MW. PGS, Florida’s largest gas distribution utility, served approximately 468,000 residential, commercial, industrial and electric power generating customers at December 31, 2022 in all major metropolitan areas of the state, with a total natural gas throughput of approximately 2.0 billion therms in 2022.

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 20222023 Annual TEC Consolidated Financial Statements for information regarding related party transactions.

20222023 PERFORMANCE

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

In 2022,2023, TEC’s net income was $540$466 million, compared with $446$540 million in 2021.2022. 2023 net income decreased compared to 2022 results were impacted by higher base revenues, partially offset by higher depreciation expense, higher O&M expense, higher interest expense and lower AFUDC.primarily due to the separation of PGS from TEC on January 1, 2023 (see section below for further information on the separation). See Operating Company Results below for further detail on the results of operations at Tampa Electric during 2023 compared to 2022. For information regarding 2022 results as compared to 2021. For information regarding 2021, including PGS results, as compared to 2020, 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, 2021.2022.

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.

On January 1, 2023, TEC transferred the assets and liabilities of its PGS division into a separate corporation called Peoples Gas System, Inc. This new corporation is a wholly owned subsidiary of a newly formed gas operations holding company, TECO Gas Operations, Inc., a wholly owned subsidiary of TECO Energy. As a result, from and after January 1, 2023, the PGS division is no longer operated by TEC. See Note 1 to the 2022 Annual TEC Consolidated Financial Statements for further information regarding the separation of PGS from TEC.

Tampa Electric anticipates earning within itstowards the lower end of the ROE range in 2023. New base rates effective January 1,2024. Normalizing 2023 as a result of the 2021 settlement agreement will result in Tampa Electric 2023 earnings to be higher than in 2022. Normalizing 2022 for weather, Tampa Electric sales volumes in 20232024 are projected to be higher than in 20222023 due to customer growth. Tampa Electric expects customer growth rates in 20232024 to be similar with 2022,comparable to 2023, reflective of currentthe expected economic growth in Florida.

18On August 16, 2023, Tampa Electric filed a petition to implement the 2024 Generation Base Rate Adjustment provisions pursuant to the 2021 rate case settlement agreement. Inclusive of Tampa Electric’s ROE adjustment, the increase of $22 million was approved by the FPSC and the order reflecting such approval was issued on November 17, 2023, effective in January 2024.

On February 1, 2024, Tampa Electric notified the FPSC of its intent to seek a base rate increase, reflecting a revenue requirement increase of approximately $290 to $320 million, effective in January 2025, and additional adjustments of approximately $100 million and $70 million for 2026 and 2027, respectively. Tampa Electric’s proposed rates include recovery of solar generation projects, energy storage capacity, a more resilient and modernized energy control center, and numerous other resiliency and reliability projects. The filing range amounts are estimates until Tampa Electric completes its analysis and files the case in April 2024. The FPSC will hear the case in the third quarter of 2024 with a decision expected by the end of 2024.

On January 23, 2023, TEC petitioned the FPSC for recovery of the storm reserve regulatory asset and the replenishment of the balance in the storm reserve to the previously approved storm reserve level of $56 million, for a total of $131 million. The storm cost recovery surcharge was approved by the FPSC on March 7, 2023, and TEC began applying the surcharge on April 2023 bills. Subsequently, on November 9, 2023, the FPSC approved TEC’s petition, filed on August 16, 2023, to update the total storm cost collection to $134 million. It also changed the collection of the expected remaining balance of $29 million as of December 31, 2023, from over the first three months of 2024 to over the 12 months of 2024. The storm recovery is subject to review of the underlying costs for prudency and accuracy by the FPSC and issuance of an order by the FPSC is expected by the third quarter of 2024. In September 2023, Tampa Electric was impacted by Hurricane Idalia. The related storm restoration costs were approximately $35 million, which were charged to the storm reserve regulatory asset and not included in the petition above. Tampa Electric will determine the timing of the request for recovery of Hurricane Idalia costs at a future time.

On January 23, 2023, TEC requested an adjustment to its fuel charges to recover the final 2022 fuel under-recovery of $518 million over a period of 21 months. The request also included an adjustment to 2023 projected fuel costs to reflect the reduction in natural gas prices since September 2022 for a projected reduction of $170 million for the balance of 2023. The proposed changes will be decidedwere approved by the FPSC inon March 7, 2023, and recovery is expected to begin inwere effective beginning on April 1, 2023.

In September 2022, Tampa Electric was impacted by Hurricane Ian. The majority of Hurricane Ian restoration costs were charged against Tampa Electric’s FPSC-approved storm reserve, resulting in minimal impact on earnings and capital expenditures. Total restoration costs were $126 million, with $119 million charged to the storm reserve. Restoration costs charged to the storm reserve exceed the reserve balance and this amount will be deferred and collected from customers in subsequent periods. In November 2022, Tampa Electric incurred costs of approximately $2 million related to Hurricane Nicole. In January 2023, Tampa Electric petitioned the FPSC for recovery of storm costs. Recovery will include costs associated with Hurricanes Ian and Nicole that exceeded the reserve, $10 million of storm restoration costs charged to the reserve since 2018, and the replenishment of the balance in the reserve to the $56 million level that existed as of October 31, 2013 for a total of approximately $131 million. The proposed changes will be decided by the FPSC in March 2023, and recovery is expected to begin in April 2023 through March 2024.

Tampa Electric has a capital investment program that supports achieving its goal to reduce CO2 emissions to 60% of 2000 levels by 2025. Since 2000, Tampa Electric has reduced its CO2 emissions by more than 50%.

In 2023,2024, Tampa Electric expects to invest approximately $1.3 billion, excluding AFUDC, in capital projects. Capital projects support normal system reliability and growth. AFUDC will be earned on eligible capital projects during the construction periods. Tampa Electricinclude solar investments, include solarstorm hardening investments, grid modernization and storm hardening investments.building resilience. 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. OurTEC's reported operating results are affected by several critical accounting estimates (see the Critical Accounting Policies and Estimates section).

The following table shows the revenues and net income of the business segments on a U.S. GAAP basis (see Note 11 to the 20222023 Annual TEC Consolidated Financial Statements).

TAMPA ELECTRIC

Electric Operations Results

Tampa Electric’s net income in 20222023 was $458$466 million, compared with $369$458 million in 2021.2022. Results primarily reflected higher revenues resulting from the 2021 rate case settlement agreement favorable weather and customer growth, partially offset by higher depreciationinterest expense and higher interestdepreciation 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