株探米国株
英語
エドガーで原本を確認する
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U.S. Securities and Exchange Commission
Washington, D.C. 20549
Form 40-F
☐ REGISTRATION STATEMENT PURSUANT TO SECTION 12 OF THE SECURITIES EXCHANGE ACT OF 1934
OR
☒ ANNUAL REPORT PURSUANT TO SECTION 13(a) OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2024
TC ENERGY CORPORATION
(Commission File Number 1-31690)

TRANSCANADA PIPELINES LIMITED
(Commission File Number 1-8887)
(Exact name of Registrant as specified in its charter)
Canada
(Province or other jurisdiction of incorporation or organization)
4922, 4923, 4924, 5172
(Primary Standard Industrial Classification Code Number (if applicable))
Not Applicable
(TC Energy Corporation)
(I.R.S. Employer Identification Number (if applicable))
52-2179728
(TransCanada PipeLines Limited)
(I.R.S. Employer Identification Number (if applicable))
TC Energy Tower, 450 - 1 Street S.W.
Calgary, Alberta, Canada, T2P 5H1
(403) 920-2000
(Address and telephone number of Registrant's principal executive offices)
TransCanada PipeLine USA Ltd., 700 Louisiana Street, Suite 700
Houston, Texas, 77002-2700; (832) 320-5201
(Name, address (including zip code) and telephone number (including area code)
of agent for service in the United States)
Securities registered or to be registered pursuant to Section 12(b) of the Act:
Title of each class Trading Symbol(s) Name of each exchange on which registered
Common Shares (including Rights under Shareholder Rights Plan) of TC Energy Corporation TRP New York Stock Exchange

Securities registered or to be registered pursuant to Section 12(g) of the Act: None
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:
Debt Securities of TransCanada PipeLines Limited

For annual reports, indicate by check mark the information filed with this Form:
☒
Annual information form
☒
Audited annual financial statements
Indicate the number of outstanding shares of each of the issuer's classes of capital or common stock as of the close of the period covered by the Annual report.
At December 31, 2024, 1,039,095,489 common shares;
18,424,004 Cumulative Redeemable First Preferred Shares, Series 1;
3,575,996 Cumulative Redeemable First Preferred Shares, Series 2;
9,997,177 Cumulative Redeemable First Preferred Shares, Series 3;
4,002,823 Cumulative Redeemable First Preferred Shares, Series 4;
12,070,593 Cumulative Redeemable First Preferred Shares, Series 5;
1,929,407 Cumulative Redeemable First Preferred Shares Series 6;
24,000,000 Cumulative Redeemable First Preferred Shares Series 7;
16,702,797 Cumulative Redeemable First Preferred Shares Series 9;
1,297,203 Cumulative Redeemable First Preferred Shares Series 10; and
10,000,000 Cumulative Redeemable First Preferred Shares, Series 11
of TC Energy Corporation were issued and outstanding.

At December 31, 2024, 992,720,977 common shares of TransCanada PipeLines Limited,
which were all owned by TC Energy Corporation, were issued and outstanding.

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or 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 (§232.405 of this chapter) 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 whether the Registrant is an emerging growth company as defined in Rule 12b-2 of the Exchange Act.
Emerging growth company ☐

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the Registrant 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.

†The term "new or revised financial accounting standard" refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.

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 officers during the relevant recovery period pursuant to §240.10D-1(b). ☐





The documents (or portions thereof) forming part of this Form 40-F are incorporated by reference into the following registration statements under the Securities Act of 1933, as amended:
Form Registration No.
TC Energy Corporation
S-8 333-5916
S-8 333-8470
S-8 333-9130
S-8 333-151736
S-8 333-184074
S-8 333-227114
S-8 333-237979
F-3 33-13564
F-3 333-6132
F-10 333-250988
F-10 333-252123
TransCanada PipeLines Limited
F-10 333-267323
F-10 333-283633


EXPLANATORY NOTE
TransCanada PipeLines Limited (“TransCanada PipeLines”) is a wholly owned subsidiary of TC Energy Corporation (“TC Energy”). As of the date of filing of this Form 40-F, TransCanada PipeLines is relying on the continuous disclosure documents filed by TC Energy pursuant to an exemption from the requirements of National Instrument 51-102 - Continuous Disclosure Obligations and as provided in the decision of the Alberta Securities Commission and the Ontario Securities Commission in Re TransCanada Corporation, 2019 ABASC 1, issued on January 3, 2019. Consistent with the exemptive relief, information contained in this Form 40-F is that provided by TC Energy except as indicated below.


AUDITED CONSOLIDATED FINANCIAL STATEMENTS AND
MANAGEMENT'S DISCUSSION & ANALYSIS
Except sections specifically referenced below which shall be deemed incorporated by reference herein and filed, no other portion of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements to shareholders, except as otherwise specifically incorporated by reference in the TC Energy Annual information form, shall be deemed filed with the U.S. Securities and Exchange Commission (the "Commission") as part of this report under the Exchange Act.
A.    Audited Consolidated Financial Statements
For audited consolidated financial statements, including the auditors' report, see pages 139 through 226 of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements included herein.
B.    Management's Discussion and Analysis
For management's discussion and analysis, see pages 9 through 138 of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements included herein under the heading "Management's discussion and analysis".
C.    Management's Report on Internal Control over Financial Reporting
For management's report on internal control over financial reporting, see "Management's Report on Internal Control over Financial Reporting" that accompanies the audited consolidated financial statements on page 139 of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements included herein.
UNDERTAKING
Each Registrant undertakes to make available, in person or by telephone, representatives to respond to inquiries made by the Commission staff, and to furnish promptly, when requested to do so by the Commission staff, information relating to: the securities registered pursuant to Form 40-F; the securities in relation to which the obligation to file an annual report on Form 40-F arises; or transactions in said securities.
DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROL OVER FINANCIAL REPORTING
For information on disclosure controls and procedures and management's annual report on internal control over financial reporting, see "Other information - Controls and Procedures" on page 119 of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements.
AUDIT COMMITTEE FINANCIAL EXPERT
Each Registrant's Board of Directors has determined that it has at least one audit committee financial expert serving on its Audit committee. Ms. Una Power has been designated as an audit committee financial expert and is independent, as that term is defined by the New York Stock Exchange's listing standards applicable to each Registrant. The Commission has indicated that the designation of Ms. Power as an audit committee financial expert does not make Ms. Power an "expert" for any purpose, impose any duties, obligations or liability on Ms. Power that is greater than those imposed on members of the Audit committee and Board of Directors who do not carry this designation or affect the duties, obligations or liability of any other member of the Audit committee.
CODE OF ETHICS
The Registrants have adopted a code of business ethics ("Code") for their directors, officers, employees and contractors. In 2024, the Code was updated with amendments to include reference to the new Procurement Policy; basic generative Artificial Intelligence (AI) governance language based on existing language found in the Acceptable Use Policy, but with specific reference to generative AI; and updated Privacy Office content to align with current program language. The Code is continually updated to ensure alignment with our corporate values and goals, as such certain ancillary amendments were made to this effect in 2025.
The Registrants' Code is available on TC Energy's website at www.tcenergy.com and any person can obtain the Code without charge upon request from the Corporate Secretary of TC Energy. No waivers have been granted from any provision of the Code during the 2024 fiscal year.


PRINCIPAL ACCOUNTANT FEES AND SERVICES
Our independent registered public accounting firm is KPMG LLP, Calgary, AB, Canada, Auditor Firm ID: 85. For information on principal accountant fees and services, see "Audit committee - Pre-approval Policies and Procedures" and "Audit committee - External Auditor Service Fees" on page 32 of the TC Energy 2024 Annual information form.
OFF-BALANCE SHEET ARRANGEMENTS
The Registrants have no off-balance sheet arrangements, as defined in this Form, other than the guarantees and commitments described in Note 31 of the Notes to the audited consolidated financial statements attached to this Form 40-F and incorporated herein by reference.
DISCLOSURE OF CONTRACTUAL OBLIGATIONS
For information on disclosure of contractual obligations, see "Financial Condition - Contractual obligations" in Management's discussion and analysis on page 90 of the TC Energy 2024 Management's discussion and analysis and audited consolidated financial statements.
IDENTIFICATION OF THE AUDIT COMMITTEE
Each Registrant has a separately-designated standing Audit committee. The members of the Audit committee as of February 13, 2025 (unless otherwise indicated) are:
Chair:
Members:
U. Power
S. Bonham
C.F. Campbell
M.R. Culbert
W.D. Johnson
S.C. Jones
D. Madahbee Leach
DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not Applicable.
FORWARD-LOOKING INFORMATION
We disclose forward-looking information to help the reader understand management's assessment of our future plans and financial outlook, and our future prospects overall.
Statements that are forward looking are based on certain assumptions and on what we know and expect today and generally include words like anticipate, expect, believe, may, will, should, estimate or other similar words.
Forward-looking statements included or incorporated by reference in this document include information about the following, among other things:
•our financial and operational performance, including the performance of our subsidiaries
•expectations about strategies and goals for growth and expansion, including acquisitions
•expected cash flows and future financing options available along with portfolio management
•expectations regarding the size, structure, timing, conditions and outcome of ongoing and future transactions
•expected dividend growth
•expected access to and cost of capital
•expected energy demand levels
•expected costs and schedules for planned projects, including projects under construction and in development
•expected capital expenditures, contractual obligations, commitments and contingent liabilities, including environmental remediation costs
•expected regulatory processes and outcomes
•expected outcomes with respect to legal proceedings, including arbitration and insurance claims
•expected impact of future tax and accounting changes
•commitments and targets contained in our Report on Sustainability and GHG Emissions Reduction Plan, including statements related to our GHG emissions intensity reduction goals


•expected industry, market and economic conditions, and ongoing trade negotiations, including their impact on our customers and suppliers.
Forward-looking statements do not guarantee future performance. Actual events and results could be significantly different because of assumptions, risks or uncertainties related to our business or events that happen after the date of this document.
Our forward-looking information is based on the following key assumptions and subject to the following risks and uncertainties:
Assumptions
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•regulatory decisions and outcomes
•planned and unplanned outages and the utilization of our pipelines, power and storage assets
•integrity and reliability of our assets
•anticipated construction costs, schedules and completion dates
•access to capital markets, including portfolio management
•expected industry, market and economic conditions, including the impact of these on our customers and suppliers
•inflation rates, commodity and labour prices
•interest, tax and foreign exchange rates
•nature and scope of hedging.
Risks and uncertainties
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•our ability to successfully implement our strategic priorities, including the Focus Project, and whether they will yield the expected benefits
•our ability to implement a capital allocation strategy aligned with maximizing shareholder value
•operating performance of our pipelines, power generation and storage assets
•amount of capacity sold and rates achieved in our pipeline businesses
•amount of capacity payments and revenues from power generation assets due to plant availability
•production levels within supply basins
•construction and completion of capital projects
•cost, availability of, and inflationary pressures on, labour, equipment and materials
•availability and market prices of commodities
•access to capital markets on competitive terms
•interest, tax and foreign exchange rates
•performance and credit risk of our counterparties
•regulatory decisions and outcomes of legal proceedings, including arbitration and insurance claims
•our ability to effectively anticipate and assess changes to government policies and regulations, including those related to the environment
•our ability to realize the value of tangible assets and contractual recoveries
•competition in the businesses in which we operate
•unexpected or unusual weather
•acts of civil disobedience
•cybersecurity and technological developments
•sustainability-related risks including climate-related risks and the impact of energy transition on our business
•economic and political conditions, and ongoing trade negotiations in North America, as well as globally
•global health crises, such as pandemics and epidemics, and the impacts related thereto.
You can read more about these factors and others in reports we have filed with Canadian securities regulators and the Commission.
As actual results could vary significantly from the forward-looking information, you should not put undue reliance on forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking statements due to new information or future events, unless we are required to by law.


DOCUMENTS FILED AS PART OF THIS REPORT
EXHIBITS
13.1
13.2
13.3
23.1
31.1
31.2
32.1
32.2
97.1
99.1
101.SCH Inline XBRL Taxonomy Extension Schema Document.
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF Inline XBRL Taxonomy Definition Linkbase Document.
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document.
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document.
104 Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).



SIGNATURES
Pursuant to the requirements of the Exchange Act, each Registrant certifies that it meets all of the requirements for filing on Form 40-F and has duly caused this annual report to be signed on its behalf by the undersigned, thereto duly authorized, in the City of Calgary, Province of Alberta, Canada.
  TC ENERGY CORPORATION
TRANSCANADA PIPELINES LIMITED
(Registrants)
  By: /s/ SEAN P. O'DONNELL
   
SEAN P. O'DONNELL
Executive Vice-President, Strategy and Corporate Development and Chief Financial Officer
Date: February 14, 2025

EX-13.1 2 a12312024tceaifenglish.htm ANNUAL INFORMATION FORM Document
EXHIBIT 13.1


TC Energy Corporation
2024 Annual information form
February 13, 2025



















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Contents
TC ENERGY CORPORATION
BUSINESS OF TC ENERGY
Power and Energy Solutions
Health, safety, sustainability and environmental protection and social policies
Fitch
DBRS
TC Energy Annual information form 2024 | 1

Presentation of information
Throughout this Annual information form (AIF), the terms, we, us, our, the Company and TC Energy mean TC Energy Corporation and its subsidiaries. In particular, TC Energy includes references to TransCanada PipeLines Limited (TCPL). The term subsidiary, when referred to in this AIF, with reference to TC Energy means direct and indirect wholly-owned subsidiaries of, and legal entities controlled by, TC Energy or TCPL, as applicable.
Unless otherwise noted, the information contained in this AIF is given at or for the year ended December 31, 2024 (Year End). Amounts are expressed in Canadian dollars, unless otherwise indicated. Information in relation to metric conversion can be found at Schedule A to this AIF. The Glossary found at the end of this AIF contains certain terms defined throughout this AIF and abbreviations and acronyms that may not otherwise be defined in this document.
Certain portions of TC Energy's management's discussion and analysis dated February 13, 2025 (MD&A) are incorporated by reference into this AIF as stated below and noted elsewhere in this AIF. The MD&A can be found on SEDAR+ (www.sedarplus.ca) under TC Energy's profile.
Financial information is presented in accordance with United States (U.S.) generally accepted accounting principles (GAAP).
2 | TC Energy Annual information form 2024

Forward-looking information
This AIF, including the MD&A disclosure incorporated by reference herein, contains certain information that is forward looking and is subject to important risks and uncertainties. We disclose forward-looking information to help the reader understand management’s assessment of our future plans and financial outlook and our future prospects overall.
Statements that are forward looking are based on certain assumptions and on what we know and expect today and generally include words like anticipate, expect, believe, may, will, should, estimate or other similar words.
Forward-looking statements included or incorporated by reference in this AIF include information about the following, among other things:
•our financial and operational performance, including the performance of our subsidiaries
•expectations about strategies and goals for growth and expansion, including acquisitions
•expected cash flows and future financing options available along with portfolio management
•expectations regarding the size, structure, timing, conditions and outcome of ongoing and future transactions
•expected dividend growth
•expected access to and cost of capital
•expected energy demand levels
•expected costs and schedules for planned projects, including projects under construction and in development
•expected capital expenditures, contractual obligations, commitments and contingent liabilities, including environmental remediation costs
•expected regulatory processes and outcomes
•expected outcomes with respect to legal proceedings, including arbitration and insurance claims
•expected impact of future tax and accounting changes
•commitments and targets contained in our Report on Sustainability and GHG Emissions Reduction Plan, including statements related to our GHG emissions intensity reduction goals
•expected industry, market and economic conditions, and ongoing trade negotiations, including their impact on our customers and suppliers.
Forward-looking statements do not guarantee future performance. Actual events and results could be significantly different because of assumptions, risks or uncertainties related to our business or events that happen after the date of this AIF.
Our forward-looking information is based on the following key assumptions and subject to the following risks and uncertainties:
Assumptions
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•regulatory decisions and outcomes
•planned and unplanned outages and the utilization of our pipelines, power and storage assets
•integrity and reliability of our assets
•anticipated construction costs, schedules and completion dates
•access to capital markets, including portfolio management
•expected industry, market and economic conditions, including the impact of these on our customers and suppliers
•inflation rates, commodity and labour prices
•interest, tax and foreign exchange rates
•nature and scope of hedging.
Risks and uncertainties
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•our ability to successfully implement our strategic priorities, including the Focus Project, and whether they will yield the expected benefits
•our ability to implement a capital allocation strategy aligned with maximizing shareholder value
•operating performance of our pipelines, power generation and storage assets
•amount of capacity sold and rates achieved in our pipeline businesses
•amount of capacity payments and revenues from power generation assets due to plant availability
TC Energy Annual information form 2024 | 3

•production levels within supply basins
•construction and completion of capital projects
•cost, availability of, and inflationary pressures on, labour, equipment and materials
•availability and market prices of commodities
•access to capital markets on competitive terms
•interest, tax and foreign exchange rates
•performance and credit risk of our counterparties
•regulatory decisions and outcomes of legal proceedings, including arbitration and insurance claims
•our ability to effectively anticipate and assess changes to government policies and regulations, including those related to the environment
•our ability to realize the value of tangible assets and contractual recoveries
•competition in the businesses in which we operate
•unexpected or unusual weather
•acts of civil disobedience
•cybersecurity and technological developments
•sustainability-related risks including climate-related risks and the impact of energy transition on our business
•economic and political conditions, and ongoing trade negotiations in North America, as well as globally
•global health crises, such as pandemics and epidemics, and the impacts related thereto.
You can read more about these factors and others in the MD&A and in other reports we have filed with Canadian securities regulators and the SEC.
As actual results could vary significantly from the forward-looking information, you should not put undue reliance on
forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking statements due to new information or future events unless we are required to by law.
4 | TC Energy Annual information form 2024

TC Energy Corporation
CORPORATE STRUCTURE
Our head office and registered office are located at 450 – 1 Street S.W., Calgary, Alberta, T2P 5H1. TC Energy was incorporated pursuant to the provisions of the Canada Business Corporations Act (CBCA) on February 25, 2003 in connection with a plan of arrangement with TCPL (Arrangement), which established TC Energy as the parent company of TCPL. The Arrangement was approved by TCPL common shareholders on April 25, 2003 and, following court approval and the filing of Articles of Arrangement, the Arrangement became effective on May 15, 2003. TCPL continues to carry on business as the principal operating subsidiary of TC Energy. TC Energy does not hold any material assets directly other than the common shares of TCPL and receivables from certain of TC Energy's subsidiaries.
On October 1, 2024, TC Energy separated into two independent, publicly listed companies through the spinoff of its Liquids Pipelines business into South Bow Corporation (South Bow) by way of a plan of arrangement under the CBCA (the Spinoff Transaction). In connection with the Spinoff Transaction, TC Energy restated its Articles of Incorporation on October 1, 2024 to effectively consolidate previous amendments made to its articles which provided for the issuance of various series of preferred shares.
INTERCORPORATE RELATIONSHIPS
The following diagram presents the name and jurisdiction of incorporation, continuance or formation of TC Energy’s principal subsidiaries as at Year End. Each of the subsidiaries shown has total assets that exceeded 10 per cent of the consolidated assets of TC Energy as at Year End or revenues that exceeded 10 per cent of the consolidated revenues of TC Energy as at Year End. Except as otherwise indicated below, TC Energy beneficially owns, controls or directs, directly or indirectly, 100 per cent of the voting shares or units in each of these subsidiaries.
mic_2024xaiforgchartxengli.jpg
TC Energy Corporation Canada TransCanada PipeLines Limited Canada TransCanada PipeLine USA Ltd. Nevada TransCanada American Investments Ltd. Delaware Columbia Pipeline Group, Inc. Delaware Columbia Pipelines Holding Company, LLC2 Delaware Columbia Pipelines Operating Company, LLC2 Delaware Columbia Gas Transmission, LLC2 Delaware 15142083 Canada Ltd. Canada 6297782 LLC Delaware TransCanada Oil Pipelines Inc. Delaware 701671 Alberta Ltd.1 Alberta TransCanada Mexican Investments Ltd.1 Alberta
The above diagram does not include all of the subsidiaries of TC Energy. The total assets and revenues of excluded subsidiaries in the aggregate did not exceed 20 per cent of the consolidated assets of TC Energy as at Year End or consolidated revenues of TC Energy as at Year End.
1 701671 Alberta Ltd. and TransCanada Mexican Investments Ltd. assets and revenues do not exceed 10 per cent of the total consolidated assets or revenues of TC Energy but have been included to meet the total consolidated revenues and assets criteria of excluded subsidiaries threshold of less than 20 per cent.
2 TC Energy beneficially owns, controls or directs, directly or indirectly, 60 per cent of the voting shares or units in each of these subsidiaries.
TC Energy Annual information form 2024 | 5

Business of TC Energy
We operate in two core businesses – Natural Gas Pipelines and Power and Energy Solutions. In order to provide information that is aligned with how management decisions about our businesses are made and how performance of our businesses is assessed, our results are reflected in four operating segments: Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines, Mexico Natural Gas Pipelines and Power and Energy Solutions. We also have a Corporate segment consisting of corporate and administrative functions that provide governance, financing and other support to TC Energy's business segments.
For information regarding our Natural Gas Pipelines business, including pipeline holdings, developments, opportunities, regulation and competitive position refer to the Natural Gas Pipelines Business, Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines and Mexico Natural Gas Pipelines sections of the MD&A, which sections are incorporated by reference herein.
For information regarding our Power and Energy Solutions business, including holdings, developments, opportunities, regulation and competitive position refer to the Power and Energy Solutions section of the MD&A, which section is incorporated by reference herein.
Refer to the About our business – 2024 Financial highlights - Consolidated results section of the MD&A for our revenues from operations by segment, for the years ended December 31, 2024 and 2023, which section is incorporated by reference herein.
General development of the business
Summarized below are significant developments that have occurred in our Natural Gas Pipelines, Liquids Pipelines and Power and Energy Solutions businesses, respectively, and certain acquisitions, dispositions, events or conditions which have had an influence on those developments, during the last three financial years and year to date in 2025. Further information about developments in our business, including changes that we expect will occur in 2025, can be found in the Natural Gas Pipelines Business, Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines, Mexico Natural Gas Pipelines, Power and Energy Solutions, About our business - Capital program - Secured projects, and Discontinued operations sections of the MD&A, which sections are incorporated by reference herein.
6 | TC Energy Annual information form 2024

NATURAL GAS PIPELINES
Developments in the Canadian Natural Gas Pipelines Segment
CANADIAN REGULATED PIPELINES
2021 NGTL System Expansion Program
The 2021 NGTL System Expansion Program was completed in 2024 and consists of 344 km (214 miles) of new pipeline, three new compressor units and associated facilities and added approximately 1.59 PJ/d (1.45 Bcf/d) of incremental capacity to the NGTL System. The capital cost of the program was $3.6 billion.
2022 NGTL System Expansion Program
The 2022 NGTL System Expansion Program was completed in 2023 and consists of approximately 166 km (103 miles) of new pipeline, one compressor unit and associated facilities and provides incremental capacity of approximately 773 TJ/d (722 MMcf/d) to meet firm-receipt and intra-basin delivery requirements with eight-year minimum terms. The capital cost of the program was $1.4 billion.
2023 NGTL System Intra-Basin Expansion
The NGTL System Intra-Basin Expansion was completed in 2024 and consists of 23 km (14 miles) of new pipeline and two new compressor stations and is underpinned by approximately 255 TJ/d (238 MMcf/d) of new firm-service contracts with 15-year terms. The capital cost of the expansion was $0.5 billion.
NGTL System/Foothills West Path Delivery Program
The NGTL System/Foothills West Path Delivery Program was completed in 2023 and consisted of a multi-year expansion of the NGTL System and Foothills system to facilitate incremental contracted export capacity connecting to the GTN pipeline system. The combined NGTL System and Foothills program consists of approximately 107 km (66 miles) of pipeline and associated facilities and is underpinned by 275 TJ/d (258 MMcf/d) of new firm-service contracts with terms that exceed 30 years. The capital cost of the program was $1.6 billion.
Valhalla North and Berland River Project
In November 2022, we sanctioned the Valhalla North and Berland River (VNBR) Project to serve aggregate system requirements and connect migrating supply to key demand markets, designed to provide incremental capacity on the NGTL System of approximately 428 TJ/d (400 MMcf/d). With an estimated capital cost of $0.5 billion, the project consists of approximately 33 km (21 miles) of new pipeline, one new non-emitting electric compressor unit and associated facilities. On December 21, 2023, we received approval from the CER to construct, own and operate the VNBR project. Construction activities commenced in 2024 with anticipated in-service dates commencing in second quarter 2026.
NGTL Ownership Transfer
On April 1, 2024, ownership of the NGTL System was transferred from Nova Gas Transmission Ltd. to NGTL GP Ltd. on behalf of NGTL Limited Partnership as part of an ordinary course corporate reorganization to support business optimization. The previously announced equity interest purchase agreement in respect of the sale by TC Energy of a 5.34 per cent interest in the NGTL System and Foothills Pipeline assets to an Indigenous-owned investment partnership was terminated by TC Energy on February 6, 2025.
NGTL System - Revenue Requirement Settlement and Multi-Year Growth Plan
On September 26, 2024, the CER approved a five-year negotiated revenue requirement settlement commencing on January 1, 2025.
The settlement enables an investment framework that supports our Board of Directors' approval to allocate approximately $3.3 billion of capital towards progression of a new multi-year growth plan for expansion facilities on the NGTL System. It is comprised of multiple distinct projects with targeted in-service dates between 2027 and 2030, subject to final company and regulatory approvals. The completion of the multi-year growth plan is expected to enable approximately 1.0 Bcf/d of incremental system throughput.
The settlement maintains an ROE of 10.1 per cent on 40 per cent deemed common equity while increasing NGTL System depreciation rates, with an incentive that allows the NGTL System the opportunity to further increase depreciation rates if tolls fall below specified levels, or if growth projects are undertaken. The settlement introduces a new incentive mechanism to reduce both physical emissions and emissions compliance costs, which builds on the incentive mechanism for certain operating costs where variances from projected amounts and emissions savings are shared with our customers. A provision for review by customers exists in the settlement if tolls exceed a pre-determined level or if final company approvals of the multi-year growth plan are not obtained.
TC Energy Annual information form 2024 | 7

LNG PIPELINE PROJECTS
Coastal GasLink Pipeline
The Coastal GasLink pipeline is a 671 km (417 mile) pipeline that transports natural gas from a receipt point in the Dawson Creek area of British Columbia to LNG Canada's (LNGC) natural gas liquefaction facility near Kitimat, British Columbia. Transportation service on the pipeline is underpinned by 25-year TSAs (with renewal provisions) with each of the five LNGC joint venture participants (LNGC Participants). We hold a 35 per cent ownership interest in Coastal GasLink LP (CGL LP), the entity that owns the Coastal GasLink pipeline. Additionally, we hold a 100 percent ownership interest in the general partner of CGL LP, the entity that is contracted to develop, construct and operate the pipeline.
In July 2022, CGL LP executed definitive agreements with LNGC Participants, TC Energy and the other CGL LP partners (collectively, the July 2022 Agreements) that amended existing project and funding agreements to address and resolve disputes over certain incurred and anticipated project costs. Subsequent to the execution of the July 2022 Agreements, the project faced material cost pressures, driven by labour, contractor and weather challenges, which ultimately increased the estimated cost of the project to approximately $14.5 billion, excluding potential cost recoveries and after accounting for certain factors that may be outside the control of CGL LP. In connection with this cost estimate, we announced our expectation that additional equity contributions required to fund the incremental project costs would be predominantly funded by us, with no anticipated change to our 35 per cent ownership interest. We further announced that our share of equity contributions over the project life was expected to be an amount of up to $5.5 billion.
The expectation that additional equity contributions would predominantly be funded by us resulted in the recognition of other-than-temporary impairments to the carrying value of our investment in CGL LP in each of the four quarters up to and including September 30, 2023. As a result, we recorded cumulative pre-tax impairment charges of $5,148 million ($4,586 million after tax) between December 2022 and September 2023. There has been no further indication of other-than-temporary impairments of our investment in CGL LP since September 2023 and we have not recorded any further impairment charges.
In 2023, the Coastal GasLink pipeline project successfully achieved mechanical completion, completed pipeline commissioning activities and was ready to deliver gas to the LNGC facility. These milestones entitled CGL LP to receive a $200 million readiness incentive payment from LNGC which, in accordance with the contractual terms between the CGL LP partners, fully accrued in December 2023 and was paid in full to TC Energy as the project developer in February 2024.
In June 2024, CGL LP successfully completed a $7.15 billion refinancing of its existing construction credit facility through a private placement bond offering of senior secured notes to Canadian and U.S. investors. Proceeds from the offering were used to repay the majority of the outstanding $8.0 billion balance on CGL LP's construction credit facility. The remaining balance on the construction credit facility was settled through the use of proceeds from the unwinding of certain hedging arrangements associated with the construction credit facility.
In November 2024, CGL LP executed a commercial agreement with LNGC and LNGC Participants that declared commercial in-service for the pipeline, allowing for the collection of tolls from customers retroactive to October 1, 2024. The agreement also includes a one-time payment of $199 million from LNGC Participants to TC Energy in recognition of the completion of certain work and the final settlement of costs. The payment is to be made by LNGC Participants upon the earlier of three months after the declared in-service of the LNGC facility, or December 15, 2025. The payment accrues in full to TC Energy in accordance with the contractual terms between the CGL LP partners and has been accounted for as an in-substance distribution from CGL LP.
Under the terms of the July 2022 Agreements, equity financing required to fund construction of the pipeline to completion was initially provided through a subordinated loan agreement, with a committed capacity of $3,375 million, between TC Energy and CGL LP (the Subordinated Loan). Draws by CGL LP on the Subordinated Loan were to be repaid with funds from equity contributions to the partnership by the CGL LP partners, including us, after the Coastal GasLink pipeline was in service.
In December 2024, following the commercial in-service of the Coastal GasLink pipeline, CGL LP repaid the $3,147 million balance owing to TC Energy under the Subordinated Loan. Our share of equity contributions required by CGL LP to fund repayment of the Subordinated Loan amounted to $3,137 million. At December 31, 2024, our share of total partner equity contributions to fund the capital cost of the project was $5.3 billion. While unused capacity of $228 million remains available under the Subordinated Loan, we do not anticipate that CGL LP will draw on a significant portion of the remaining availability.
In late third quarter 2024, the Coastal GasLink pipeline began delivering commissioning gas to the LNGC facility. Post-construction reclamation activities are expected to be complete in 2025 and the project remains on track with its capital cost estimate of approximately $14.5 billion. CGL LP continues to pursue cost recovery, including certain arbitration proceedings which involve claims by, and the defense of certain claims against, CGL LP. With the exception of settlements made with respect to certain contractor disputes, including with SA Energy Group, these claims have not yet been conclusively determined, but our expectation is that these proceedings are likely to result in net cost recoveries.
8 | TC Energy Annual information form 2024

Coastal GasLink - Cedar Link Expansion
In June 2024, CGL LP sanctioned the Cedar Link project following a positive final investment decision (FID) for the construction of the Cedar LNG facility by the Cedar LNG joint venture partners, Haisla Nation and Pembina Pipeline Corporation. The Cedar LNG facility is a proposed floating liquefied natural gas facility to be constructed in Kitimat, B.C. The Cedar Link project is an expansion of the Coastal GasLink pipeline that is expected to enable delivery of up to 0.4 Bcf/d of natural gas to the Cedar LNG facility. With an estimated cost of $1.2 billion, the expansion project includes the addition of a new compressor station, connector pipeline and meter station to the existing Coastal GasLink pipeline infrastructure.
Funding for the expansion will be provided through project-level credit facilities of up to $1.4 billion secured by CGL LP in June 2024, equity funding to be provided by the CGL LP partners, including us, and the recovery of construction carrying costs from LNGC Participants who have elected to make payments on a quarterly basis throughout construction. The incremental funds available through the project-level credit facilities and cash AFUDC payments provide additional contingency to mitigate future funding requirements for CGL LP should costs exceed initial estimates of $1.2 billion. TC Energy has entered into an equity contribution agreement to fund up to a maximum of $37 million for its proportionate share of the equity requirements related to the Cedar Link project.
All major regulatory permits have been received and construction began in July 2024. The planned in-service date for the Cedar Link project is 2028, subject to the completion of plant commissioning activities at the Cedar LNG facility.
Coastal GasLink - Indigenous Equity Option
In March 2022, we announced the signing of option agreements to sell up to a 10 per cent equity interest in CGL LP, to Indigenous communities across the project corridor, from our current 35 per cent equity ownership. The equity option is exercisable after commercial in-service of the Coastal GasLink pipeline, subject to customary regulatory approvals and consents, including the consent of LNGC. As a result of the commercial agreement with LNGC and LNGC Participants, the Coastal GasLink pipeline was declared commercially in service prior to the LNGC plant. Accordingly, we are actively collaborating with the participating Indigenous communities to establish a mutually agreeable timeframe in which the option can be exercised.
TC Energy Annual information form 2024 | 9

Developments in the U.S. Natural Gas Pipelines Segment
U.S. NATURAL GAS PIPELINES - COLUMBIA PIPELINE GROUP
Columbia Gas and Columbia Gulf Monetization
On October 4, 2023, we completed the sale of a 40 per cent equity interest in Columbia Gas and Columbia Gulf to Global Infrastructure Partners (GIP) for proceeds of $5.3 billion (US$3.9 billion). Columbia Gas and Columbia Gulf are held by a newly formed entity with GIP. Preceding the close of the equity sale, on August 8, 2023, Columbia Pipelines Operating Company LLC and Columbia Pipelines Holding Company LLC issued US$4.6 billion and US$1.0 billion of long-term, senior unsecured debt, respectively. The net proceeds from the offerings were used to repay existing intercompany indebtedness with TC Energy entities and were directed towards reducing leverage. We continue to have a controlling interest in Columbia Gas and Columbia Gulf and we remain the operator of these pipelines. TC Energy and GIP each fund their proportionate share of annual maintenance, modernization and sanctioned growth capital expenditures through internally generated cash flows, debt financing within the Columbia entities, or from proportionate contributions from TC Energy and GIP.
Columbia Gas Rate Case Settlement
In September 2024, Columbia Gas filed a Section 4 rate case with FERC requesting an increase to the maximum transportation rates expected to become effective April 1, 2025, subject to refund. We intend to pursue a collaborative process to find a mutually beneficial outcome with our customers through settlement.
Columbia Gas - VR Project
In July 2021, we approved the VR Project, a delivery market project on Columbia Gas designed to replace and upgrade certain facilities while improving reliability and reducing emissions. In November 2023, the FERC provided a certificate order approving the VR Project. The VR Project is subject to customary conditions precedent and normal-course regulatory approvals. It is anticipated to be in-service in 2025.
Columbia Gas - KO Transmission Enhancement Acquisition
On April 28, 2022, we approved the approximately US$80 million acquisition of KO Transmission assets to be integrated into our Columbia Gas pipeline to provide additional last-mile connectivity of Columbia Gas into northern Kentucky and southern Ohio to growing LDC markets and a platform for future capital investments including future conversions of coal-fueled power plants in the region. FERC approval for the acquisition was received in November 2022 and the transaction closed in February 2023.
Columbia Gas - Virginia Electrification Project
In February 2024, the Virginia Electrification Project, an expansion project that replaced and upgraded certain facilities through conversion to electric compression, was placed in service.
Columbia Gulf Rate Settlement
On July 7, 2023, Columbia Gulf filed an uncontested rate settlement, which set new recourse rates for Columbia Gulf effective March 1, 2024 and instituted a rate moratorium through February 28, 2027. Columbia Gulf must file for new rates no later than March 1, 2029.
Columbia Gulf - Louisiana XPress Project
The Louisiana XPress project, a Columbia Gulf project designed to connect natural gas supply to U.S. Gulf Coast LNG export facilities, was phased into service over the course of third quarter 2022.
Columbia Gulf - Pulaski and Maysville Projects
In November 2024, we approved two projects on our Columbia Gulf System: the Pulaski and Maysville Projects. These mainline extension projects off Columbia Gulf will facilitate full coal-to-gas conversion at two existing power plants and are expected to provide 0.2 Bcf/d of capacity for incremental gas-fired generation. The projects have anticipated in-service dates in 2029 and total estimated costs of US$0.7 billion.
Columbia Gulf - Southeast Virginia Energy Storage Project
In November 2024, we approved the US$0.3 billion Southeast Virginia Energy Storage Project. This is an LNG peaking facility in southeast Virginia that will serve an existing LDC's growing winter peak day load and mitigate its peak day pricing exposure, as well as increase operational flexibility on the Columbia Gas system. The project has an anticipated in-service date of 2030.
10 | TC Energy Annual information form 2024

OTHER U.S. NATURAL GAS PIPELINES
ANR Section 4 Rate Case
ANR reached a settlement with its customers effective August 2022 and received FERC approval in April 2023. As part of the settlement, there is a moratorium on any further rate changes until November 1, 2025. ANR must file for new rates with an effective date no later than August 1, 2028. The settlement also included an additional rate step up effective August 2024 related to certain modernization projects. In second quarter 2023, previously accrued rate refund liabilities, including interest, were refunded to customers.
ANR Pipeline - Alberta XPress Project
The Alberta XPress Project, an expansion project on ANR which utilizes existing capacity on the Great Lakes and Canadian Mainline systems to connect growing supply from the WCSB to U.S. Gulf Coast LNG export markets, was placed in service January 2023.
ANR Pipeline - Elwood Power Project/ANR Horsepower Replacement
The Elwood Power Project/ANR Horsepower Replacement, an expansion project to replace, upgrade and modernize certain facilities while improving reliability and reducing GHG emissions along a highly utilized section of the ANR pipeline system, was placed in service in November 2022.
ANR Pipeline - Wisconsin Access Project
The Wisconsin Access Project, a project to replace, upgrade and modernize certain facilities while improving reliability and reducing GHG emissions along portions of the ANR pipeline system, was placed in service in November 2022.
ANR Pipeline - WR Project
In November 2021, we approved the WR Project, a delivery market project on ANR to replace and upgrade certain facilities while improving reliability and reducing emissions along portions of the ANR pipeline system in principal delivery markets. In December 2023, the FERC approved the WR Project. It is expected to be placed in service in late 2025.
ANR Pipeline - Ventura XPress Project
In December 2022, we approved the Ventura XPress Project, a set of ANR projects designed to improve base system reliability and allow for additional long-term contracted transportation services to a point of delivery on the Northern Border pipeline at Ventura, Iowa. The project is expected to be placed in service in 2025.
ANR Pipeline - Heartland Project
In February 2024, we approved the US$0.9 billion Heartland Project, an expansion project on our ANR system that is expected to increase capacity and improve system reliability. The Heartland Project involves pipeline looping, compressor facility additions as well as upgrades and is expected to increase ANR’s overall market share in the Midwest region. The anticipated in-service date is late 2027.
Gas Transmission Northwest LLC (GTN) - GTN XPress
In December 2024, the GTN XPress project, an expansion of the GTN system that will provide for the transport of incremental contracted export capacity facilitated by the NGTL System/Foothills West Path Delivery Program, was placed in service. The capital cost of this project was approximately US$0.1 billion.
Great Lakes Rate Settlement
In April 2022, FERC approved Great Lakes' unopposed rate case settlement with its customers by which Great Lakes and the settling parties agreed to maintain existing recourse rates through October 31, 2025.
Gillis Access Project
In March 2024, the Gillis Access Project, a 68 km (42 mile) greenfield pipeline system that connects gas production sourced from the Gillis hub to downstream markets in southeast Louisiana, was placed in service. The capital cost of this project was approximately US$0.3 billion.
Gillis Access Project - Extension
In February 2023, we approved a 63 km (39 mile), 1.4 Bcf/d extension of the Gillis Access Project to further connect supplies from the Haynesville basin at Gillis. Effective September 1, 2024, all remaining shipper conditions expired and the project was expanded to 1.9 Bcf/d. The project has anticipated in-service dates starting in late 2026 and total estimated costs of US$0.4 billion.
North Baja - North Baja XPress Project
In June 2023, the North Baja XPress Project, an expansion project designed to expand capacity and meet increased customer demand on our North Baja pipeline, was placed in service.
TC Energy Annual information form 2024 | 11

Portland Natural Gas Transmission System (PNGTS)
On March 4, 2024, we announced that TC Energy and its partner Northern New England Investment Company, Inc., a subsidiary of Énergir L.P. (Énergir), entered into a purchase and sale agreement to sell PNGTS to BlackRock, through a fund managed by its Diversified Infrastructure business, and investment funds managed by Morgan Stanley Infrastructure Partners (the Purchaser). On August 15, 2024, we completed the sale of PNGTS for a gross purchase price of approximately $1.6 billion (US$1.1 billion), which included US$250 million of senior notes outstanding held at PNGTS and assumed by the Purchaser. We are providing customary transition services and will continue to work jointly with the Purchaser to facilitate the safe and orderly transition of this natural gas system.
Bison XPress Project
In third quarter 2023, we approved the Bison XPress Project, an expansion project on our Northern Border and Bison systems that will replace and upgrade certain facilities and provide much needed production egress from the Bakken basin to a delivery point at the Cheyenne Hub. In October 2024, FERC provided a certificate order approving the project that has an anticipated in-service date in 2026.
12 | TC Energy Annual information form 2024

Developments in the Mexico Natural Gas Pipelines Segment
MEXICO NATURAL GAS PIPELINES
TGNH Strategic Alliance with the CFE
In August 2022, we announced a strategic alliance with Mexico’s state-owned electric utility, the CFE, for the development of new natural gas infrastructure in central and southeast Mexico. In connection with the strategic alliance, we reached an FID to develop and construct the Southeast Gateway pipeline, a 1.3 Bcf/d, 715 km (444 mile) offshore natural gas pipeline to serve the southeast region of Mexico. We continue to be aligned with the CFE on finalizing the remaining project completion activities for achieving an in-service date of May 1, 2025. The estimated project cost for the Southeast Gateway pipeline is approximately US$3.9 billion, which is lower than the initial cost estimate of US$4.5 billion.
During second quarter 2024, upon the CFE’s equity injection of US$340 million as well as non-cash consideration in recognition of the completion of certain contractual obligations, including land acquisition and permitting support, the CFE became a partner in TGNH with a 13.01 per cent equity interest. Provided that the CFE's contractual commitments are met related to land acquisition, community relations and permitting support, the CFE's equity in TGNH would build up to a maximum of 15 per cent with the in-service of the Southeast Gateway pipeline and will increase to approximately 35 per cent upon expiry of the contract in 2055.

Tula
In third quarter 2022, we placed the east section of the Tula pipeline into commercial service and we reached an agreement with the CFE to jointly develop and complete the remaining segments of the Tula pipeline, with the central segment subject to an FID. Due to the delay of an FID, recording AFUDC on the assets under construction for the Tula pipeline project was suspended in late 2023.
Villa de Reyes
We placed the north and lateral sections of the Villa de Reyes pipeline into commercial service in third quarter 2022 and third quarter 2023, respectively. We continue to work with our partner, the CFE, to complete the south section of the Villa de Reyes pipeline. The in-service date will be determined upon resolution of outstanding stakeholder issues.
TC Energy Annual information form 2024 | 13

LIQUIDS PIPELINES
Developments in the Liquids Pipelines Segment
Spinoff Transaction
On July 27, 2023, we announced plans to separate into two independent, investment-grade, publicly listed companies through the spinoff of our Liquids Pipelines business into its own entity named South Bow Corporation. TC Energy shareholders voted to approve the Spinoff Transaction at our 2024 Annual and Special Meeting of shareholders held on June 4, 2024. The Spinoff Transaction received final approval from the Court of King’s Bench of Alberta on June 4, 2024 and was completed on October 1, 2024. The Spinoff Transaction was effected by way of a plan of arrangement under the CBCA pursuant to which, among other things, holders of TC Energy common shares retained their interest in TC Energy and received a pro rata allocation of South Bow’s common shares.
On October 1, 2024, TC Energy and South Bow entered into a separation agreement setting forth the terms of the separation of the Liquids Pipelines business from the business of TC Energy, including the transfer of certain assets related to the Liquids Pipelines business from TC Energy to South Bow and the allocation of certain liabilities and obligations related to the Liquids Pipelines business between TC Energy and South Bow. The separation agreement provides, among other things, that TC Energy will indemnify South Bow for 86 per cent of total net liabilities and costs associated with the Milepost 14 incident and the existing variable toll disputes on the Keystone Pipeline System (excluding any future impacts to the variable toll after October 1, 2024) subject to a maximum liability to South Bow of $30 million, in aggregate, for those two matters. Due to the inherent uncertainties of the final amounts to be settled under these indemnities, any amounts that may ultimately be payable in respect of these net liabilities to South Bow could differ materially from those reported at December 31, 2024.
14 | TC Energy Annual information form 2024

POWER AND ENERGY SOLUTIONS
Developments in the Power and Energy Solutions Segment
CANADIAN POWER
Canadian Cogeneration Plants
In 2024, we executed contract extensions of 5-years at Mackay River, a natural gas cogeneration plant located in Alberta, and 10-years at Grandview, a natural gas cogeneration plant located in New Brunswick.
Saddlebrook Solar
In October 2023, we completed construction of the 81 MW Saddlebrook Solar project near Aldersyde, Alberta and began commissioning activities, including supplying generation to the Alberta market. Full commercial operation was achieved on January 5, 2024. The project was partially supported with funding from Emissions Reduction Alberta and Lockheed Martin.
Renewable Energy Contracts and/or Investment Opportunities
In November 2023, a majority of the 297 MW Sharp Hills Wind Farm achieved commercial operation resulting in the commencement of our 15-year Power Purchase Agreement for 100 per cent of the power produced and the rights to all environmental attributes from the facility. In second quarter 2023, we finalized contracts to sell 50 MW under our 24-by-7 carbon-free power offering in Alberta, which provides customers power and carbon credits for the decarbonization of the customers’ Scope 2 emissions. Contract terms range from 15 to 20 years and commenced in January 2025.
Bruce Power
The Unit 6 MCR, which began in January 2020, was declared commercially operational in September 2023, ahead of schedule and on budget despite challenges from the COVID-19 pandemic.
In first quarter 2023, Unit 3 was removed from service and began its MCR construction, with an expected return to service in 2026.
The Unit 4 MCR final cost and schedule estimate was submitted to the IESO in December 2023, and received IESO approval on February 8, 2024. The Unit 4 MCR commenced on January 31, 2025 with an expected completion in 2028.
The Unit 5 MCR final cost and schedule estimate was submitted to the IESO on January 31, 2025. Future MCR investments will be subject to discrete decisions for each unit with specified off-ramps available for Bruce Power and the IESO.
In 2021, Bruce Power launched Project 2030 with the goal of achieving a site peak output of 7,000 MW by 2033 in support of climate change targets and future clean energy needs. Project 2030 will focus on continued asset optimization, innovation and leveraging new technology, which could include integration with storage and other forms of energy, to increase the site peak output at Bruce Power. Project 2030 is arranged in three stages with Stage 1, 2 and 3a fully approved for execution. Stage 1 started in 2019 and is expected to add 150 MW of output and Stage 2, which began in early 2022, is targeting another 200 MW. Bruce Power is also progressing with Stage 3a which is designed to provide an additional incremental capacity of approximately 90 MW.
Bruce Power's contract price increased in April 2022, in accordance with contract terms, reflecting capital to be invested under the Unit 3 MCR program and the 2022 to 2024 Asset Management program plus normal annual inflation adjustments. The contract price was then increased again in April 2024 as a result of the IESO approving the Unit 4 MCR program and will increase again in April 2025 to reflect the 2025 to 2027 Asset Management program plus normal annual inflation adjustments and the 9-year reset for salaries and pensions.
Ontario Pumped Storage Project (OPSP)
We continue to progress the development of the OPSP, a pumped hydro storage facility located near Meaford, Ontario. The 1,000-megawatt project will provide enough electricity to power 1 million homes for up to 11 hours, while enhancing the reliability and efficiency of Ontario's electricity system. This project is designed to store emission-free energy when available and provide that energy to Ontario during periods of peak demand, thereby maximizing the value of nuclear and other existing emissions-free generation in the province. We and our prospective partners, Saugeen Ojibway Nation, will advance pre-development work on the OPSP following the Ontario Government's recent announcement on January 24, 2025 to invest up to $285 million. With the Ontario Government’s investment, the OPSP can now advance critical development work, including the completion of a detailed cost estimate, the commencement of federal and provincial environmental assessments, advanced design and engineering and continued community engagement. The OPSP remains subject to approval by our Board of Directors, the Saugeen Ojibway Nation and the Government of Ontario.
U.S. POWER
In March 2023, we acquired 100 per cent of the Class B Membership interests in the 155 MW Fluvanna Wind Farm located in Scurry County, Texas for US$99 million, before post-closing adjustments. In June 2023, we acquired 100 per cent of the Class B Membership Interests in the 148 MW Blue Cloud Wind Farm located in Bailey County, Texas for US$125 million, before post-closing adjustments. In addition to these two wind farms, as of December 31, 2024, we have approximately 350 MW of wind generation PPAs and associated environmental attributes in the U.S.
OTHER ENERGY SOLUTIONS
In October 2022, we acquired a 30 per cent ownership interest in the Lynchburg Renewable Fuels project, a renewable natural gas (RNG) production facility in Lynchburg, Tennessee being developed by 3 Rivers Energy Partners, LLC (3 Rivers Energy). Along with our ownership interest, we will market all RNG and environmental attributes generated from the facility once operational, which we expect in 2025.
TC Energy Annual information form 2024 | 15

General
EMPLOYEES
At Year End, TC Energy's principal operating subsidiary, TCPL, had 6,668 employees, substantially all of whom were employed in Canada and the U.S., as set forth in the following table.
Calgary 2,179 
Western Canada (excluding Calgary) 584 
Eastern Canada 276 
Houston 751 
U.S. Midwest 779 
U.S. Northeast 249 
U.S. Southeast/Gulf Coast (excluding Houston) 1,133 
U.S. West Coast 85 
Mexico 632 
Total 6,668 
HEALTH, SAFETY, SUSTAINABILITY AND ENVIRONMENTAL PROTECTION AND SOCIAL POLICIES
A discussion of our health, safety, sustainability and environmental protection policies can be found in the MD&A in the Other information – Health, safety, sustainability and environmental matters section, which section is incorporated by reference herein.
Social Policies
We have a number of corporate governance documents, such as policies and standards, including a Commitment Statement, to help guide our teams’ behavior and actions, so they understand their responsibility and extend respect, courtesy and the opportunity to respond to Indigenous groups and other stakeholders. We have a Code of Business Ethics (COBE) Policy which applies to all employees, officers and directors, and contingent workforce contractors of TC Energy and its wholly-owned subsidiaries and operated entities in countries where we conduct business, with the exception of independently operated entities whose corporate governance documents meet or exceed TC Energy’s requirements. Annual online COBE training is provided to all employees and contingent workforce contractors, and all employees and contingent workforce contractors (including executive officers) and directors must certify their compliance with COBE annually.
We also have an Avoiding Bribery and Corruption (ABC) Program which includes an ABC Policy, annual online training included as part of annual online COBE training, instructor-led training provided to personnel in higher risk areas of our business, a supplier and contractor due diligence review process, and auditing of certain types of transactions.
Our Indigenous Relations Policy is informed by our guiding principles and corporate values to ensure we build and sustain support through early and honest communication, by mitigating impacts, and through mutually beneficial partnerships. We seek to listen to Indigenous peoples and incorporate their traditional and local knowledge in project design and planning. We strive to work with Indigenous communities to mitigate negative impacts and maximize benefits through hiring and buying locally. We aim to build mutually beneficial, partnership-oriented relationships with Indigenous communities who are most impacted by our activities. In Canada, we will seek to expand benefits for equity participation in our projects because the best way to align interests from the start is to sit at the table together as partners/owners. Through all these efforts, we strive to be considered as a partner of choice for Indigenous groups and play a meaningful role in reconciliation.
Consistent with our corporate values, Commitment Statement and as outlined in our COBE Policy, TC Energy does not tolerate human rights abuses. In our business activities, including engaging with Indigenous groups and other stakeholders across Canada, the U.S and Mexico, we are committed to respecting human rights and will not be complicit with, or engage in, any activity that supports or facilitates abuse of human rights such as forced labour, child labour, or physical or mental abuses.
16 | TC Energy Annual information form 2024

Risk factors
A discussion of our risk factors can be found in the MD&A in the Natural Gas Pipelines Business, Natural Gas Pipelines - Business risks, Power and Energy Solutions – Business risks and Other information – Risk oversight and enterprise risk management sections, which sections are incorporated by reference herein.
Dividends
Our Board has not adopted a formal dividend policy. The Board reviews the financial performance of TC Energy quarterly and makes a determination of the appropriate level of dividends to be declared in the following quarter. Currently, our payment of dividends is primarily funded from dividends TC Energy receives as the sole common shareholder of TCPL.
Provisions of various trust indentures and credit arrangements with certain of our subsidiaries can restrict those subsidiaries’ ability and, in certain cases, our ability to declare and pay dividends or make distributions under certain circumstances. In the opinion of management, these provisions do not currently restrict our ability to declare or pay dividends.
Additionally, pursuant to the terms of the trust notes issued by TransCanada Trust (a financing trust subsidiary wholly-owned by TCPL) and related agreements, in certain circumstances, including where holders of the trust notes receive deferral preferred shares of TCPL in lieu of cash interest payments and where exchange preferred shares of TCPL are issued to holders of the trust notes as a result of certain bankruptcy related events, TC Energy and TCPL would be prohibited from declaring or paying dividends on or redeeming their outstanding preferred shares (or, if none are outstanding, their respective common shares) until all such exchange or deferral preferred shares are redeemed by TCPL. No deferral preferred shares or exchange preferred shares of TCPL have ever been issued.
Dividends on our preferred shares are payable quarterly, as and when declared by the Board. The dividends declared on our common and preferred shares during the past three completed financial years, and the increase to the quarterly dividend per common share on our outstanding common shares for the quarter ending March 31, 2025, are set out in the MD&A under the heading About our business – 2024 Financial highlights – Dividends section, which section is incorporated by reference herein.
TC Energy Annual information form 2024 | 17

Description of capital structure
SHARE CAPITAL
TC Energy’s authorized share capital consists of an unlimited number of common shares and an unlimited number of first preferred shares and second preferred shares, issuable in series. The number of common shares and preferred shares issued and outstanding as at Year End are set out in the MD&A in the Financial Condition – Share information section, which section is incorporated by reference herein. The following is a description of the material characteristics of each of these classes of shares.
Common shares
The common shares entitle the holders thereof to one vote per share at all meetings of shareholders, except meetings at which only holders of another specified class of shares are entitled to vote, and, subject to the rights, privileges, restrictions and conditions attaching to the first preferred shares and the second preferred shares, whether as a class or a series, and to any other class or series of shares of TC Energy which rank prior to the common shares, entitle the holders thereof to receive (i) dividends if, as and when declared by the Board out of the assets of TC Energy properly applicable to the payment of the dividends in such amount and payable at such times and at such place or places as the Board may from time to time determine, and (ii) the remaining property of TC Energy upon a liquidation, dissolution or winding up of the Company.
We have a shareholder rights plan (the Plan) that is designed to protect the rights of our shareholders, ensure they are treated fairly and provide the Board with adequate time to identify, develop and negotiate alternative value maximizing transactions if there is a take-over bid for TC Energy. The Plan creates a right attaching to each common share outstanding and to each common share subsequently issued. Each right becomes exercisable 10 trading days after a person has acquired (an acquiring person), or commences a take-over bid to acquire, 20 per cent or more of the common shares, other than by an acquisition pursuant to a take-over bid permitted under the terms of the Plan (a permitted bid). Prior to a flip-in event (as described below), each right permits registered holders to purchase from the Company common shares of TC Energy at an exercise price equal to three times the market price of such shares, subject to adjustments and anti-dilution provisions (the exercise price). The beneficial acquisition by any person of 20 per cent or more of the common shares, other than by way of a permitted bid, is referred to as a flip-in event. Ten trading days after a flip-in event, each right will permit registered holders other than an acquiring person to receive, upon payment of the exercise price, the number of common shares with an aggregate market price equal to twice the exercise price. The Plan was reconfirmed at the 2022 annual meeting of TC Energy shareholders and must be reconfirmed at every third annual meeting thereafter. Reconfirmation of the Plan will be voted on at the 2025 annual meeting of TC Energy shareholders.
A discussion of our dividend reinvestment and share purchase plan can be found in the MD&A in the About our business - 2024 Financial highlights – Dividends – Dividend reinvestment and share purchase plan and the Financial condition - Dividend reinvestment plan sections, which sections are incorporated by reference herein.
18 | TC Energy Annual information form 2024

First preferred shares
Subject to certain limitations, the Board may, from time to time, issue first preferred shares in one or more series and determine for any such series, its designation, number of shares and respective rights, privileges, restrictions and conditions. The first preferred shares as a class have, among others, the provisions described below.
The first preferred shares of each series rank on a parity with the first preferred shares of every other series, and are entitled to preference over the common shares, the second preferred shares and any other shares ranking junior to the first preferred shares with respect to the payment of dividends, the repayment of capital and the distribution of assets of TC Energy in the event of its liquidation, dissolution or winding up.
Except as provided by the CBCA, the holders of the first preferred shares will not have any voting rights nor will they be entitled to receive notice of or to attend shareholders' meetings. The holders of any particular series of first preferred shares will, if the directors so determine prior to the issuance of such series, be entitled to such voting rights as may be determined by the Board if TC Energy fails to pay dividends on that series of preferred shares for any period as may be so determined by the Board. TC Energy currently does not intend to issue any first preferred shares with voting rights, and any issuances of first preferred shares are expected to be made only in connection with corporate financings.
The provisions attaching to the first preferred shares as a class may be modified, amended or varied only with the approval of the holders of the first preferred shares as a class. Any such approval to be given by the holders of the first preferred shares may be given by the affirmative vote of the holders of not less than 66 2/3 per cent of the first preferred shares represented and voted at a meeting or adjourned meeting of such holders.
The holders of Series 1, 3, 5, 7, 9 and 11 preferred shares will be entitled to receive quarterly fixed rate cumulative preferential cash dividends, as and when declared by the Board, to be reset periodically on prescribed dates to an annualized rate equal to the sum of the then five-year Government of Canada bond yield, calculated at the start of the applicable five-year period, and a spread as set forth in the table below and have the right to convert their shares into cumulative redeemable Series 2, 4, 6, 8, 10 and 12 preferred shares, respectively, subject to certain conditions, on such conversion dates as set forth in the table below. The Series 1, 3, 5, 7, 9 and 11 preferred shares are redeemable by TC Energy in whole or in part on such redemption dates as set forth in the table below, by the payment of an amount in cash for each share to be redeemed equal to $25.00 plus all accrued and unpaid dividends thereon.
The holders of Series 2, 4, 6, 8, 10 and 12 preferred shares will be entitled to receive quarterly floating rate cumulative preferential cash dividends, as and when declared by the Board, at an annualized rate equal to the sum of the then 90-day Government of Canada treasury bill rate, recalculated quarterly, and a spread as set forth in the table below and have the right to convert their shares into Series 1, 3, 5, 7, 9 and 11 preferred shares, respectively, subject to certain conditions, on such conversion dates as set forth in the table below. The Series 2, 4, 6, 8, 10 and 12 preferred shares are redeemable by TC Energy in whole or in part after their respective initial redemption date as set forth in the table below, by the payment of an amount in cash for each share to be redeemed equal to (i) $25.00 in the case of redemptions on such redemption dates as set out in the table below, or (ii) $25.50 in the case of redemptions on any other date, in each case plus all accrued and unpaid dividends thereon.
TC Energy Annual information form 2024 | 19

In the event of liquidation, dissolution or winding up of TC Energy, the holders of Series 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11 and 12 preferred shares shall be entitled to receive $25.00 per preferred share plus all accrued and unpaid dividends thereon in preference over the common shares or any other shares ranking junior to the first preferred shares.
Series of first preferred shares Initial redemption/conversion date Redemption/conversion dates Spread (%)
Series 1 preferred shares December 31, 2014
December 31, 2029 and every fifth year thereafter
 1.92 
Series 2 preferred shares —
December 31, 2029 and every fifth year thereafter
 1.92 
Series 3 preferred shares June 30, 2015 June 30, 2025 and every fifth year thereafter 1.28 
Series 4 preferred shares — June 30, 2025 and every fifth year thereafter 1.28 
Series 5 preferred shares January 30, 2016 January 30, 2026 and every fifth year thereafter 1.54 
Series 6 preferred shares — January 30, 2026 and every fifth year thereafter 1.54 
Series 7 preferred shares April 30, 2019
April 30, 2029 and every fifth year thereafter
 2.38 
Series 8 preferred shares —
April 30, 2029 and every fifth year thereafter
 2.38 
Series 9 preferred shares October 30, 2019
October 30, 2029 and every fifth year thereafter
 2.35 
Series 10 preferred shares —
October 30, 2029 and every fifth year thereafter
 2.35 
Series 11 preferred shares November 30, 2020 November 28, 2025 and every fifth year thereafter 2.96 
Series 12 preferred shares — November 28, 2025 and every fifth year thereafter 2.96 
Except as provided by the CBCA, the respective holders of the first preferred shares of each outstanding series are not entitled to receive notice of, attend at, nor vote at any meeting of shareholders unless and until TC Energy shall have failed to pay eight quarterly dividends on such series of preferred shares, whether or not consecutive, in which case the holders of the first preferred shares of such series shall have the right to receive notice of and to attend each meeting of shareholders at which directors are to be elected and which take place more than 60 days after the date on which the failure first occurs, and to one vote with respect to resolutions to elect directors for each of the first preferred share of such series, until all arrears of dividends have been paid. Subject to the CBCA, the series provisions attaching to the first preferred shares may be amended with the written approval of all the holders of such series of shares outstanding or by at least two thirds of the votes cast at a meeting of the holders of such shares duly called for that purpose and at which a quorum is present.
Second preferred shares
The rights, privileges, restrictions and conditions attaching to the second preferred shares are substantially identical to those attaching to the first preferred shares, except that the second preferred shares rank junior to the first preferred shares with respect to the payment of dividends, repayment of capital and the distribution of assets of TC Energy in the event of a liquidation, dissolution or winding up of TC Energy.


20 | TC Energy Annual information form 2024

Credit ratings
Although TC Energy has not issued debt to the public, it has been assigned credit ratings by Moody's Investors Service, Inc. (Moody's), S&P Global Ratings (S&P) and Fitch Ratings Inc. (Fitch), and its outstanding preferred shares have also been assigned credit ratings by S&P, Fitch and DBRS Limited (DBRS). Moody's has assigned TC Energy an issuer rating of Baa3 with a stable outlook, S&P has assigned an issuer credit rating of BBB+ with a negative outlook, and Fitch has assigned a long-term issuer default rating of BBB+ with a stable outlook. TC Energy does not presently intend to issue debt securities to the public in its own name and any future debt financing requirements are expected to continue to be funded primarily through its subsidiary, TCPL. The following table sets out the current credit ratings assigned to those outstanding classes of securities of the Company, TCPL and TransCanada Trust, a wholly-owned financing trust subsidiary of TCPL, and certain related subsidiaries which have been rated by Moody's, S&P, Fitch and DBRS:
Moody's S&P Fitch DBRS
TCPL - Senior unsecured debt
Baa2
BBB+
 BBB+
BBB (high)
TCPL - Junior subordinated notes
Baa3
BBB-
 Not rated
BBB (low)
TransCanada Trust - Subordinated trust notes
Ba1
BBB-
BBB-
Not rated
TC Energy Corporation - Preferred shares
Not rated
P-2 (Low)
BBB-
Pfd-3 (high)
Commercial paper (TCPL and TCPL guaranteed)
P-2
A-2
F2
R-2 (high)
Rating outlook/status
Stable
Negative
Stable
 Stable
Credit ratings are intended to provide investors with an independent measure of credit quality of an issue of securities. Credit ratings are not recommendations to purchase, hold or sell securities and do not address the market price or suitability of a specific security for a particular investor. There is no assurance that any rating will remain in effect for any given period of time or that any rating will not be revised or withdrawn entirely by a rating agency in the future if, in its judgment, circumstances so warrant.
Each of the Company, TCPL, TransCanada Trust and certain of our other subsidiaries paid fees to each of Moody's, S&P, Fitch and DBRS for the credit ratings rendered in respect of their outstanding classes of securities noted above. In addition to annual monitoring fees for the Company and TCPL and their rated securities, additional payments are made in respect of other services provided in connection with various rating advisory services.
The information concerning our credit ratings relates to our financing costs, liquidity and operations. The availability and cost of our funding options may be affected by certain factors, including the global capital markets environment and outlook as well as our financial performance. Our access to capital markets for required capital at competitive rates is influenced by our credit rating and rating outlook, as determined by credit rating agencies such as Moody's, S&P, Fitch and DBRS. If our ratings were downgraded, TC Energy's financing costs and future debt issuances could be unfavourably impacted. A description of the rating agencies' credit ratings listed in the table above is set out below.
MOODY’S
Moody's has different rating scales for short- and long-term obligations. Numerical modifiers 1, 2 and 3 are appended to each rating classification from Aa through Caa. The modifier 1 indicates that the obligation ranks in the higher end of its generic rating category; the modifier 2 indicates a mid-range ranking; and a modifier 3 indicates a ranking in the lower end of that generic rating category. The Baa2 rating assigned to TCPL's senior unsecured debt and the Baa3 rating assigned to TCPL's junior subordinated notes are in the fourth highest of nine rating categories for long-term obligations. Obligations rated Baa are judged to be medium-grade and are subject to moderate credit risk, and as such, may possess certain speculative characteristics. The Ba1 rating assigned to the TransCanada Trust subordinated trust notes, is in the fifth highest of nine rating categories for long-term obligations. Obligations rated Ba are judged to have speculative elements and are subject to substantial credit risk. The P-2 rating assigned to TCPL's and TCPL guaranteed U.S. commercial paper programs is the second highest of four rating categories for short-term debt issuers. Issuers rated P-2 have a strong ability to repay short-term debt obligations. Outlooks may be assigned at the issuer level or at the rating level. A Moody’s rating outlook is an opinion regarding the likely rating direction over the medium term. A stable outlook indicates a low likelihood of a rating change over the medium term. A negative, positive or developing outlook indicates a higher likelihood of a rating change over the medium term.
TC Energy Annual information form 2024 | 21

S&P
S&P has different rating scales for short- and long-term obligations and Canadian preferred shares. Ratings from AA through CCC may be modified by the addition of a plus (+) or minus (-) sign to show the relative standing within a particular rating category. The BBB+ rating assigned to TCPL's senior unsecured debt is in the fourth highest of 10 rating categories for long-term obligations. A BBB rating indicates the obligor's capacity to meet its financial commitment is adequate; however, adverse economic conditions or changing circumstances are more likely to weaken the obligor's capacity to meet its financial commitments on the obligation. The BBB- ratings assigned to TCPL’s junior subordinated notes and to the TransCanada Trust subordinated trust notes, is in the fourth highest of 10 rating categories for long-term debt obligations and the P-2 (Low) rating assigned to TC Energy’s preferred shares is the second highest of eight rating categories for Canadian preferred shares. The BBB- ratings assigned to TCPL's junior subordinated notes and the TransCanada Trust subordinated trust notes, and the P-2 (Low) rating assigned to TC Energy's preferred shares indicate these obligations exhibit adequate protection parameters. However, adverse economic conditions or changing circumstances are more likely to weaken the obligor’s capacity to meet its financial commitment on the obligation. TCPL's and TCPL guaranteed U.S. commercial paper programs are each rated A-2 which is the second highest of six rating categories for short-term debt issuers. Short-term debt issuers rated A-2 have satisfactory capacity to meet their financial commitments, however they are somewhat more susceptible to adverse effects of changes in circumstances and economic conditions than obligors in the highest rating category. S&P assigns outlooks to issuers and not to individual debt securities. An S&P outlook assesses the potential direction of a long-term credit rating over the intermediate term, which is generally up to two years for investment grade issuers. S&P has assigned a negative outlook to the Company, meaning that a rating may be lowered by S&P.
FITCH
Fitch has different rating scales for short- and long-term obligations. Ratings from AA through CCC may be modified by the addition of a plus (+) or minus (-) sign to show the relative status within a particular rating category. The BBB+ rating assigned to TCPL's senior unsecured debt, and the BBB- ratings assigned to the TransCanada Trust subordinated trust notes and TC Energy's preferred shares are in the fourth highest of 11 rating categories for long-term obligations. A BBB rating indicates that expectations of default risk are currently low and that the capacity for payment of financial commitments is considered adequate, but adverse business or economic conditions are more likely to impair this capacity. The F2 rating assigned to TCPL's and TCPL guaranteed U.S. commercial paper program is the second highest of seven rating categories for short-term debt issuers. Issuers rated F2 have good intrinsic capacity for timely payment of financial commitments. Ratings outlooks by Fitch indicate the direction a rating is likely to move over a one-to-two year period and reflect financial or other trends that have not yet reached or been sustained to the level that would cause a rating action, but which may do so if such trends continue.
22 | TC Energy Annual information form 2024

DBRS
DBRS has different rating scales for short- and long-term obligations and Canadian preferred shares. High or low grades are used to indicate the relative standing within all rating categories other than AAA and D and other than in respect of DBRS’ ratings of commercial paper and short-term debt, which utilize high, middle and low subcategories for its R-1 and R-2 rating categories. In respect of long-term debt and preferred share ratings, the absence of either a high or low designation indicates the rating is in the middle of the category. The BBB (high) rating assigned to TCPL's senior unsecured debt and the BBB (low) rating assigned to TCPL's junior subordinated notes are in the fourth highest of 10 categories for long-term debt and indicate adequate credit quality. The capacity for the payment of financial obligations is considered acceptable. Long-term debt rated BBB may be vulnerable to future events. The Pfd-3 (high) rating assigned to TC Energy's preferred shares is in the third highest of six rating categories for preferred shares. Preferred shares rated Pfd-3 are generally of adequate credit quality. While protection of dividends and principal is still considered acceptable, the issuing entity is more susceptible to adverse changes in financial and economic conditions, and there may be other adverse conditions present which detract from debt protection. Pfd-3 ratings generally correspond with issuers with a BBB category or higher reference point. The R-2 (high) rating assigned to TCPL's Canadian commercial paper program is in the fourth highest of 10 rating categories for short-term debt issuers and indicates the upper end of adequate credit quality. The capacity for payment of short-term financial obligations as they fall due is acceptable. Short-term debt rated R-2 (high) may be vulnerable to future events. Rating trends provide guidance in respect of DBRS' opinion regarding the outlook for a credit rating. The rating trend indicates the direction in which DBRS considers the credit rating may move if present circumstances continue. In cases when a significant event occurs that directly impacts the credit quality of a particular entity or group of entities and there is uncertainty regarding the outcome, and DBRS is unable to provide an objective, forward-looking opinion in a timely fashion, then the credit ratings of the issuer are typically placed “Under Review” with the appropriate Implications designation of Positive, Negative or Developing.
Market for securities
TC Energy's common shares are listed on the TSX and the NYSE under the symbol TRP. The following table sets out our preferred shares listed on the TSX.
Type Issue Date Stock Symbol
Series 1 preferred shares September 30, 2009 TRP.PR.A
Series 2 preferred shares December 31, 2014 TRP.PR.F
Series 3 preferred shares March 11, 2010 TRP.PR.B
Series 4 preferred shares June 30, 2015 TRP.PR.H
Series 5 preferred shares June 29, 2010 TRP.PR.C
Series 6 preferred shares February 1, 2016 TRP.PR.I
Series 7 preferred shares March 4, 2013 TRP.PR.D
Series 9 preferred shares January 20, 2014 TRP.PR.E
Series 10 preferred shares
 October 30, 2024
TRP.PR.L
Series 11 preferred shares March 2, 2015 TRP.PR.G

TC Energy Annual information form 2024 | 23

The following tables set out the reported monthly high, low, and month end closing trading prices and monthly trading volumes of the common shares of TC Energy on the TSX and the NYSE, and the respective Series 1, 2, 3, 4, 5, 6, 7, 9, 10 and 11 preferred shares on the TSX, for the periods indicated:
COMMON SHARES
TSX (TRP) Unadjusted Adjusted1 Volume traded
High
($)		 Low
($)		 Close
($)		 High
($)		 Low
($)		 Close
($)
December 2024
 $69.24 $64.03 $66.99 $69.24 $64.03 $66.99 151,062,244 
November 2024
 $70.32 $64.27 $68.26 $70.32 $64.27 $68.26 55,299,104 
October 2024
 $66.70 $58.61 $64.76 $66.70 $58.41 $64.76 115,600,458 
September 2024
 $64.83 $60.72 $64.29 $59.05 $55.31 $58.56 211,845,569 
August 2024
 $62.54 $58.02 $62.42 $56.97 $52.85 $56.86 62,059,330 
July 2024
 $58.95 $50.59 $58.62 $53.69 $46.08 $53.40 147,184,435 
June 2024
 $55.08 $51.25 $51.86 $50.17 $46.68 $47.24 206,485,429 
May 2024
 $53.64 $48.91 $52.56 $48.86 $44.55 $47.88 71,238,170 
April 2024
 $55.01 $48.12 $49.32 $50.11 $43.83 $44.93 180,758,148 
March 2024
 $55.28 $52.88 $54.44 $50.36 $48.17 $49.59 208,202,477 
February 2024
 $54.20 $50.27 $53.68 $49.37 $45.79 $48.90 52,414,242 
January 2024
 $53.80 $51.62 $53.04 $49.01 $47.02 $48.31 124,330,081 
NYSE (TRP) Unadjusted
Adjusted1
 Volume traded
High
(US$)		 Low
(US$)		 Close
(US$)		 High
(US$)		 Low
(US$)		 Close
(US$)
December 2024
 $49.40 $44.69 $46.53 $49.40 $44.69 $46.53 48,534,667 
November 2024
 $50.37 $46.09 $48.93 $50.37 $46.09 $48.93 41,660,192 
October 2024
 $48.42 $43.39 $46.51 $48.25 $43.24 $46.51 56,811,598 
September 2024
 $48.14 $44.75 $47.55 $43.85 $40.76 $43.31 65,369,870 
August 2024
 $46.40 $41.08 $46.34 $42.27 $37.42 $42.21 47,121,504 
July 2024
 $42.72 $37.07 $42.41 $38.91 $33.77 $38.63 68,942,809 
June 2024
 $40.25 $37.40 $37.90 $36.66 $34.07 $34.52 62,162,596 
May 2024
 $39.31 $35.54 $38.56 $35.81 $32.37 $35.12 57,521,741 
April 2024
 $40.52 $34.95 $35.85 $36.91 $31.84 $32.66 95,447,544 
March 2024
 $41.03 $38.92 $40.20 $37.37 $35.45 $36.62 66,128,989 
February 2024
 $40.13 $37.20 $39.55 $36.55 $33.88 $36.03 46,690,037 
January 2024
 $40.29 $38.28 $39.43 $36.70 $34.87 $35.92 45,267,886 
1 Adjusted to reflect the effect of the Spinoff Transaction.
24 | TC Energy Annual information form 2024

PREFERRED SHARES
Month Series 1 Series 2 Series 3 Series 4 Series 5 Series 6 Series 7 Series 9
Series 10
 Series 11
December 2024
High
 $18.08 $17.88 $14.63 $15.25 $15.08 $15.80 $21.10 $19.44 $22.00 $22.25
Low
 $17.48 $17.37 $13.95 $14.45 $14.10 $15.00 $20.50 $18.81 $19.20 $21.65
Close
 $18.08 $17.60 $14.58 $14.59 $14.84 $15.35 $21.00 $19.25 $21.50 $22.18
Volume Traded 298,299 186,939 93,999 77,330 66,851 33,294 706,434 396 4,319 74,937
November 2024
High
 $18.24 $18.40 $14.28 $15.07 $14.50 $15.34 $21.08 $19.14 $22.00 $22.33
Low
 $16.83 $17.20 $13.20 $14.11 $13.42 $14.53 $19.73 $17.98 $19.00 $20.00
Close
 $18.07 $18.14 $14.28 $15.00 $14.49 $15.20 $20.94 $19.07 $19.48 $22.24
Volume Traded 334,498 241,645 259,932 55,722 109,581 14,774 232,640 236 2,100 203,494
October 2024
High
 $17.35 $17.35 $13.88 $14.40 $14.19 $15.25 $21.35 $19.15 — $20.60
Low
 $16.56 $16.71 $13.25 $13.99 $13.81 $14.71 $20.06 $18.32 — $20.15
Close
 $17.15 $17.28 $13.65 $14.30 $13.95 $15.15 $20.28 $18.56 — $20.31
Volume Traded 205,826 66,030 838,488 50,482 464,985 18,998 478,880 512 — 137,411
September 2024
High
 $17.19 $17.58 $13.75 $14.68 $14.25 $15.65 $21.45 $19.37 — $21.00
Low
 $16.61 $16.60 $13.24 $13.92 $13.73 $14.94 $20.90 $18.45 — $19.55
Close
 $17.08 $17.08 $13.75 $14.25 $13.96 $15.10 $21.30 $19.23 — $20.40
Volume Traded 144,642 64,278 327,111 31,700 213,279 31,448 478,699 222 — 100,321
August 2024
High
 $17.40 $17.68 $13.63 $14.60 $14.22 $15.44 $21.28 $18.97 — $20.42
Low
 $15.37 $16.41 $12.49 $13.34 $13.01 $14.20 $19.17 $17.10 — $18.87
Close
 $16.90 $17.40 $13.55 $14.60 $14.00 $15.28 $21.01 $18.65 — $19.90
Volume Traded 294,224 77,504 260,525 63,763 400,384 31,494 708,917 512 — 164,249
July 2024
High
 $17.01 $17.00 $14.22 $14.43 $13.97 $15.24 $20.05 $18.75 — $23.35
Low
 $15.90 $16.50 $12.45 $13.71 $12.80 $14.51 $19.12 $18.00 — $19.29
Close
 $16.00 $16.80 $13.00 $14.30 $13.74 $14.91 $19.89 $18.00 — $19.41
Volume Traded 275,208 81,212 514,684 53,327 367,654 32,404 405,463 478 — 149,454
June 2024
High
 $16.99 $17.10 $13.42 $14.43 $13.49 $15.45 $19.45 $18.89 — $19.49
Low
 $15.25 $15.99 $12.21 $13.36 $11.88 $14.30 $18.29 $16.90 — $18.02
Close
 $16.36 $16.35 $13.33 $14.00 $13.49 $15.45 $19.45 $18.27 — $19.17
Volume Traded 261,278 77,556 114,858 94,267 102,652 39,229 496,635 342 — 88,422
May 2024
High
 $17.14 $17.45 $13.57 $14.61 $13.45 $15.51 $19.20 $18.99 — $19.59
Low
 $15.96 $16.56 $12.84 $14.10 $13.10 $15.10 $18.45 $17.84 — $19.01
Close
 $16.83 $17.09 $13.39 $14.27 $13.40 $15.48 $19.20 $18.85 — $19.35
Volume Traded 367,696 81,980 264,004 52,056 387,372 26,325 693,249 429 — 221,351
April 2024
High
 $16.26 $16.77 $12.94 $14.21 $13.23 $15.27 $19.33 $17.94 — $19.10
Low
 $15.32 $15.92 $12.46 $13.66 $12.55 $14.65 $18.53 $17.22 — $18.14
Close
 $16.19 $16.75 $12.90 $14.11 $13.13 $15.16 $18.71 $17.91 — $19.10
Volume Traded 323,943 88,528 508,731 30,259 154,509 30,982 1,053,467 798 — 125,063
March 2024
High
 $16.31 $16.10 $12.74 $13.80 $13.13 $15.19 $18.97 $17.80 — $19.00
Low
 $14.95 $15.42 $11.63 $13.41 $12.02 $14.55 $17.72 $16.83 — $17.90
Close
 $15.75 $16.04 $12.69 $13.80 $12.97 $15.15 $18.84 $17.80 — $18.51
Volume Traded 320,385 46,210 338,038 40,987 96,970 18,109 828,341 205 — 243,989
February 2024
High
 $15.79 $16.30 $12.15 $14.21 $12.72 $15.07 $18.41 $17.22 — $18.36
Low
 $15.07 $15.80 $11.71 $13.46 $12.00 $14.52 $17.50 $16.65 — $17.82
Close
 $15.10 $15.80 $11.71 $13.53 $12.08 $14.80 $17.91 $16.83 — $17.82
Volume Traded 160,434 59,968 83,763 54,570 488,822 15,759 377,328 223 — 102,442
January 2024
High
 $15.45 $16.10 $12.10 $14.13 $12.52 $17.50 $17.80 $16.89 — $18.47
Low
 $13.90 $14.79 $11.20 $12.96 $11.36 $13.71 $16.50 $15.24 — $16.10
Close
 $15.23 $15.99 $12.05 $13.90 $12.40 $14.80 $17.70 $16.78 — $18.00
Volume Traded 129,095 98,598 77,582 71,342 202,743 26,791 463,451 2,592 — 132,418
TC Energy Annual information form 2024 | 25

Directors and officers
As of February 13, 2025, the directors and executive officers of TC Energy as a group beneficially owned, or exercised control or direction over, directly or indirectly, an aggregate of 494,825 common shares, constituting 0.05 per cent of the common shares of TC Energy. The Company collects this information from our directors and executive officers but otherwise we have no direct knowledge of individual holdings of TC Energy's securities.
DIRECTORS
The following table sets forth the names of the directors who serve on the Board as of February 13, 2025, together with their jurisdictions of residence, all positions and offices held by them with TC Energy, unless otherwise stated, their principal occupations or employment during the past five years and the year from which each director has continually served as a director of TC Energy. Positions and offices held with TC Energy are also held by such person at TCPL. Each director holds office until the next annual meeting or until his or her successor is earlier elected or appointed.
Name and place of residence
Principal occupation during the five preceding years 
Director since
Scott Bonham
Atherton, California
U.S.A.
 Corporate director. Co-founder of Intentional Capital Real Estate (Canada) (real estate asset management) since October 2014. Advisor to the CEO, Magna International Inc. (Magna) (automotive manufacturing) since May 2021. Director, Loblaw Companies Limited (retail grocery) since October 2016 and The Bank of Nova Scotia (Scotiabank) (chartered bank) since January 2016. Director, Magna from May 2012 to May 2021. 2024
Cheryl F. Campbell
Monument, Colorado
U.S.A.
 Corporate director. Director, Pacific Gas & Electric Corporation (PGE) (utilities) since April 2019, Summit Utilities (Summit) (natural gas distribution) since September 2020 and Board Chair of Summit since January 2024, JANA Corporation (engineering) since January 2020. Director, National Underground Group (infrastructure service provider) from March 2018 to December 2023. 2022
Michael R. Culbert
Calgary, Alberta
Canada
 Corporate director. Director, ARC Resources Ltd. (ARC) (oil and gas, exploration and production) since May 2024 and Humble Midstream II LLC (oil and gas) since December 2023. Director, Precision Drilling Corporation (Precision) (oil and gas services) from December 2017 to June 2024, Komfort IQ Canada (HVAC controls company) from June 2022 to December 2023, Reserve Royalty Income Trust (private oil and gas royalty trust) from May 2017 to June 2021. Director, Enerplus Corporation (Enerplus) (oil and gas, exploration and production) from March 2014 to August 2020. Vice-Chair (Non-Executive) and Director, PETRONAS Canada Ltd. (PETRONAS) (oil and natural gas) from November 2016 to March 2020. 2020
William D. Johnson
Knoxville, Tennessee
U.S.A.
Corporate director. Director, Terrestrial Energy Inc. (nuclear technology) since February 2023, NiSource Inc. (utilities) since March 2022 and BrightNight LLC (renewable integrated power company) since December 2021. President and CEO, PGE (utilities) from May 2019 to June 2020. President and CEO, Tennessee Valley Authority (Tennessee Valley) (electricity) from January 2013 to May 2019.
 2021
Susan C. Jones
Calgary, Alberta
Canada
 Corporate director. Director, Canadian National Railway Limited (freight railway) since May 2022. Director, Piedmont Lithium Inc. (Piedmont) (emerging lithium company) from June 2021 to June 2023. Director, ARC from April 2020 to February 2023. Director, Gibson Energy Inc. (Gibson) (mid-stream oil-focused infrastructure company) from December 2018 to February 2020. Director, Canpotex Limited (Canpotex) (Canadian exporter of potash) from June 2018 to December 2019 (Chair of the Board from June 2019 to December 2019). Executive Vice-President and CEO of the Potash Business Unit, Nutrien Ltd. (Nutrien) (largest global underground soft-rock miner)from June 2018 to September 2019 and Executive Advisor to the CEO from October 2019 to December 2019. 2020
John E. Lowe
Houston, Texas
U.S.A.
Corporate director. Chair of the Board, TC Energy since January 2024. Director, Phillips 66 Company (energy infrastructure) since May 2012. Non-executive Chair of the Board, Apache Corporation (Apache) (oil and gas) from May 2015 to September 2022. Senior Executive Adviser at Tudor, Pickering, Holt & Co. LLC (energy investment and merchant banking) from September 2012 to August 2021.
 2015
26 | TC Energy Annual information form 2024

Name and place of residence
Principal occupation during the five preceding years 
Director since
David MacNaughton
Toronto, Ontario
Canada
President, Palantir Canada (data integration and analytics software) since September 2019. Canada's Ambassador to the United States from March 2016 to August 2019.
 2020
Dawn Madahbee Leach
Little Current, Ontario
Canada
General Manager, Waubetek Business Corporation (Indigenous financial institution) since 1988 and Founder, President and Chief Executive Officer of Indigenous Business International (strategic advisor) since 2016. Director, Niobay Metals Inc. (mining) since 2017, Peace Hills Trust (financial institution) since 2012, English River First Nation’s Des Nedhe Group (Indigenous business investment) since 2024 and Chairperson of The National Indigenous Economic Development Board (federally appointed advisory board) since 2000.
2024
François L. Poirier
Calgary, Alberta
Canada
President and CEO since January 2021. Chief Operating Officer (COO) and President, Power and Storage from September 2020 to December 2020. COO and President, Power and Storage and Mexico from January 2020 to September 2020. Executive Vice-President, Corporate Development and Strategy, and President, Power & Storage and Mexico from May 2019 to January 2020. Executive Vice-President, Corporate Development and Strategy and President, Mexico Natural Gas Pipelines and Energy from January 2019 to May 2019. Director, Canadian Imperial Bank of Commerce (chartered bank) since September 2024.
 2021
Una Power
Vancouver, British Columbia
Canada
Corporate director. Director, Teck Resources Limited (Teck) (diversified mining) since April 2017 and Scotiabank (chartered bank) since April 2016. Director, Kinross Gold Corporation (gold producer) from April 2013 to May 2019.
 2019
Mary Pat Salomone
Naples, Florida
U.S.A.
Corporate director. Director, South Bow Corporation (energy infrastructure) since October 2024. Director, Intertape Polymer Group (manufacturing) from November 2015 to June 2022. Director, Herc Rentals (equipment rental) from July 2016 to December 2021.
 2013
Indira Samarasekera
Vancouver, British Columbia
Canada
Senior Advisor, Bennett Jones LLP (law firm) since September 2015. Director, Intact Financial Corporation (property and casualty insurance) since May 2021 and Magna (automotive manufacturing) since May 2014. Member, selection panel for Canada's outstanding CEO since 2013. Director, Scotiabank (chartered bank) from May 2008 to April 2021 and Stelco Holdings Inc. (manufacturing) from May 2018 to November 2024.
 2016
Siim A. Vanaselja
Toronto, Ontario
Canada
Corporate director. Chair of the Board, TC Energy from May 2017 to December 2023. Director, Power Corporation (financial services) since May 2020, Power Financial Corporation (financial services) since May 2018, RioCan Real Estate Investment Trust (real estate) since May 2017 and Great-West Lifeco Inc. (financial services) since May 2014.
 2014
Thierry Vandal
Mamaroneck, New York
U.S.A.
President, Axium Infrastructure U.S., Inc. (independent infrastructure fund management firm) and Director, Axium Infrastructure Inc. (independent infrastructure fund management firm) since 2015. Director, Royal Bank of Canada (chartered bank) since 2015.
 2017
Dheeraj "D" Verma
Houston, Texas
U.S.A.
 Senior Advisor, Quantum Energy Partners (Quantum) (private equity firm) since November 2021. President, Quantum Energy Partners from November 2016 to November 2021. Director, Jagged Peak Energy Inc. (oil and gas) from January 2017 to January 2020. 2022
Cease Trade Orders, Bankruptcies, Penalties or Sanctions
As of the date hereof, except as indicated below, no other director or executive officer of the Company is or was a director or officer of another company in the past 10 years that:
•was the subject of a cease trade or similar order, or an order denying that company access to any exemption under securities legislation, that was in effect for a period of more than 30 consecutive days
•was involved in an event that resulted in the company being subject to one of the above orders after the director or executive officer no longer held that role with the company, which resulted from an event that occurred while that person was acting in the capacity as director, chief executive officer or chief financial officer
•while acting in that capacity, or within a year of ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold the assets of that company.
TC Energy Annual information form 2024 | 27

In January 2019, PGE filed for bankruptcy under Chapter 11 of the United States Bankruptcy Code as a result of claims arising from fires caused by PGE’s electrical equipment. Following discussions initiated by the PGE board of directors, Mr. Johnson agreed to serve as President and CEO throughout PGE’s bankruptcy process, beginning May 2, 2019, with the understanding that upon PGE’s emergence from bankruptcy he would resign from PGE. On July 1, 2020, PGE emerged from Chapter 11 bankruptcy, upon completing a restructuring process that was confirmed by the United States Bankruptcy Court on June 20, 2020. Mr. Johnson resigned as President and CEO of PGE on June 30, 2020.
Ms. Campbell joined the board of directors of PGE in April 2019, after PGE filed for bankruptcy under Chapter 11 of the United States Bankruptcy Code in January 2019 and prior to its emergence from Chapter 11 bankruptcy in July 2020. Ms. Campbell continues to be a director of PGE.
No director or executive officer of the Company has within the past 10 years:
•become bankrupt
•made a proposal under any legislation relating to bankruptcy or insolvency
•become subject to or launched any proceedings, arrangement or compromise with any creditors, or
•had a receiver, receiver manager or trustee appointed to hold any of their assets.
No director or executive officer of the Company has been subject to:
•any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority, or
•any other penalties or sanctions imposed by a court or regulatory body that would likely be considered important to a reasonable investor in making an investment decision.
BOARD COMMITTEES
TC Energy has four standing committees of the Board: the Audit Committee, the Governance Committee, the Health, Safety, Sustainability and Environment Committee and the Human Resources Committee. As President and CEO of TC Energy, Mr. Poirier is not a member of any Board committees, but is invited to attend committee meetings as required.
The voting members of each of these committees, as of February 13, 2025, are identified below. Information about the Audit Committee can be found in this AIF under the heading Audit Committee.
Director
Audit
Committee
Governance
Committee
Health, Safety, Sustainability and
Environment Committee
Human Resources
Committee
Scott Bonham
 ü ü
Cheryl F. Campbell
 ü ü
Michael R. Culbert ü ü
William D. Johnson ü Chair
Susan C. Jones
 ü ü
John E. Lowe (Chair)
 ü ü
David MacNaughton ü ü
Dawn Madahbee Leach
 ü ü
Una Power Chair ü
Mary Pat Salomone ü Chair
Indira Samarasekera ü ü
Siim A. Vanaselja
 ü ü
Thierry Vandal Chair ü
Dheeraj "D" Verma ü ü
28 | TC Energy Annual information form 2024

OFFICERS
With the exception of Stanley G. Chapman, III, Tina V. Faraca, Patrick C. Muttart, Sean P. O'Donnell and Alisa M. Williams, all of the executive officers and corporate officers of TC Energy reside in Alberta, Canada. Positions and offices held with TC Energy are also held by such person at TCPL. As of the date hereof, the officers of TC Energy, their present positions within TC Energy, unless otherwise stated, and their principal occupations during the five preceding years are as follows:
Executive officers
Name Present position held  Principal occupation during the five preceding years
François L. Poirier
President and Chief Executive Officer
Prior to January 2021, COO and President, Power and Storage. Prior to September 2020, COO and President, Power and Storage and Mexico. Prior to January 2020, Executive Vice-President, Corporate Development and Strategy, and President, Power & Storage and Mexico. Prior to May 2019, Executive Vice-President, Corporate Development and Strategy and President, Mexico Natural Gas Pipelines and Energy.
Stanley G. Chapman, III
Texas, U.S.A.1
Executive Vice-President
Prior to February 2025, Executive Vice-President and Chief Operating Officer, Natural Gas Pipelines. Prior to August 2023, Executive Vice-President, Group Executive, U.S. and Mexico Natural Gas Pipelines. Prior to September 2022, Executive Vice-President and President, U.S. and Mexico Natural Gas Pipelines. Prior to September 2020, Executive Vice-President and President, U.S. Natural Gas Pipelines.
Dawn E. de Lima
Executive Vice-President, Corporate Services
Prior to December 2020, Chief Shared Services Officer, TransAlta Corporation (TransAlta) (electricity service provider). Prior to February 2019, Chief Officer, Business and Operational Services, TransAlta.
Tina V. Faraca
Texas, U.S.A.
 Executive Vice-President and Chief Operating Officer, Natural Gas Pipelines
Prior to February 2025, Executive Vice-President and President, U.S. Natural Gas Pipelines. Prior to August 2023, President, U.S. Natural Gas Pipelines. Prior to September 2022, Senior Vice-President, Operations, Projects and Technical Operational Services. Prior to December 2021, Senior Vice-President, Commercial. Prior to April 2020, Chief Commercial Officer, Enable Midstream (oil and natural gas). Prior to October 2019, Senior Vice-President, Commercial, Enable Midstream.
Gregory D. Grant Executive Vice-President and President, Power and Energy Solutions Prior to February 2025, President, Canadian Natural Gas Pipelines. Prior to January 2022, Senior Vice-President, Commercial. Prior to March 2020, Senior Vice-President, Strategy and Corporate Development.
Patrick M. Keys2
Executive Vice-President and General Counsel
Prior to September 2021, Executive Vice-President, Stakeholder Relations and General Counsel. Prior to May 2019, Senior Vice-President, Legal (Corporate Services Division). Prior to February 2019, Vice-President, Commercial West (Natural Gas Pipelines Division (Canada)).
Patrick C. Muttart
Texas, U.S.A.
Senior Vice-President, External Relations
Prior to December 2022, Senior Vice-President, Stakeholder Relations. Prior to September 2021, Director External Affairs, PMI Global Services (tobacco manufacturing).
Sean P. O'Donnell
Texas, U.S.A.
 Executive Vice-President, Strategy and Corporate Development and Chief Financial Officer Prior to February 2025, Executive Vice-President and Chief Financial Officer. Prior to May 2024, Senior Vice-President, Capital Markets and Corporate Planning. Prior to November 2023, Executive Vice-President and Chief Financial Officer, Mexico Pacific Holdings LLC. Prior to November 2023, Operating Partner, Partner and Managing Director, Quantum Capital Group, LLC (formerly known as Quantum Energy Partners, LLC).
1 Stanley Chapman III announced his retirement from TC Energy, effective in Q2 2025. Mr. Chapman will continue as an executive advisor until Q2 2025. Tina Faraca succeeded Mr. Chapman on February 1, 2025 as Executive Vice-President and Chief Operating Officer, Natural Gas Pipelines.

2 Patrick Keys announced his retirement from TC Energy, anticipated to be at the end of Q1 2025.
TC Energy Annual information form 2024 | 29

Corporate officers
Name
 Present position held  Principal occupation during the five preceding years
Jane M. Brindle
Vice-President, Law and Corporate Secretary
Prior to December 2024, Director, Corporate Secretarial and Finance Law.
Yvonne Frame-Zawalykut
Vice-President, Corporate Controller
Prior to February 2023, Vice-President and Assistant Controller. Prior to November 2022, Director, Corporate Planning. Prior to December 2020, Director, Internal Group Finance.
David R. Marchand
Vice-President, Finance and Treasurer
Prior to December 2024, Vice-President, Finance. Prior to November 2024, Director, Finance. Prior to October 2021, Manager, Finance.
Michele L. Waters
Vice-President, Risk Management
 Prior to November 2024, Director, Risk and Insurance, Cenovus Energy Inc.
Alisa M. Williams
Texas, U.S.A.
 Vice-President, Tax
Prior to August 2023, Director, Income Tax, U.S. and Mexico. Prior to July 2019, Manager, Income Tax, U.S. Reporting.
CONFLICTS OF INTEREST
Directors and officers of TC Energy and its subsidiaries are required to disclose any existing or potential conflicts in accordance with TC Energy's policies governing directors and officers and in accordance with the CBCA.
COBE covers potential conflicts of interest and requires that all employees, officers, directors and contract workers of TC Energy avoid situations that may result in a potential conflict.
In the event an employee, officer, director or contract worker finds themselves in a potential conflict situation, COBE stipulates that:
•the conflict should be reported; and
•the person should refrain from participation in any decision or action where there is a real or perceived conflict.
COBE also notes that employees and officers of TC Energy may not engage in outside business activities that are in conflict with or detrimental to the interests of TC Energy. The CEO and the executive leadership team must receive consent from the Chair of the Governance Committee for all outside business activities.
Under COBE, directors must also declare any material interest that they may have in a material contract or transaction and recuse himself or herself from related deliberations and approvals.
In addition to COBE, the directors and corporate officers of TC Energy are required to disclose any related parties and related party transactions in their annual directors and officers questionnaires. These questionnaires assist TC Energy in identifying and monitoring material related party transactions.
The Governance Committee reviews and approves any material related party transactions prior to the transaction occurring, and maintains oversight over material related party transactions following such approval.
There were no material conflicts of interests or related party transactions reported by the Board, CEO or the corporate officers, including the executive leadership team, in 2024.
30 | TC Energy Annual information form 2024

Serving on other boards
The Board believes that it is important for it to be composed of qualified and knowledgeable directors. As a result, due to the specialized nature of the energy infrastructure business, some of the directors are associated with or sit on the boards of companies that ship natural gas through our pipeline systems. Transmission services on most of TC Energy’s pipeline systems in Canada and the U.S. are subject to regulation and, accordingly, we generally cannot deny transportation services to a creditworthy shipper. The Governance Committee monitors relationships among directors to ensure that business associations do not affect the Board’s performance.
The Board considers whether directors serving on the boards of, or acting as officers or in another similar capacity, for other entities including public and private companies, Crown corporations and other state-owned entities, and non-profit organizations pose any potential conflict. The Board reviews these relationships annually to determine that they do not interfere with any of our director’s ability to act in our best interests. If a director declares a material interest in any material contract or material transaction being considered at a meeting, the director is not present during the discussion and does not vote on the matter.
COBE requires employees to receive consent before accepting a directorship with an entity that is not an affiliate. The CEO and executive vice-presidents must receive the consent of the Chair of the Governance Committee. All other employees must receive the consent of the Corporate Secretary or their delegate.
Affiliates
The Board oversees relationships between TC Energy and any affiliates to avoid any potential conflicts of interest.
Corporate governance
Our Board and management are committed to the highest standards of ethical conduct and corporate governance.
TC Energy is a public company listed on the TSX and the NYSE, and we recognize and respect rules and regulations in both Canada and the U.S.
Our corporate governance practices comply with the Canadian governance guidelines, which include the governance rules of the CBCA, TSX and Canadian Securities Administrators, including:
•National Instrument 52-110, Audit Committees
•National Policy 58-201, Corporate Governance Guidelines, and
•National Instrument 58-101, Disclosure of Corporate Governance Practices.
We also comply with the governance listing standards of the NYSE and the governance rules of the SEC that apply, in each case, to foreign private issuers.
Our governance practices comply with the NYSE standards for U.S. companies in all significant respects. As a non-U.S. company, we are not required to comply with most of the governance listing standards of the NYSE. As a foreign private issuer, however, we must disclose how our governance practices differ from those followed by U.S. companies that are subject to the NYSE standards. Our corporate governance practices do not significantly differ from those required to be followed by U.S. domestic issuers under the NYSE's listing standards. A summary of our governance practices compared to U.S. standards can be found on our website (www.tcenergy.com).
We benchmark our policies and procedures against major North American companies to assess our standards and we adopt best practices as appropriate. Some of our best practices are derived from the NYSE rules and comply with applicable rules adopted by the SEC to meet the requirements of the Sarbanes-Oxley Act of 2002 and the Dodd-Frank Wall Street Reform and Consumer Protection Act.
TC Energy Annual information form 2024 | 31

Audit Committee
The Audit Committee is responsible for assisting the Board in overseeing the integrity of our financial statements and our compliance with legal and regulatory requirements. It is also responsible for overseeing and monitoring the accounting and reporting process and the process, performance and independence of our internal and external auditors. The charter of the Audit Committee can be found in Schedule B of this AIF.
RELEVANT EDUCATION AND EXPERIENCE OF MEMBERS
The members of the Audit Committee as of February 13, 2025 are Una Power (Chair), Scott Bonham, Cheryl F. Campbell, Michael R. Culbert, William D. Johnson, Susan C. Jones and Dawn Madahbee Leach.
The Board believes that the composition of the Audit Committee reflects a high level of financial literacy and expertise. Each member of the Audit Committee has been determined by the Board to be independent and financially literate within the meaning of the definitions under Canadian and U.S. securities laws and the NYSE rules. In addition, the Board has determined that Ms. Power is an Audit Committee Financial Expert as that term is defined under U.S. securities laws. The Board has made this determination based on the education and breadth and depth of experience of each member of the Audit Committee. The following is a description of the education and experience, apart from their respective roles as directors of TC Energy, of each member of the Audit Committee that is relevant to the performance of his or her responsibilities as a member of the Audit Committee.
Una Power (Chair)
Ms. Power earned a Bachelor of Commerce (Honours) degree from Memorial University and holds Chartered Professional Accountant, Chartered Accountant and Chartered Financial Analyst designations. She serves on the board of directors for Teck where she currently serves as audit committee Chair and also serves on the board of directors for Scotiabank, where she previously served as a member and Chair of its audit committee. Ms. Power was previously the Chief Financial Officer of Nexen Energy ULC, a former publicly traded oil and gas company that is now a wholly-owned subsidiary of CNOOC Limited, where she held various executive positions with responsibility for financial and risk management, strategic planning, budgeting, business development, energy marketing and trading, information technology and capital investment.
Scott Bonham
Mr. Bonham holds a Bachelor of Science degree in electrical engineering from Queen’s University and a Master of Business Administration from Harvard Business School. He currently serves on the board of directors for Scotiabank, where he is a member of the Audit and Conduct Review and Corporate Governance Committees, and Loblaw Companies Limited, where he is a member of the Audit Committee and the Risk and Compliance Committee. He has an extensive background in venture capital and from 2000 to 2015, he was co-founder of GGV Capital. He is also the co-founder of Intentional Capital Real Estate (Canada). He previously served as a director of Magna and currently serves in an executive advisory role to the CEO.
Cheryl F. Campbell
Ms. Campbell holds a Master of Science degree in finance, with a minor in management, from the University of Colorado, Denver, as well as Bachelor of Science degrees in chemical engineering and business from the University of Colorado, Boulder. She currently serves on the board of directors of PGE, where she is Chair of the Safety & Nuclear Oversight Committee as well as a member of the Sustainability & Governance Committee. She also serves as the Chair of the board of Summit, as well as serving on the board of JANA Corporation. She previously served as a director and Audit Committee member of National Underground Group and, for 13 years, as Senior Vice President, Gas, with Xcel.
Michael R. Culbert
Mr. Culbert holds a Bachelor of Science degree in Business Administration from Emmanuel College in Boston, Massachusetts. He currently serves on the board of directors of Precision, and is a member of its audit committee. He previously served as a director of Enerplus and Reserve Royalty Income Trust, and as a director and Vice-Chair of PETRONAS, where he also served as a member of each of their audit committees. Mr. Culbert was also a director and President of PNW LNG LP and former co-founder, director, President and CEO of Progress Energy Ltd.
32 | TC Energy Annual information form 2024

William D. Johnson
Mr. Johnson holds a Juris Doctor degree (high honors) from the University of North Carolina School of Law and a Bachelor of Arts degree (history, summa cum laude) from Duke University in North Carolina. He recently served as President and CEO of PGE. Mr. Johnson also served as President and CEO of Tennessee Valley, as well as serving as Chairman, President and CEO of Progress Energy, Inc.
Susan C. Jones
Ms. Jones earned a Bachelor of Arts degree in Political Science and Hispanic Studies from the University of Victoria. She also holds a Bachelor of Laws degree from the University of Ottawa. She earned a Leadership Diploma from the University of Oxford and holds a Director Certificate from Harvard University. Ms. Jones serves as a director of Canadian National Railway Company and is a member of its audit committee and Chair of its Safety & Environment committee. Ms. Jones previously served as a director of ARC and was a member of the audit and finance committee of Seven Generations Energy Ltd. prior to its merger with ARC. She also served as a director of Piedmont. She previously served on the boards and as a member of the audit committees of Gibson and Canpotex, where she also served as Chair of the board. Ms. Jones held an executive leadership role at Nutrien for 15 years, most recently as Executive Vice-President and CEO of the Potash Business Unit.
Dawn Madahbee Leach
Ms. Madahbee Leach graduated from the University of Waterloo’s Economic Development Program and holds a degree in Political Science and Law from York and Laurentian Universities. She is the General Manager for the Waubetek Business Development Corporation since she helped create and start the organization in 1988. Waubetek is a leading Indigenous Financial Institution that provides financial services to Indigenous entrepreneurs across Canada. She is also the founder, President and Chief Executive Officer of Indigenous Business International, which assists Indigenous people and companies internationally with various economic sector strategies and project reviews. She is the Chair of the National Indigenous Economic Development Board and has been part of this federally appointed board since 2000, providing advice and guidance to the federal government on issues related to Indigenous economic policies and programming. She also serves on the board of Peace Hills Trust where she is a member of the Executive, Loans and Trust Committees and is Chair of the Investment Committee. She is also a board member of Niobay Metals Inc. since 2017.
PRE-APPROVAL POLICIES AND PROCEDURES
TC Energy's Audit Committee maintains a pre-approval policy with respect to permitted non-audit services and audit services. For non-audit service engagements of up to $250,000, approval of the Audit Committee Chair is required, and the Audit Committee is to be informed of the engagement at the next scheduled Audit Committee meeting. For all non-audit service engagements of $250,000 or more, pre-approval of the Audit Committee is required.
To date, all non-audit services have been pre-approved by the Audit Committee in accordance with the pre-approval policy described above.
TC Energy Annual information form 2024 | 33

EXTERNAL AUDITOR SERVICE FEES
The table below shows the services KPMG LLP provided during the last two fiscal years and the fees they invoiced us:
($ millions)
2024
2023
Audit fees
19.4
18.5
•audit of the annual consolidated financial statements
•services related to statutory and regulatory filings or engagements
•review of interim consolidated financial statements and information contained in various prospectuses and other securities offering documents
Audit-related fees
1.4
0.9
•services related to the audit of the financial statements of TC Energy pipeline abandonment trusts, certain post-retirement plans, and certain special purpose audits
Tax fees
1.5
1.5
•Canadian and international tax planning and tax compliance matters, including the review of income tax returns and other tax filings
All other fees
0.5
0.2
•fees for other products and services provided by the auditors not described above, which included fees related to advice and assistance with ESG services, and French and Spanish translation services
Total fees
22.8
21.1
Note
•2024 total fees are higher than 2023 due to increased audit work related to the Spinoff Transaction, including additional financial statements required in connection with debt financings of certain Liquid's subsidiaries and additional securities work.

34 | TC Energy Annual information form 2024

Legal proceedings and regulatory actions
Except as described below, there are no legal proceedings in respect of which the Company is or was a party, or in respect of which any of the Company’s property is or was the subject during the year ended December 31, 2024, nor are there any such proceedings known by the Company to be contemplated, that involve a claim for damages exceeding 10% of the Company’s current assets. In addition, there have not been any (a) penalties or sanctions imposed against the Company by a court relating to securities legislation or by a securities regulatory authority during the year ended December 31, 2024, (b) any other penalties or sanctions imposed by a court or regulatory body against the Company that would likely be considered important to a reasonable investor in making an investment decision, or (c) settlement agreements entered into by the Company before a court relating to securities legislation or with a securities regulatory authority during the year ended December 31, 2024.
SA Energy Group
CGL LP and SA Energy Group (SAEG), one of the prime construction contractors on the Coastal GasLink pipeline, reached a mutually acceptable resolution to their disputes in the second quarter of 2024. The settlement was not an admission of liability by either party and the parties mutually released their respective claims in arbitration. Details of the arbitration and the settlement are confidential.
Pacific Atlantic Pipeline Construction Ltd.
CGL LP is in arbitration with one of its previous prime contractors, Pacific Atlantic Pipeline Construction Ltd. (PAPC). CGL LP terminated its contract with PAPC for cause, due to the failure of PAPC to complete work as scheduled and made a demand on the parental guarantee for payment of the guaranteed obligations. Following CGL LP’s demand on the guarantee, in August 2022, PAPC initiated arbitration. As of December 31, 2024, PAPC purports to seek at least $460 million in damages for wrongful termination for cause, termination damages and payments alleged to be outstanding. CGL LP disputes the merits of PAPC’s claims and has counterclaimed against PAPC and its parent company and guarantor, Bonatti S.p.A., citing delays and failures by PAPC to perform and manage work in accordance with the terms of its contract. CGL LP estimates its damages to be $1.3 billion. PAPC and Bonatti S.p.A. dispute CGL LP's claims and assert that CGL LP's damages, if any, are subject to a contractual limit of approximately $220 million. The arbitration hearing previously scheduled to commence in November of 2024 has now been rescheduled to the third quarter of 2025. At December 31, 2024, the final outcome of this matter cannot be reasonably estimated.
Separately, CGL LP drew on a $117 million irrevocable standby letter of credit (LOC) provided by PAPC based on a bona fide belief that CGL LP's damages are in excess of the face value of the LOC. On October 17, 2023 PAPC applied for an injunction in the Court of King’s Bench of Alberta restraining CGL LP from drawing on the LOC pending the completion of the arbitration between CGL LP, PAPC and Bonatti S.p.A., but was ultimately unsuccessful following the pursuit of the injunction up to the Supreme Court of Canada. CGL LP is now able to use the recovered LOC funds. PAPC and Bonatti S.p.A. have amended their original claims to seek additional damages in relation to the draw on the LOC. The amount claimed has not been articulated beyond the $117 million. The parties have agreed that the issue of damages arising from CGL LP's draw on the LOC will be determined, if necessary, at a date subsequent to the arbitration hearing noted above.

TC Energy Annual information form 2024 | 35

Transfer agent and registrar
TC Energy's transfer agent and registrar is Computershare Investor Services, Inc. with its Canadian transfer facilities in the cities of Calgary, Montréal, Toronto and Vancouver.
Material contracts
TC Energy did not enter into any material contracts outside the ordinary course of business during the year ended December 31, 2024, nor has it entered into any material contracts outside the ordinary course of business prior to the year ended December 31, 2024 which are still in effect as at the date of this AIF.
Interest of experts
KPMG LLP are the auditors of TC Energy and have confirmed with respect to TC Energy that they are independent within the meaning of the relevant rules and related interpretations prescribed by the relevant professional bodies in Canada and any applicable legislation or regulations and also that they are independent accountants with respect to TC Energy under all relevant U.S. professional and regulatory standards.
Additional information
1.Additional information in relation to TC Energy may be found under TC Energy's profile on SEDAR+ (www.sedarplus.ca).
2.Additional information including directors' and officers' remuneration and indebtedness, principal holders of TC Energy's securities and securities authorized for issuance under equity compensation plans (all where applicable), is contained in TC Energy's Management Information Circular for its most recent annual meeting of shareholders that involved the election of directors and can be obtained upon request from the Corporate Secretary of TC Energy.
3.Additional financial information is provided in TC Energy's audited consolidated financial statements and MD&A for its most recently completed financial year.
36 | TC Energy Annual information form 2024

Glossary
Capitalized terms used throughout this AIF but not otherwise defined herein have the meanings given to such terms in the MD&A and are incorporated by reference into this AIF.
Units of measure
Bcf Billion cubic feet
hp
Horsepower
km Kilometres
MMcf/d Million cubic feet per day
MW Megawatt(s)
MWh Megawatt hours
TJ/d Terajoules per day
General terms and terms related to our operations
B.C. British Columbia
DRP Dividend Reinvestment and Share Purchase Plan
ESG Environmental, social and governance
force majeure Unforeseeable circumstances that prevent a party to a contract from fulfilling it
GHG Greenhouse gas
investment base Includes rate base as well as assets under construction
LNG Liquefied natural gas
MCR
Major component replacement
rate base Average assets in service, working capital and deferred amounts used in setting of regulated rates
WCSB Western Canada Sedimentary Basin
Year End
Year ended December 31, 2024
Accounting terms
GAAP U.S. generally accepted accounting principles
ROE Return on common equity
Government and regulatory bodies terms
AER Alberta Energy Regulator
BCEAO
Environmental Assessment Office (British Columbia)
BCER B.C. Energy Regulator (formerly B.C. Oil and Gas Commission)
CBCA Canada Business Corporations Act
CER Canada Energy Regulator (formerly the National Energy Board (Canada))
CFE Comisión Federal de Electricidad (Mexico)
CRE
Comisión Reguladora de Energía, or Energy Regulatory Commission (Mexico)
DOS U.S. Department of State
FERC Federal Energy Regulatory Commission (U.S.)
IESO
Independent Electricity System Operator (Ontario)
NYSE New York Stock Exchange
PHMSA Pipeline and Hazardous Materials Safety and Administration
SEC U.S. Securities and Exchange Commission
TSX Toronto Stock Exchange

TC Energy Annual information form 2024 | 37

Schedule A
METRIC CONVERSION TABLE
The conversion factors set out below are approximate factors. To convert from Metric to Imperial multiply by the factor indicated. To convert from Imperial to Metric divide by the factor indicated.
Metric Imperial Factor
Kilometres
Miles
 0.62
Millimetres
Inches
 0.04
Gigajoules
Million British thermal units
 0.95
Cubic metres*
Cubic feet
 35.3
Kilopascals
Pounds per square inch
 0.15
Degrees Celsius
Degrees Fahrenheit
to convert to Fahrenheit multiply by 1.8, then add 32 degrees; to convert to Celsius subtract 32 degrees, then divide by 1.8
*The conversion is based on natural gas at a base pressure of 101.325 kilopascals and at a base temperature of 15 degrees Celsius.
38 | TC Energy Annual information form 2024

Schedule B
CHARTER OF THE AUDIT COMMITTEE
1.    PURPOSE
The Audit Committee shall assist the Board of Directors (the Board) in overseeing and monitoring, among other things, the:
•Company’s financial accounting and reporting process;
•integrity of the financial statements;
•Company’s internal control over financial reporting;
•external financial audit process;
•compliance by the Company with legal and regulatory requirements; and
•independence and performance of the Company’s internal and external auditor.
To fulfill its purpose, the Audit Committee has been delegated certain authorities by the Board that it may exercise on behalf of the Board.
2.    ROLES AND RESPONSIBILITIES
I.    Appointment of the Company’s External Auditor
Subject to confirmation by the external auditor of their compliance with Canadian and U.S. regulatory registration requirements, the Audit Committee shall recommend to the Board the appointment of the external auditor, such appointment to be confirmed by the Company’s shareholders at each annual meeting. The Audit Committee shall also recommend to the Board the compensation to be paid to the external auditor for audit services. The Audit Committee shall also be directly responsible for the oversight of the work of the external auditor (including resolution of disagreements between management and the external auditor regarding financial reporting) for the purpose of preparing or issuing an audit report or related work. The external auditor shall report directly to the Audit Committee.
The Audit Committee shall review and approve the audit plan of the external auditor. The Audit Committee shall also receive periodic reports from the external auditor regarding the auditor’s independence, discuss such reports with the auditor, consider whether the provision of non‑audit services is compatible with maintaining the auditor’s independence and take appropriate action to satisfy itself of the independence of the external auditor. In addition, to further satisfy itself of audit quality and the independence of the external auditor, the Audit Committee shall undertake a Periodic Comprehensive Review of the External Auditor at least once every five years.
II.    Oversight in Respect of Financial Disclosure
The Audit Committee shall, to the extent it deems it necessary or appropriate:
(a)    review, discuss with management and the external auditor and recommend to the Board for approval, the Company’s audited annual consolidated financial statements, annual information form, management’s discussion and analysis (MD&A), all financial information in prospectuses and other offering memoranda, financial statements required by securities regulators, all prospectuses and all documents which may be incorporated by reference into a prospectus, including, without limitation, the annual management information circular, but excluding any pricing or prospectus supplement relating to the issuance of debt securities of the Company;
(b)    review, discuss with management and the external auditor and approve, the release to the public of the Company’s interim reports, including the consolidated financial statements, MD&A and news releases on quarterly financial results;
(c)    review and discuss with management and the external auditor the use of non-GAAP information and the applicable reconciliation;
TC Energy Annual information form 2024 | 39

(d)    review and discuss with management any financial outlook or future-oriented financial information disclosure in advance of its public release; provided, however, that such discussion may be done generally (consisting of discussing the types of information to be disclosed and the types of presentations to be made). The Audit Committee need not discuss in advance each instance in which the Company may provide financial projections or presentations to credit rating agencies;
(e)    review with management and the external auditor major issues regarding accounting policies and auditing practices, including any significant changes in the Company’s selection or application of accounting policies, as well as major issues as to the adequacy of the Company’s internal controls and any special audit steps adopted in light of material control deficiencies that could significantly affect the Company’s financial statements;
(f)    review and discuss quarterly findings reports from the external auditor on:
(i)    all critical accounting policies and practices to be used;
(ii)    all alternative treatments of financial information within generally accepted accounting principles that have been discussed with management, ramifications of the use of such alternative disclosures and treatments, and the treatment preferred by the external auditor;
(iii)    other material written communications between the external auditor and management, such as any management letter or schedule of unadjusted differences;
(g)    review with management and the external auditor the effect of regulatory and accounting developments on the Company’s financial statements;
(h)    review with management and the external auditor the effect of any off-balance sheet structures on the Company’s financial statements;
(i)    review with management, the external auditor and, if necessary, legal counsel, any litigation, claim or contingency, including arbitration and tax assessments, that could have a material effect upon the financial position of the Company, and the manner in which these matters have been disclosed in the financial statements;
(j)    review disclosures made to the Audit Committee by the Company’s Chief Executive Officer (CEO) and Chief Financial Officer (CFO) during their certification process for the periodic reports filed with securities regulators about any significant deficiencies in the design or operation of internal controls or material weaknesses therein and any fraud involving management or other employees who have a significant role in the Company’s internal controls;
(k)    discuss with management the Company’s material financial risk exposures and the steps management has taken to monitor and control such exposures, including the Company’s risk assessment and risk management policies;
III.    Oversight in Respect of Legal and Regulatory Matters
(a)    review with the Company’s General Counsel legal matters that may have a material impact on the financial statements, the Company’s compliance policies and any material reports or inquiries received from regulators or governmental agencies;
IV.    Oversight in Respect of Internal Audit
(a)    review and approve the audit plans of the internal auditor of the Company including the degree of coordination between such plans and those of the external auditor and the extent to which the planned audit scope can be relied upon to detect weaknesses in internal control, fraud or other illegal acts;
(b)    review the significant findings prepared by the internal audit department and recommendations issued by it or by any external party relating to internal audit issues, together with management’s response thereto;
(c)    review compliance with the Company’s policies and avoidance of conflicts of interest;
(d)    review the report prepared by the internal auditor on officers’ expenses and aircraft usage;
40 | TC Energy Annual information form 2024

(e)    review the adequacy of the resources of the internal auditor to ensure the objectivity and independence of the internal audit function, including reports from the internal audit department on its audit process with subsidiaries and affiliates;
(f)    ensure the internal auditor has access to the Chair of the Audit Committee, the Board and the CEO and meet separately with the internal auditor to review with him or her any problems or difficulties he or she may have encountered and specifically:
(i)    any difficulties which were encountered in the course of the audit work, including restrictions on the scope of activities or access to required information, and any disagreements with management;
(ii)    any changes required in the planned scope of the internal audit;
(iii)    the internal audit department responsibilities, budget and staffing;
and to report to the Board on such meetings;
V.    Oversight in Respect of the External Auditor
(a)    review any letter, report or other communication from the external auditor in respect of any identified weakness in internal control or unadjusted difference and management’s response and follow‑up, inquire regularly of management and the external auditor of any significant issues between them and how they have been resolved, and intervene in the resolution if required;
(b)    receive and review annually the external auditor’s formal written statement of independence delineating all relationships between itself and the Company;
(c)    meet separately with the external auditor to review any problems or difficulties the external auditor may have encountered and specifically:
(i)    any difficulties which were encountered in the course of the audit work, including any restrictions on the scope of activities or access to required information, and any disagreements with management;
(ii)    any changes required in the planned scope of the audit;
and to report to the Board on such meetings;
(d)    meet with the external auditor prior to the audit to review the planning and staffing of the audit;
(e)    receive and review annually the external auditor's written report on their own internal quality control procedures; any material issues raised by the most recent internal quality control review, or peer review, of the external auditor, or by any inquiry or investigation by governmental or professional authorities, within the preceding five years, and any steps taken to deal with such issues;
(f)    review and evaluate the external auditor, including the lead partner of the external auditor team;
(g)    ensure the rotation of the lead (or coordinating) audit partner having primary responsibility for the audit and the audit partner responsible for reviewing the audit as required by law, but at least every five years;
VI.    Oversight in Respect of Audit and Non‑Audit Services
(a)    pre-approve all audit services (which may entail providing comfort letters in connection with securities underwritings) and all permitted non‑audit services, other than non‑audit services where:
(i)    the aggregate amount of all such non‑audit services provided to the Company that were not pre-approved constitutes not more than five percent of the total fees paid by the Company and its subsidiaries to the external auditor during the fiscal year in which the non‑audit services are provided;
(ii)    such services were not recognized by the Company at the time of the engagement to be non‑audit services;
TC Energy Annual information form 2024 | 41

(iii)    such services are promptly brought to the attention of the Audit Committee and approved, prior to the completion of the audit, by the Audit Committee or by one or more members of the Audit Committee to whom authority to grant such approvals has been delegated by the Audit Committee;
(b)    approval by the Audit Committee of a non‑audit service to be performed by the external auditor shall be disclosed as required under securities laws and regulations;
(c)    the Audit Committee may delegate to one or more designated members of the Audit Committee the authority to grant pre-approvals required by this subsection. The decisions of any member to whom authority is delegated to pre-approve an activity shall be presented to the Audit Committee at its first scheduled meeting following such pre-approval;
(d)    if the Audit Committee approves an audit service within the scope of the engagement of the external auditor, such audit service shall be deemed to have been pre-approved for purposes of this subsection;
VII.    Oversight in Respect of Certain Policies
(a)    review and recommend to the Board for approval the implementation of, and significant amendments to, policies and program initiatives deemed advisable by management or the Audit Committee with respect to the Company’s code of business ethics (COBE), risk management and financial reporting policies;
(b)    obtain reports from management, the Company’s senior internal auditing executive and the external auditor and report to the Board on the status and adequacy of the Company’s efforts to ensure its businesses are conducted and its facilities are operated in an ethical, legally compliant and socially responsible manner, in accordance with the Company’s COBE;
(c)    establish a non‑traceable, confidential and anonymous system by which callers may ask for advice or report any ethical or financial concern, ensure that procedures for the receipt, retention and treatment of complaints in respect of accounting, internal controls and auditing matters are in place, and receive reports on such matters as necessary;
(d)    annually review and assess the adequacy of the Company’s public disclosure policy;
(e)    review and approve the Company’s hiring policy for partners, employees and former partners and employees of the present and former external auditor (recognizing the Sarbanes-Oxley Act of 2002 does not permit the CEO, controller, CFO or chief accounting officer to have participated in the Company’s audit as an employee of the external auditor during the preceding one-year period) and monitor the Company’s adherence to the policy;
VIII.    Oversight in Respect of Financial Aspects of the Company’s Canadian Pension Plans (the Company’s pension plans), specifically:
(a)review and approve annually the Statement of Investment Beliefs for the Company’s pension plans;
(b)delegate the ongoing administration and management of the financial aspects of the Canadian pension plans to the Pension Committee comprised of members of the Company’s management team appointed by the Human Resources Committee, in accordance with the Pension Committee Charter, which terms shall be approved by both the Audit Committee and the Human Resources Committee, and the terms of the Statement of Investment Beliefs;
(c)monitor the financial management activities of the Pension Committee and receive updates at least annually from the Pension Committee on the investment of the Plan assets to ensure compliance with the Statement of Investment Beliefs;
(d)    provide advice to the Human Resources Committee on any proposed changes in the Company’s pension plans in respect of any significant effect such changes may have on pension financial matters;
(e)    review and consider financial and investment reports and the funded status relating to the Company’s pension plans and recommend to the Board on pension contributions;
42 | TC Energy Annual information form 2024

(f)    receive, review and report to the Board on the actuarial valuation and funding requirements for the Company’s pension plans;
(g)    approve the initial selection or change of actuary for the Company’s pension plans;
(h)    approve the appointment or termination of the pension plans’ auditor;
IX.    U.S. Stock Plans
(a)    review and approve the engagement and related fees of the auditor for any plan of a U.S. subsidiary that offers Company stock to employees as an investment option under the plan;
X.    Oversight in Respect of Internal Administration
(a)    review annually the reports of the Company’s representatives on certain audit committees of subsidiaries and affiliates of the Company and any significant issues and auditor recommendations concerning such subsidiaries and affiliates;
(b)    oversee succession planning for the senior management in finance, treasury, tax, risk, internal audit and the controllers’ group;
XI.    Information Security
(a)review quarterly, the report of the Chief Information Officer (or such other appropriate Company representative) on information security controls, education and awareness.
XII.    Oversight Function
While the Audit Committee has the responsibilities and powers set forth in this Charter, it is not the duty of the Audit Committee to plan or conduct audits or to determine that the Company’s financial statements and disclosures are complete and accurate or are in accordance with generally accepted accounting principles and applicable rules and regulations. These are the responsibilities of management and the external auditor. The Audit Committee, its Chair and any of its members who have accounting or related financial management experience or expertise, are members of the Board, appointed to the Audit Committee to provide broad oversight of the financial disclosure, financial risk and control related activities of the Company, and are specifically not accountable nor responsible for the day to day operation of such activities. Although designation of a member or members as an “audit committee financial expert” is based on that individual’s education and experience, which that individual will bring to bear in carrying out his or her duties on the Audit Committee, designation as an “audit committee financial expert” does not impose on such person any duties, obligations or liability that are greater than the duties, obligations and liability imposed on such person as a member of the Audit Committee and Board in the absence of such designation. Rather, the role of any audit committee financial expert, like the role of all Audit Committee members, is to oversee the process and not to certify or guarantee the internal or external audit of the Company’s financial information or public disclosure.
3.    COMPOSITION OF AUDIT COMMITTEE
The Audit Committee shall consist of three or more directors, a majority of whom are resident Canadians (as defined in the Canada Business Corporations Act), and all of whom are unrelated and/or independent for the purposes of applicable Canadian and United States securities law and applicable rules of any stock exchange on which the Company's securities are listed. Each member of the Audit Committee shall be financially literate and at least one member shall have accounting or related financial management expertise (as those terms are defined from time to time under the requirements or guidelines for audit committee service under securities laws and the applicable rules of any stock exchange on which the Company’s securities are listed for trading or, if it is not so defined, as that term is interpreted by the Board in its business judgment).
4.    APPOINTMENT OF AUDIT COMMITTEE MEMBERS
The members of the Audit Committee shall be appointed by the Board from time to time on the recommendation of the Governance Committee and shall hold office until the next annual meeting of shareholders or until their successors are earlier appointed or until they cease to be directors of the Company.
TC Energy Annual information form 2024 | 43

5.    VACANCIES
Where a vacancy occurs at any time in the membership of the Audit Committee, it may be filled by the Board on the recommendation of the Governance Committee.
6.    AUDIT COMMITTEE CHAIR
The Board shall appoint a Chair of the Audit Committee who shall:
(a)    review and approve the agenda for each meeting of the Audit Committee and, as appropriate, consult with members of management;
(b)    preside over meetings of the Audit Committee;
(c)    make suggestions and provide feedback from the Audit Committee to management regarding information that is or should be provided to the Audit Committee;
(d)    report to the Board on the activities of the Audit Committee relative to its recommendations, resolutions, actions and concerns; and
(e)    meet as necessary with the internal and external auditor.
7.    ABSENCE OF AUDIT COMMITTEE CHAIR
If the Chair of the Audit Committee is not present at any meeting of the Audit Committee, one of the other members of the Audit Committee present at the meeting shall be chosen by the Audit Committee to preside at the meeting.
8.    SECRETARY OF AUDIT COMMITTEE
The Corporate Secretary shall act as Secretary to the Audit Committee.
9.    MEETINGS
The Chair, or any two members of the Audit Committee, or the internal auditor, or the external auditor, may call a meeting of the Audit Committee. The Audit Committee shall meet at least quarterly. The Audit Committee shall meet periodically with management, the internal auditor and the external auditor in separate executive sessions.
10.    QUORUM
A majority of the members of the Audit Committee, present in person or by telephone or other telecommunication device that permit all persons participating in the meeting to speak to each other, shall constitute a quorum.
11.    NOTICE OF MEETINGS
Notice of the time and place of every meeting shall be given in writing, facsimile communication or by other electronic means to each member of the Audit Committee at least 24 hours prior to the time fixed for such meeting; provided, however, that a member may in any manner waive a notice of a meeting. Attendance of a member at a meeting is a waiver of notice of the meeting, except where a member attends a meeting for the express purpose of objecting to the transaction of any business on the grounds that the meeting is not lawfully called.
12.    ATTENDANCE OF COMPANY OFFICERS AND EMPLOYERS AT MEETING
At the invitation of the Chair of the Audit Committee, one or more officers or employees of the Company may attend any meeting of the Audit Committee.
13.    PROCEDURE, RECORDS AND REPORTING
The Audit Committee shall fix its own procedure at meetings, keep records of its proceedings and report to the Board when the Audit Committee may deem appropriate but not later than the next meeting of the Board.
14.    REVIEW OF CHARTER AND EVALUATION OF AUDIT COMMITTEE
The Audit Committee shall review its Charter annually or otherwise, as it deems appropriate and, if necessary, propose changes to the Governance Committee and the Board. The Audit Committee shall annually review the Audit Committee’s own performance.
44 | TC Energy Annual information form 2024

15.    OUTSIDE EXPERTS AND ADVISORS
The Audit Committee is authorized, when deemed necessary or desirable, to retain and set and pay the compensation for independent counsel, outside experts and other advisors, at the Company’s expense, to advise the Audit Committee or its members independently on any matter.
16.    RELIANCE
Absent actual knowledge to the contrary (which shall be promptly reported to the Board), each member of the Audit Committee shall be entitled to rely on (i) the integrity of those persons or organizations within and outside the Company from which it receives information, (ii) the accuracy of the financial and other information provided to the Audit Committee by such persons or organizations and (iii) representations made by management and the external auditor, as to any information technology, internal audit and other non-audit services provided by the external auditor to the Company and its subsidiaries.
TC Energy Annual information form 2024 | 45
EX-13.2 3 trp-12312024xmda.htm MANAGEMENT'S DISCUSSION AND ANALYSIS Document
EXHIBIT 13.2
Management's discussion and analysis
February 13, 2025
This management's discussion and analysis (MD&A) contains information to help the reader make investment decisions about TC Energy Corporation (TC Energy). It discusses our business, operations, financial position, risks and other factors for the year ended December 31, 2024.
This MD&A should also be read in conjunction with our December 31, 2024 audited Consolidated financial statements and notes for the same period, which have been prepared in accordance with U.S. GAAP.
Contents
ABOUT THIS DOCUMENT
ABOUT OUR BUSINESS
 
•  Our core businesses
  •  Our strategy
•  2024 Financial highlights
•Non-GAAP measures
•Supplementary financial measure
•  Outlook
•  Capital program
NATURAL GAS PIPELINES BUSINESS
CANADIAN NATURAL GAS PIPELINES
U.S. NATURAL GAS PIPELINES
MEXICO NATURAL GAS PIPELINES
POWER AND ENERGY SOLUTIONS
CORPORATE
FOREIGN EXCHANGE
FINANCIAL CONDITION
DISCONTINUED OPERATIONS
•  Non-GAAP measures
OTHER INFORMATION
 
•  Risk oversight and enterprise risk management
  •  Controls and procedures
  •  Critical accounting estimates
  •  Financial instruments
•  Related party transactions
  •  Accounting changes
  •  Quarterly results
GLOSSARY

TC Energy Management's discussion and analysis 2024 | 9
About this document
Throughout this MD&A, the terms we, us, our and TC Energy mean TC Energy Corporation and its subsidiaries. Abbreviations and acronyms that are not defined in the document are defined in the glossary on page 138. All information is as of February 13, 2025 and all amounts are in Canadian dollars, unless noted otherwise.
On July 27, 2023, TC Energy announced plans to separate into two independent, investment-grade, publicly listed companies through the spinoff of its Liquids Pipelines business. TC Energy shareholders voted to approve the spinoff in June 2024 and, on October 1, 2024, TC Energy completed the spinoff of its Liquids Pipelines business into a new public company, South Bow Corporation (South Bow)(the Spinoff Transaction). Upon completion of the Spinoff Transaction, the Liquids Pipelines business was accounted for as a discontinued operation. To allow for a meaningful comparison, discussions throughout this MD&A are based on continuing operations unless otherwise noted. Prior year results have been recast to reflect the split between continuing and discontinued operations. Discontinued operations reflect nine months of Liquids Pipelines earnings for the year ended December 31, 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to Note 4, Discontinued operations, of our 2024 Consolidated financial statements for additional information.
FORWARD-LOOKING INFORMATION
We disclose forward-looking information to help the reader understand management's assessment of our future plans and financial outlook and our future prospects overall.
Statements that are forward looking are based on certain assumptions and on what we know and expect today and generally include words like anticipate, expect, believe, may, will, should, estimate or other similar words.
Forward-looking statements in this MD&A include information about the following, among other things:
•our financial and operational performance, including the performance of our subsidiaries
•expectations about strategies and goals for growth and expansion, including acquisitions
•expected cash flows and future financing options available along with portfolio management
•expectations regarding the size, structure, timing, conditions and outcome of ongoing and future transactions
•expected dividend growth
•expected access to and cost of capital
•expected energy demand levels
•expected costs and schedules for planned projects, including projects under construction and in development
•expected capital expenditures, contractual obligations, commitments and contingent liabilities, including environmental remediation costs
•expected regulatory processes and outcomes
•expected outcomes with respect to legal proceedings, including arbitration and insurance claims
•expected impact of future tax and accounting changes
•commitments and targets contained in our Report on Sustainability and GHG Emissions Reduction Plan, including statements related to our GHG emissions intensity reduction goals
•expected industry, market and economic conditions, and ongoing trade negotiations, including their impact on our customers and suppliers.
Forward-looking statements do not guarantee future performance. Actual events and results could be significantly different because of assumptions, risks or uncertainties related to our business or events that happen after the date of this MD&A.
10 | TC Energy Management's discussion and analysis 2024
Our forward-looking information is based on the following key assumptions and subject to the following risks and uncertainties:
Assumptions
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•regulatory decisions and outcomes
•planned and unplanned outages and the utilization of our pipelines, power and storage assets
•integrity and reliability of our assets
•anticipated construction costs, schedules and completion dates
•access to capital markets, including portfolio management
•expected industry, market and economic conditions, including the impact of these on our customers and suppliers
•inflation rates, commodity and labour prices
•interest, tax and foreign exchange rates
•nature and scope of hedging.
Risks and uncertainties
•realization of expected benefits from acquisitions and divestitures, including the Spinoff Transaction
•our ability to successfully implement our strategic priorities, including the Focus Project, and whether they will yield the expected benefits
•our ability to implement a capital allocation strategy aligned with maximizing shareholder value
•operating performance of our pipelines, power generation and storage assets
•amount of capacity sold and rates achieved in our pipeline businesses
•amount of capacity payments and revenues from power generation assets due to plant availability
•production levels within supply basins
•construction and completion of capital projects
•cost, availability of, and inflationary pressures on, labour, equipment and materials
•availability and market prices of commodities
•access to capital markets on competitive terms
•interest, tax and foreign exchange rates
•performance and credit risk of our counterparties
•regulatory decisions and outcomes of legal proceedings, including arbitration and insurance claims
•our ability to effectively anticipate and assess changes to government policies and regulations, including those related to the environment
•our ability to realize the value of tangible assets and contractual recoveries
•competition in the businesses in which we operate
•unexpected or unusual weather
•acts of civil disobedience
•cybersecurity and technological developments
•sustainability-related risks including climate-related risks and the impact of energy transition on our business
•economic and political conditions, and ongoing trade negotiations in North America, as well as globally
•global health crises, such as pandemics and epidemics, and the impacts related thereto.
You can read more about these factors and others in this MD&A and in other reports we have filed with Canadian securities regulators and the SEC.
As actual results could vary significantly from the forward-looking information, you should not put undue reliance on forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking statements due to new information or future events unless we are required to by law.
FOR MORE INFORMATION
You can find more information about TC Energy in our Annual Information Form and other disclosure documents, which are available on SEDAR+ (www.sedarplus.ca).

TC Energy Management's discussion and analysis 2024 | 11
About our business
With over 70 years of experience, TC Energy is a leader in the responsible development and reliable operation of North American energy infrastructure, including natural gas pipelines, power generation and natural gas storage facilities.
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12 | TC Energy Management's discussion and analysis 2024
OUR CORE BUSINESSES
We operate in two core businesses – Natural Gas Pipelines and Power and Energy Solutions. In order to provide information that is aligned with how management decisions about our businesses are made and how performance of our businesses is assessed, our results are reflected in four operating segments: Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines, Mexico Natural Gas Pipelines and Power and Energy Solutions. We also have a Corporate segment consisting of corporate and administrative functions that provide governance, financing and other support to TC Energy's business segments.
TC Energy completed the Spinoff Transaction on October 1, 2024 and subsequently accounted for the Liquids Pipelines business as a discontinued operation. Refer to the Discontinued operations section on page 94 for additional information.
Year at-a-glance
at December 31
(millions of $) 2024
2023¹
Total assets by segment    
Canadian Natural Gas Pipelines 31,167  29,782 
U.S. Natural Gas Pipelines 56,304  50,499 
Mexico Natural Gas Pipelines 15,995  12,003 
Power and Energy Solutions 10,217  9,525 
Corporate 4,189  7,715 
117,872  109,524 
Discontinued Operations
 371  15,510 
118,243  125,034 
1    Prior year results have been recast to reflect the split between continuing and discontinued operations.
year ended December 31
(millions of $) 2024 2023
Total revenues from continuing operations by segment1
    
Canadian Natural Gas Pipelines 5,600  5,173 
U.S. Natural Gas Pipelines 6,339  6,229 
Mexico Natural Gas Pipelines
 870  846 
Power and Energy Solutions 954  1,019 
Corporate
 8  — 
13,771  13,267 
1    Excludes revenues of $2,217 million and $2,667 million for the years ended December 31, 2024 and 2023, respectively, related to discontinued operations, which represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023.
TC Energy Management's discussion and analysis 2024 | 13
year ended December 31
(millions of $) 2024 2023
Comparable EBITDA from continuing operations by segment1,2
    
Canadian Natural Gas Pipelines 3,388  3,335 
U.S. Natural Gas Pipelines 4,511  4,385 
Mexico Natural Gas Pipelines 999  805 
Power and Energy Solutions 1,214  1,020 
Corporate (63) (73)
10,049  9,472 
1    Comparable EBITDA is a non-GAAP measure and does not have any standardized meaning as prescribed by U.S. GAAP and therefore may not be comparable to similar measures presented by other companies. The most directly comparable GAAP measure is segmented earnings (losses). Refer to the Financial results sections for each business segment for a reconciliation to comparable EBITDA as well as the About our business - Non-GAAP measures section for additional information.
2    Excludes Comparable EBITDA from discontinued operations of $1,145 million and $1,516 million for the years ended December 31, 2024 and 2023, respectively, which represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023. For further information on the reconciliation of segmented earnings to comparable EBITDA, refer to the Financial results sections for each business segment and the Discontinued operations section.
14 | TC Energy Management's discussion and analysis 2024
OUR STRATEGY
Our vision is to be the trusted leader in North America’s energy infrastructure, committed to excellence in safety, performance and stakeholder relationships. Our mission is to safely and efficiently move, generate and store the critical energy that North America and the world rely on. We are a team of energy problem solvers working to deliver energy in a safe, reliable, secure and affordable manner, while seeking to uphold our value proposition: to deliver solid growth with low risk and repeatable performance, year after year.
Our business consists of natural gas transportation and storage, as well as power generation assets:
•we deliver natural gas to Canada, the U.S. and Mexico, including to export terminals that ship LNG globally
•we generate electricity in Canada and the U.S., primarily from nuclear energy, but also from natural gas, wind and solar assets
•we store natural gas in Canada and the U.S. through regulated and non-regulated businesses.
These long-life infrastructure assets are anchored by our conservative risk preferences and are generally supported by long-term commercial arrangements and/or rate regulation. We believe that our assets will generate predictable and sustainable cash flows and earnings, providing the cornerstones of our low-risk value proposition. Our long-term strategy is driven by the following key beliefs:
•natural gas will continue to play a pivotal role in North America's energy future and support global GHG emissions reduction
•the need for reliable, on-demand energy sources will continue to grow
•energy assets will become increasingly valuable in a world with growing energy demand and existing challenges in developing new infrastructure.
Allocation of comparable EBITDA from continuing operations1
year ended December 31 2024
2023²
Comparable EBITDA from continuing operations by segment3
  
Canadian Natural Gas Pipelines 33  % 35  %
U.S. Natural Gas Pipelines 45  % 46  %
Mexico Natural Gas Pipelines 10  % 8  %
Power and Energy Solutions 12  % 11  %
100  % 100  %
1    Refer to the Financial highlights section for an allocation of segmented earnings by business segment.
2    Prior year results have been recast to reflect continuing operations only.
3    Excludes losses from Corporate comparable EBITDA from continuing operations of $63 million and $73 million for the years ended December 31, 2024 and 2023, respectively.
Our asset mix will continue to evolve with the North American energy mix. We anticipate the following trends in capital allocation over the next several years:
•Natural Gas Pipelines will continue to attract capital to meet growing customer demand, driven by coal-to-gas conversion, LNG exports and data centre buildouts
•Power and Energy Solutions' capital will primarily be allocated to extending the life and increasing the capacity of the nuclear business. We will make measured investment in emerging technologies to develop capabilities that are complementary to our core businesses, without taking significant commodity price risk, volumetric risk or utilizing unproven technologies
•additional discretionary investment will fund select high-grade opportunities in our development projects portfolio and incremental opportunities around existing assets across our businesses.
TC Energy Management's discussion and analysis 2024 | 15
Key components of our strategy
Maximize the value of our assets through safety and operational excellence
•Maintaining safe and reliable operations by maximizing availability of assets and ensuring asset integrity, while minimizing environmental impacts, continues to be the foundation of our business
•Our extensive network of natural gas pipeline assets connect long-life, low-cost supply basins with premium North American and export markets, which we believe will generate predictable and sustainable cash flows and earnings
•Our power and non-regulated storage assets are primarily under long-term contracts that provide stable cash flows and earnings
•We continually seek to enhance and protect the value of each of our assets using operational, commercial and other levers while pursuing revenue enhancements such as creating additional capacity in our systems and leveraging commercial marketing activities.
Execute our selective portfolio of growth projects
•Safety, executability, profitability and reliability are fundamental to our investments
•We develop high quality, long-life assets, largely underpinned by long-term contracts or rate regulation. We expect that these investments will contribute to incremental earnings and cash flows as they are placed in service
•We believe that our incumbent positions in regions with natural gas and power demand growth are expected to present us with a steady cadence of growth opportunities
•We strive to develop projects and manage construction risk in a disciplined manner that maximizes capital efficiency and returns to shareholders
•We seek to prudently manage development costs, minimizing capital at risk in a project's early stages
•We rely on our experience, as well as our policy, regulatory, commercial, financial, legal and operational expertise to permit, fund, build and integrate new pipelines and other energy infrastructure
•We will advance selected opportunities, including lower carbon growth initiatives, in emerging sub-sectors where we are likely to build a strong competitive position, market conditions are appropriate, technology is proven and project risks and returns are known and acceptable.
Ensure financial strength and agility
•Disciplined capital allocation supports our ability to maximize asset value over the short, medium and long term while protecting and growing our network of assets. We seek to allocate capital in a manner that improves the cost competitiveness and returns of our portfolio, while extending the life of our assets
•Our capital allocation process is designed to ensure that we remain within the annual target for net capital spend, while maximizing the expected returns of the projects that we sanction
•We assess opportunities to develop and acquire energy infrastructure that complements our existing portfolio, protects and grows our business, enhances future resilience under a changing energy mix and diversifies access to attractive supply and market regions within our risk preferences
•We monitor trends specific to energy supply and demand fundamentals, in addition to analyzing how our portfolio performs under different energy mix scenarios. This enables the identification of opportunities that we believe will contribute to our resilience, strengthen our asset base and/or improve diversification
•We believe that our high-quality, diversified portfolio of energy infrastructure assets results in predictable, low-risk cash flows and positions us well to succeed under various energy transition scenarios and across all economic cycles
•We continually seek to enhance our core competencies in safety, operational excellence, investment opportunity origination, project execution, stakeholder relations and sustainability to ensure we deliver shareholder value.
16 | TC Energy Management's discussion and analysis 2024
How we operate our business
The need for safe, reliable, secure and affordable energy solutions has become increasingly important. Decades of experience in the energy infrastructure business, a disciplined approach to project management and a proven capital allocation model result in a solid competitive position as we remain focused on our purpose – to connect the world to the energy it needs. We will do this through:
•strong leadership and governance: we maintain rigorous governance over our approach to business ethics, enterprise risk management, competitive behaviour, operating capabilities and strategy development, as well as regulatory, legal, commercial, stakeholder and financing support
•a high-quality portfolio: the strategic advantage supporting our vision is our extensive asset footprint in an industry with high barriers to entry. Our low-risk portfolio of assets offers the scale to provide essential and highly competitive infrastructure services, enabling us to maximize the full-life value of our investments throughout all points of the business cycle. Our platforms not only provide a diversified portfolio but also position TC Energy as a leader in the energy infrastructure sector. Our synergistic footprint supports both molecules and electrons, providing us flexibility to allocate capital towards natural gas, electrification or other emerging lower-carbon technologies that are complementary to our core businesses
•disciplined operations: our workforce is highly skilled in designing, building and operating energy infrastructure with a focus on safety and operational excellence and a commitment to the environment in the communities we serve that is suited to both today's environment, as well as an evolving energy industry
•financial positioning: we exhibit consistently strong financial performance, long-term stability and profitability, along with a disciplined approach to capital investment. We can access competitively-priced capital to support new investments while preserving financial flexibility, including portfolio management, to fund our operations in all market conditions. We aim to deliver a balance of dividend income and share price growth
•proven ability to adapt: we have a long track record of turning policy and technology changes into opportunities – for example, re-entering Mexico when the country shifted from fuel oil to natural gas, reversing pipeline flows in response to the shale gas revolution, installing electric compression and/or switching gas compression to electrification and currently assessing development of grid-scale, flexible and clean energy storage
•commitment to sustainability: we take a long-term view to managing our interactions with the environment, Indigenous groups, community members and landowners. We aim to communicate transparently to all rights holders and stakeholders on sustainability-related topics and publish annually our corporate GHG emissions intensity in our Report on Sustainability. We continue to focus on our sustainability commitments, which reflect the interests of our business, Indigenous rights holders and stakeholders; positioning us for long-term success. We are committed to collectively advancing a lower-emissions energy system and expect to provide an update on our interim GHG emission reduction target in 2025 to reflect the impact of the Liquids Pipelines business spinoff and projected increased utilization across our systems. We remain focused on our long-term goal of positioning to reach net-zero emissions from our operations by 2050 and acknowledge that achieving this goal requires accelerated changes in global energy policies, regulations and support for new technologies. We continue to focus on our nine sustainability commitments and associated metrics and targets that help ensure our business is well positioned for long-term success
•open communication: we carefully manage relationships with our customers, suppliers, regulators and other stakeholders and offer clear, candid communication to investors in order to build trust and support
•culture and people: our people are our most important asset and living our company values of safety, personal accountability, working as one team and active learning. These values shape how we do business and, in turn, deliver on our commitments.
TC Energy Management's discussion and analysis 2024 | 17
Our risk preferences
The following is an overview of our risk philosophy:
•financial strength and flexibility: rely on internally generated cash flows, existing debt capacity, partnerships and portfolio management to finance new initiatives
•known and acceptable project risks: select investments with known, acceptable and manageable project execution risk, including stakeholder considerations, partnership agreements, human capital and capability constraints
•business underpinned by strong fundamentals and policy support: invest in assets that are investment-grade on a stand-alone basis with stable cash flows supported by strong underlying macroeconomic fundamentals, conducive policy and regulations and/or long-term contracts with creditworthy counterparties
•manage credit metrics to ensure "top-end" sector ratings: solid investment-grade ratings are an important competitive advantage and TC Energy will seek to ensure our credit profile remains at the top end of our sector while balancing the interests of equity and fixed income investors
•prudent management of counterparty exposure: limit counterparty concentration and sovereign risk; seek diversification and solid commercial arrangements underpinned by strong fundamentals.
18 | TC Energy Management's discussion and analysis 2024

2024 FINANCIAL HIGHLIGHTS
We use certain financial measures that do not have a standardized meaning under GAAP because we believe they improve our ability to compare results between reporting periods and enhance understanding of our operating performance. Known as non-GAAP measures, they may not be comparable to similar measures provided by other companies.
Comparable EBITDA, comparable earnings and comparable earnings per common share from continuing and discontinued operations and comparable funds generated from operations are all non-GAAP measures. Refer to page 24 for more information about the non-GAAP measures we use, as well as the Financial results section in each business segment and Discontinued operations section for reconciliations to the most directly comparable GAAP measures.
As discussed on page 10 of the About this document section, results of the Liquids Pipelines business are reported as a discontinued operation. To allow for a meaningful comparison, discussions throughout this MD&A are based on continuing operations unless otherwise noted. Prior year results have been recast to reflect the split between continuing and discontinued operations. Discontinued operations reflect nine months of Liquids Pipelines earnings for the year ended December 31, 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
year ended December 31
(millions of $, except per share amounts) 2024
2023¹
2022¹
Income
Revenues
 13,771  13,267  12,309 
Net income (loss) attributable to common shares 4,594  2,829  641 
from continuing operations
 4,199  2,217  8 
 from discontinued operations2
 395  612  633 
Net income (loss) per common share – basic $4.43  $2.75  $0.64 
from continuing operations
 $4.05  $2.15  $0.01 
 from discontinued operations2
 $0.38  $0.60  $0.63 
Comparable EBITDA3
 11,194  10,988  9,901 
from continuing operations 10,049  9,472  8,483 
from discontinued operations2
 1,145  1,516  1,418 
Comparable earnings3
 4,430  4,652  4,279 
from continuing operations
 3,865  3,896  3,618 
from discontinued operations2
 565  756  661 
Comparable earnings per common share3
 $4.27  $4.52  $4.30 
from continuing operations
 $3.73  $3.78  $3.64 
   from discontinued operations2
 $0.54  $0.74  $0.66 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
3Additional information on the most directly comparable GAAP measure can be found on page 24.
TC Energy Management's discussion and analysis 2024 | 19

year ended December 31
(millions of $)
 2024 2023 2022
Cash flows1
Net cash provided by operations2
 7,696  7,268  6,375 
Comparable funds generated from operations2,3
 7,890  7,980  7,353 
Capital spending4
 7,904  12,298  8,961 
Acquisitions, net of cash acquired —  (307) — 
Proceeds from sales of assets, net of transaction costs 791  33  — 
Disposition of equity interest, net of transaction costs5
 419  5,328  — 
1Includes continuing and discontinued operations.
2Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
3Additional information on the most directly comparable GAAP measure can be found on page 24.
4Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments net of Other distributions from equity investments of $3.1 billion in 2024 in the Canadian Natural Gas Pipelines segment (2023 - nil, 2022 - $1.2 billion in the Corporate segment). Refer to Note 5, Segmented information, Note 7, Coastal GasLink and Note 12, Loans receivable from affiliates, of our 2024 Consolidated financial statements for additional information.
5Included in the Financing activities section of the Consolidated statement of cash flows, of our 2024 Consolidated financial statements.
at December 31 (unless otherwise noted)
(millions of $, except per share amounts) 2024 2023 2022
Balance sheet
Total assets1
 118,243  125,034  114,348 
Long-term debt, including current portion 47,931  52,914  41,543 
Junior subordinated notes 11,048  10,287  10,495 
Preferred shares 2,499  2,499  2,499 
Non-controlling interests 10,768  9,455  126 
Common shareholders' equity 25,093  27,054  31,491 
Dividends declared2
per common share3
 $3.7025  $3.72  $3.60 
Basic common shares (millions)
– weighted average for the year ended
 1,038  1,030  995 
– issued and outstanding at end of year 1,039  1,037  1,018 
1At December 31, 2024, includes assets of $371 million (2023 - $15,510 million; 2022 - $15,587 million), related to discontinued operations. Refer to Note 4, Discontinued operations, of our 2024 Consolidated financial statements for additional information.
2For the year ended.
3Dividends declared in fourth quarter 2024 reflect TC Energy’s proportionate allocation following the Spinoff Transaction. Refer to the Discontinued operations section for additional information.
20 | TC Energy Management's discussion and analysis 2024

Consolidated results
year ended December 31
(millions of $, except per share amounts) 2024
2023¹
2022¹
Canadian Natural Gas Pipelines 2,016  (90) (1,440)
U.S. Natural Gas Pipelines 4,053  3,531  2,617 
Mexico Natural Gas Pipelines 929  796  491 
Power and Energy Solutions 1,102  1,004  833 
Corporate (136) (144) (51)
Total segmented earnings (losses) 7,964  5,097  2,450 
Interest expense
 (3,019) (2,966) (2,300)
Allowance for funds used during construction 784  575  369 
Foreign exchange gains (losses), net
 (147) 320  (185)
Interest income and other 324  272  140 
Income (loss) from continuing operations before income taxes
 5,906  3,298  474 
Income tax (expense) recovery from continuing operations
 (922) (842) (322)
Net income (loss) from continuing operations
 4,984  2,456  152 
Net income (loss) from discontinued operations, net of tax2
 395  612  633 
Net income (loss)
 5,379  3,068  785 
Net (income) loss attributable to non-controlling interests
 (681) (146) (37)
Net income (loss) attributable to controlling interests
 4,698  2,922  748 
Preferred share dividends (104) (93) (107)
Net income (loss) attributable to common shares
 4,594  2,829  641 
Net income (loss) per common share – basic
 $4.43  $2.75  $0.64 
   from continuing operations
 $4.05  $2.15  $0.01 
   from discontinued operations2
 $0.38  $0.60  $0.63 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
year ended December 31
(millions of $)
 2024
2023¹
2022¹
Amounts attributable to common shares
   Net income (loss) from continuing operations 4,984  2,456  152 
   Net (income) loss attributable to non-controlling interests (681) (146) (37)
   Net income (loss) attributable to controlling interests from continuing operations
 4,303  2,310  115 
   Preferred share dividends
 (104) (93) (107)
   Net income (loss) attributable to common shares from continuing operations
 4,199  2,217  8 
   Net income (loss) from discontinued operations, net of tax2
 395  612  633 
Net income (loss) attributable to common shares
 4,594  2,829  641 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
Net income attributable to common shares from continuing operations in 2024 was $4.2 billion or $4.05 per share (2023 – $2.2 billion or $2.15 per share; 2022 – $8 million or $0.01 per share), an increase of $2.0 billion or $1.90 per share compared to 2023 and an increase of $2.2 billion or $2.14 per share in 2023 compared to 2022. Refer to the About our business - Non-GAAP measures section for a listing of specific items included in Net income attributable to common shares from continuing operations, which have been excluded from our calculation of comparable measures.
Refer to the Discontinued operations - Non-GAAP measures section for a listing of specific items included in Net income (loss) from discontinued operations, net of tax, which have been excluded from our calculation of comparable measures.
TC Energy Management's discussion and analysis 2024 | 21

Cash flows
Net cash provided by operations of $7.7 billion in 2024 was six per cent higher than 2023 primarily due to higher funds generated from continuing operations and the amount and timing of working capital changes. Comparable funds generated from operations of $7.9 billion in 2024 were one per cent lower than 2023 primarily due to lower comparable earnings, partially offset by increased distributions from our equity investments.
Funds used in investing activities
Capital spending1
year ended December 31
(millions of $) 2024 2023 2022
Canadian Natural Gas Pipelines 2,100  6,184  4,719 
U.S. Natural Gas Pipelines 2,575  2,660  2,137 
Mexico Natural Gas Pipelines 2,228  2,292  1,027 
Power and Energy Solutions 824  1,080  894 
Corporate 50  33  41 
7,777  12,249  8,818 
Discontinued operations 127  49  143 
7,904  12,298  8,961 
1Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments net of Other distributions from equity investments of $3.1 billion in 2024 in the Canadian Natural Gas Pipelines segment (2023 - nil, 2022 - $1.2 billion in the Corporate segment). Refer to Note 5, Segmented information, Note 7, Coastal GasLink and Note 12, Loans receivable from affiliates, of our 2024 Consolidated financial statements, for additional information.
In 2024 and 2023, we invested $7.9 billion and $12.3 billion, respectively, in capital projects to maintain and optimize the value of our existing assets and to develop new, complementary assets in high-demand areas. Our total capital spending in 2024 and 2023 included contributions of $1.5 billion (net of distributions) and $4.1 billion, respectively, to our equity investments, predominantly related to Coastal GasLink Limited Partnership (Coastal GasLink LP) and Bruce Power.
Proceeds from sales of assets
In 2024, TC Energy and its partner, Northern New England Investment Company, Inc., a subsidiary of Énergir L.P. (Énergir), completed the sale of Portland Natural Gas Transmission System (PNGTS) to a third party. Our share of the proceeds was     $743 million (US$546 million), net of transaction costs.
In 2024, we also completed the sale of other non-core assets for gross proceeds of $48 million.
In 2023, we completed the sale of a 20.1 per cent equity interest in Port Neches Link LLC to its joint venture partner, Motiva Enterprises, for gross proceeds of $33 million (US$25 million). As part of the Spinoff Transaction on October 1, 2024, our remaining interest in Port Neches Link LLC was transferred to South Bow.
Acquisitions
In 2023, we acquired 100 per cent of the Class B Membership Interests in Fluvanna Wind Farm and Blue Cloud Wind Farm (Texas Wind Farms) for US$224 million, before post-closing adjustments.
Balance sheet
We continue to maintain a solid financial position while growing our total assets, excluding discontinued operations, by         $8.3 billion in 2024. At December 31, 2024, common shareholders' equity and non-controlling interests, represented         37 per cent (2023 – 37 per cent) of our capital structure, while other subordinated capital, in the form of junior subordinated notes and preferred shares, represented an additional 14 per cent (2023 – 13 per cent). Refer to the Financial Condition section for additional information.
22 | TC Energy Management's discussion and analysis 2024

Dividends
Commencing with the dividends payable on January 31, 2025 to shareholders of record at the close of business on     December 31, 2024, the amounts reflect TC Energy’s proportionate allocation following the Spinoff Transaction. Refer to the Discontinued operations section for additional information.
On February 14, 2025, we announced a quarterly dividend on our outstanding common shares of $0.85 per common share for the quarter ending March 31, 2025, which represents an increase of 3.3 per cent from TC Energy's proportionate allocation of the dividend following the Spinoff Transaction. This equates to an annual dividend of $3.40 per common share. This was the         twenty-fifth consecutive year we have increased the dividend on our common shares and is consistent with our goal of growing our common share dividend at an average annual rate of three to five per cent.
Dividend reinvestment and share purchase plan
Under the DRP, eligible holders of common and preferred shares of TC Energy can reinvest their dividends and make optional cash payments to obtain additional TC Energy common shares. From August 31, 2022 to July 31, 2023, common shares were issued from treasury at a discount of two per cent to market prices over a specified period.
Commencing with the dividends declared on July 27, 2023, common shares purchased under TC Energy's DRP are acquired on the open market at 100 per cent of the weighted average purchase price.
Cash dividends paid
year ended December 31
(millions of $) 2024 2023 2022
Common shares 3,953  2,787  3,192 
Preferred shares 99  92  106 
TC Energy Management's discussion and analysis 2024 | 23

NON-GAAP MEASURES
This MD&A references non-GAAP measures, which are described in the table below. These measures do not have any standardized meaning as prescribed by GAAP and therefore may not be comparable to similar measures presented by other entities. These measures are reviewed regularly by our President and Chief Executive Officer, management and the Board of Directors in assessing our performance and making decisions regarding the ongoing operations of our business and its ability to generate cash flows. Some or all of these measures may also be used by investors and other external users of our financial statements as a supplemental measure to provide decision-useful information regarding our period-over-period performance and ability to generate earnings that are core to our ongoing operations. Discussions throughout this MD&A on the factors impacting comparable earnings before interest, taxes, depreciation and amortization (comparable EBITDA) and comparable earnings before interest and taxes (comparable EBIT) are consistent with the factors that impact segmented earnings, except where noted otherwise.
Comparable measures
We calculate comparable measures by adjusting certain GAAP measures for specific items we believe are significant but not reflective of our underlying operations in the period. Except as otherwise described herein, these comparable measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, as applicable.
Our decision to adjust for a specific item in reporting comparable measures is subjective and made after careful consideration. We maintain a consistent approach to adjustments, which generally fall into the categories described below:
•by their nature are unusual, infrequent and separately identifiable from our normal business operations and in our view are not reflective of our underlying operations in the period and generally include the following:
◦gains or losses on sales of assets or assets held for sale; impairment of goodwill, plant, property and equipment, equity investments and other assets; legal, contractual and other infrequent settlements; acquisition, integration and restructuring costs; expected credit loss provisions on net investment in leases and certain contract assets in Mexico; impacts resulting from changes in legislation and enacted tax rates and unusual tax refunds/payments and valuation allowance adjustments
•unrealized gains and losses related to fair value adjustments that do not reflect realized earnings or losses or cash impacts incurred in the current period from our underlying operations and generally include the following:
◦unrealized gains and losses from changes in the fair value of derivatives related to financial and commodity price risk management activities; unrealized fair value adjustments related to our proportionate share of Bruce Power’s risk management activities and its funds invested for post-retirement benefits; unrealized fair value adjustments on intercompany loans that impact consolidated earnings.
The following table identifies our non-GAAP measures against their most directly comparable GAAP measures. These measures are applicable to each of our continuing operations and discontinued operations. Quantitative reconciliations of our comparable measures to their GAAP measures and a discussion of specific adjustments made for 2024 and comparative periods can be found on pages 26 and 27, the Financial results section in each business segment, and the Financial condition section. Non-GAAP measures for discontinued operations are found in the Discontinued operations section on page 96.
Non-GAAP measure GAAP measure
comparable EBITDA segmented earnings (losses)
comparable EBIT segmented earnings (losses)
comparable earnings net income (loss) attributable to common shares
comparable earnings per common share net income (loss) per common share
funds generated from operations net cash provided by operations
comparable funds generated from operations net cash provided by operations
24 | TC Energy Management's discussion and analysis 2024

Comparable EBITDA and comparable EBIT
Comparable EBITDA represents segmented earnings (losses) adjusted for specific items described in the Comparable measures section, excluding charges for depreciation and amortization. We use comparable EBITDA as a measure of our earnings from ongoing operations as it is a useful indicator of our performance and is also presented on a consolidated basis. Comparable EBIT represents segmented earnings (losses) adjusted for specific items and is an effective tool for evaluating trends in each segment. Refer to each business segment and the Discontinued operations section for a reconciliation to segmented earnings (losses).
Funds generated from operations and comparable funds generated from operations
Funds generated from operations reflects net cash provided by operations before changes in operating working capital. The components of changes in working capital are disclosed in Note 29, Changes in operating working capital, of our 2024 Consolidated financial statements. Comparable funds generated from operations is adjusted for the cash impact of specific items described in the Comparable measures section. We believe funds generated from operations and comparable funds generated from operations are useful measures of our consolidated operating cash flows because they exclude fluctuations from working capital balances, which do not necessarily reflect underlying operations in the same period, and are used to provide a consistent measure of the cash-generating ability of our businesses. Refer to the Financial condition section for a reconciliation to Net cash provided by operations.
Comparable earnings and comparable earnings per common share
Comparable earnings represents earnings attributable to common shareholders on a consolidated basis, adjusted for specific items described in the Comparable measures section. Comparable earnings is comprised of segmented earnings (losses), Interest expense, AFUDC, Foreign exchange (gains) losses, net, Interest income and other, Income tax expense (recovery), Net income (loss) attributable to non-controlling interests and Preferred share dividends on our Consolidated statement of income, adjusted for specific items. We use comparable earnings as a measure of our earnings from ongoing operations as it is a useful indicator of our performance and is also presented on a consolidated basis. Refer to page 27 and the Discontinued operations section for reconciliations to Net income (loss) attributable to common shares and Net income (loss) per common share for our continuing operations and discontinued operations.
TC Energy Management's discussion and analysis 2024 | 25

Comparable earnings and comparable earnings per common share - from continuing operations
The following specific items were recognized in Net income (loss) attributable to common shares from continuing operations and were excluded from comparable earnings from continuing operations:
2024
•a pre-tax gain of $572 million (after-tax $456 million) related to the sale of PNGTS which was completed on August 15, 2024
•a pre-tax net gain on debt extinguishment of $228 million (after-tax $178 million) related to the purchase and cancellation of certain senior unsecured notes and medium term notes and the retirement of outstanding callable notes in October 2024
•pre-tax unrealized foreign exchange gains, net of $143 million (after-tax $153 million) on the peso-denominated intercompany loan between TransCanada PipeLines Limited (TCPL) and Transportadora de Gas Natural de la Huasteca (TGNH), net of non-controlling interest
•a pre-tax gain of $48 million (after-tax $63 million) related to the sale of non-core assets in U.S. Natural Gas Pipelines and Canadian Natural Gas Pipelines
•a pre-tax recovery of $22 million (after-tax $15 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico, net of non-controlling interest
•a deferred income tax expense of $96 million resulting from the revaluation of remaining deferred tax balances following the Spinoff Transaction
•a pre-tax impairment charge of $36 million (after-tax $27 million) related to development costs incurred on Project Tundra, a next-generation technology carbon capture and storage project, following our decision to end our collaboration on the project
•a pre-tax expense of $34 million (after-tax $26 million) related to a non-recurring third-party settlement
•a pre-tax expense of $24 million (after-tax $18 million) related to Focus Project costs
•pre-tax costs of $10 million (after-tax $42 million) related to the NGTL System Ownership Transfer.
2023
•a pre-tax impairment charge of $2.1 billion (after-tax $1.9 billion) related to our equity investment in Coastal GasLink LP. Refer to Note 7, Coastal GasLink, of our 2024 Consolidated financial statements for additional information
•a pre-tax expense of $65 million (after-tax $48 million) related to Focus Project costs
•pre-tax unrealized foreign exchange losses, net, of $44 million (after-tax $44 million) on the peso-denominated intercompany loan between TCPL and TGNH
•a pre-tax recovery of $80 million (after-tax $55 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico.
2022
•a pre-tax impairment charge of $3.0 billion (after-tax $2.6 billion) related to our equity investment in Coastal GasLink LP
•a pre-tax goodwill impairment charge of $571 million (after-tax $531 million) related to Great Lakes
•a $196 million expense related to the settlement of prior years' income tax assessments related to our operations in Mexico
•a pre-tax expected credit loss provision of $163 million (after-tax $114 million) related to TGNH net investment in leases and certain contract assets in Mexico.
Refer to the Financial results section in each business segment and the Financial condition section of this MD&A for additional information.
26 | TC Energy Management's discussion and analysis 2024

Reconciliation of net income (loss) attributable to common shares to comparable earnings - from continuing operations
year ended December 31
(millions of $, except per share amounts) 2024
2023¹
2022¹
Net income (loss) attributable to common shares from continuing operations
 4,199  2,217  8 
Specific items (pre tax):
Gain on sale of PNGTS (572) —  — 
Net gain on debt extinguishment2
 (228) —  — 
Foreign exchange (gains) losses, net – intercompany loan3
 (143) 44  — 
Gain on sale of non-core assets (48) —  — 
Expected credit loss provision on net investment in leases
  and certain contract assets in Mexico4
 (22) (80) 163 
Project Tundra impairment charge 36  —  — 
Third-party settlement 34  —  — 
Focus Project costs5
 24  65  — 
NGTL System ownership transfer costs 10  —  — 
Coastal GasLink impairment charge —  2,100  3,048 
Great Lakes goodwill impairment charge —  —  571 
Bruce Power unrealized fair value adjustments
 (8) (7) 17 
Risk management activities6
 433  (395) 149 
Taxes on specific items7
 150  (48) (338)
Comparable earnings from continuing operations
 3,865  3,896  3,618 
Net income (loss) per common share from continuing operations
 $4.05  $2.15  $0.01 
Specific items (net of tax)
 (0.32) 1.63  3.63 
Comparable earnings per common share from continuing operations
 $3.73  $3.78  $3.64 
1Prior year results have been recast to reflect continuing operations only.
2In October 2024, TCPL commenced and completed our cash tender offers to purchase and cancel certain senior unsecured notes and medium term notes at a 7.73 per cent weighted average discount. In addition, we retired outstanding callable notes at par. These extinguishments of debt resulted in a pre-tax net gain of $228 million, primarily due to fair value discounts and unamortized debt issue costs. The net gain on debt extinguishment was recorded in Interest expense in the Consolidated statement of income. Refer to the Financial condition section for additional information.
3In 2023, TCPL and TGNH became party to an unsecured revolving credit facility. The loan receivable and loan payable are eliminated upon consolidation; however, due to differences in the currency that each entity reports its financial results, there is an impact to net income reflecting the revaluation and translation of the loan receivable and loan payable to TC Energy's reporting currency. As the amounts do not accurately reflect what will be realized at settlement, we exclude from comparable measures the unrealized foreign exchange gains and losses on the loan receivable, as well as the corresponding unrealized foreign exchange gains and losses on the loan payable, net of non-controlling interest.
4In 2022, TGNH and the CFE executed agreements which consolidate several natural gas pipelines under one TSA. As this TSA contains a lease, we have recognized amounts in net investment in leases on our Consolidated balance sheet. As required by U.S. GAAP, we have recognized an expected credit loss provision related to net investment in leases and certain contract assets in Mexico, which will fluctuate from period to period based on changing economic assumptions and forward-looking information. This provision is an estimate of losses that may occur over the duration of the TSA through 2055. This provision does not reflect losses or cash outflows that were incurred under this lease arrangement in the current period or from our underlying operations, and therefore, we have excluded any unrealized changes, net of non-controlling interest, from comparable measures. Refer to Note 28, Risk management and financial instruments, of our 2024 Consolidated financial statements for additional information.
5In 2022, we launched the Focus Project with benefits in the form of enhanced safety, productivity and cost-effectiveness expected to be realized in the future. Beginning in 2023, we recognized expenses in Plant operating costs and other, for external consulting and severance, some of which are not recoverable through regulatory and commercial tolling structures. Refer to the Corporate – Significant events section for additional information.
TC Energy Management's discussion and analysis 2024 | 27

6
 year ended December 31
(millions of $) 2024 2023 2022
U.S. Natural Gas Pipelines (113) 80  (15)
Canadian Power 84  (31) 4 
U.S. Power (10) 9  — 
Natural Gas Storage (57) 91  11 
Interest rate (71) —  — 
Foreign exchange (266) 246  (149)
(433) 395  (149)
Income tax attributable to risk management activities 105  (99) 36 
Total unrealized gains (losses) from risk management activities (328) 296  (113)
7
Refer to the Corporate - Financial results section for additional information.
Comparable EBITDA to comparable earnings - from continuing operations
Comparable EBITDA from continuing operations represents segmented earnings (losses) from continuing operations adjusted for the specific items described above and excludes charges for depreciation and amortization. For further information on our reconciliation to comparable EBITDA, refer to the Financial results sections for each business segment.
year ended December 31
(millions of $, except per share amounts) 2024
2023¹
2022¹
Comparable EBITDA from continuing operations
Canadian Natural Gas Pipelines 3,388  3,335  2,806 
U.S. Natural Gas Pipelines 4,511  4,385  4,089 
Mexico Natural Gas Pipelines 999  805  753 
Power and Energy Solutions 1,214  1,020  907 
Corporate
 (63) (73) (72)
Comparable EBITDA from continuing operations 10,049  9,472  8,483 
Depreciation and amortization (2,535) (2,446) (2,262)
Interest expense included in comparable earnings (3,176) (2,966) (2,300)
Allowance for funds used during construction 784  575  369 
Foreign exchange gains (losses), net included in comparable earnings
 (85) 118  (8)
Interest income and other
 324  272  140 
Income tax (expense) recovery included in comparable earnings
 (772) (890) (660)
Net (income) loss attributable to non-controlling interests included in comparable
earnings
 (620) (146) (37)
Preferred share dividends (104) (93) (107)
Comparable earnings from continuing operations 3,865  3,896  3,618 
Comparable earnings per common share from continuing operations
 $3.73  $3.78  $3.64 
1Prior year results have been recast to reflect continuing operations only.
28 | TC Energy Management's discussion and analysis 2024

Comparable EBITDA from continuing operations
2024 versus 2023
Comparable EBITDA from continuing operations in 2024 increased by $577 million compared to 2023 primarily due to the net result of the following:
•increased Power and Energy Solutions EBITDA primarily attributable to higher contributions from Bruce Power due to higher generation and a higher contract price, and Natural Gas Storage and other due to higher realized Alberta natural gas storage spreads, partially offset by decreased Canadian Power earnings primarily due to lower realized power prices net of lower natural gas fuel costs
•higher U.S. dollar-denominated EBITDA from Mexico Natural Gas Pipelines mainly due to increased equity earnings from Sur de Texas as a result of peso-denominated financial exposure and lower income tax expense
•increased EBITDA from Canadian Natural Gas Pipelines primarily due to higher flow-through costs and increased rate-base earnings on the NGTL System and Foothills, partially offset by lower earnings from Coastal GasLink related to the recognition of a $200 million incentive payment in 2023
•higher U.S. dollar-denominated EBITDA from U.S. Natural Gas Pipelines due to incremental earnings from growth projects placed in service and additional contract sales, partially offset by higher operational costs and decreased earnings as a result of the sale of PNGTS, which was completed on August 15, 2024
•the positive foreign exchange impact of a stronger U.S. dollar on the Canadian dollar equivalent comparable EBITDA in our U.S. dollar-denominated operations. As detailed on page 79, U.S. dollar-denominated comparable EBITDA from continuing operations increased by US$180 million compared to 2023, which was translated to Canadian dollars at an average rate of 1.37 in 2024 versus 1.35 in 2023. Refer to the Foreign exchange section for additional information.
2023 versus 2022
Comparable EBITDA from continuing operations in 2023 increased by $989 million compared to 2022 primarily due to the net result of the following:
•increased EBITDA from Canadian Natural Gas Pipelines primarily due to higher flow-through costs and increased rate-base earnings on the NGTL System and higher earnings from Coastal GasLink related to the recognition of a $200 million incentive payment upon meeting certain milestones
•increased Power and Energy Solutions EBITDA primarily attributable to higher contributions from Bruce Power as a result of a higher contract price, fewer planned outage days and lower depreciation expense, partially offset by increased business development activities across the segment
•higher U.S. dollar-denominated EBITDA from U.S. Natural Gas Pipelines due to incremental earnings from growth projects placed in service, a net increase in earnings from ANR resulting from an increase in transportation rates effective August 2022, higher realized margins related to our U.S. natural gas marketing business, partially offset by higher operational costs reflective of increased system utilization and lower commodity prices related to our mineral rights business
•higher U.S. dollar-denominated EBITDA from Mexico Natural Gas Pipelines primarily related to certain sections of the Villa de Reyes and Tula pipelines that were placed in commercial service in third quarter 2022 and 2023, partially offset by lower equity earnings from Sur de Texas primarily due to peso-denominated financial exposure and higher interest expense
•the positive foreign exchange impact of a stronger U.S. dollar on the Canadian dollar equivalent comparable EBITDA in our U.S. dollar-denominated operations. As detailed on page 79,U.S. dollar-denominated comparable EBITDA from continuing operations increased by US$100 million compared to 2022, which was translated to Canadian dollars at an average rate of 1.35 in 2023 versus 1.30 in 2022. Refer to the Foreign exchange section for additional information.
Due to the flow-through treatment of certain costs including income taxes, financial charges and depreciation in our Canadian rate-regulated pipelines, changes in these costs impact our comparable EBITDA despite having no significant effect on net income.
TC Energy Management's discussion and analysis 2024 | 29

Comparable earnings from continuing operations
2024 versus 2023
Comparable earnings from continuing operations in 2024 were $31 million or $0.05 per common share lower than in 2023, and were primarily the net result of:
•changes in comparable EBITDA from continuing operations described above
•higher depreciation and amortization reflecting expansion facilities and new projects placed in service
•higher interest expense primarily due to long-term debt issuances, net of maturities, the foreign exchange impact of a stronger U.S. dollar in 2024 compared to 2023, higher interest rates on short-term borrowings in 2024 and the impact of interest expense allocated to discontinued operations for nine months in 2024 compared to a full year in 2023
•higher AFUDC predominantly due to spending on the Southeast Gateway pipeline project, partially offset by projects placed in service and the cessation of AFUDC on Tula in fourth quarter 2023
•risk management activities used to manage our foreign exchange exposure to net liabilities in Mexico and to U.S. dollar‑denominated income and the revaluation of our peso-denominated net monetary liabilities to U.S. dollars
•higher interest income and other due to higher interest earned on short-term investments and a reduction in insurance-related provisions
•decreased income tax expense due to the impact of Mexico foreign exchange exposure and lower comparable earnings subject to income tax, partially offset by lower foreign income tax rate differentials and higher flow-through income taxes
•higher net income attributable to non-controlling interests primarily due to the net effect of the sale of a 40 per cent non-controlling equity interest in Columbia Gas Transmission, LLC (Columbia Gas) and Columbia Gulf Transmission, LLC (Columbia Gulf) in fourth quarter 2023 and the 13.01 per cent non-controlling equity interest in TGNH to the CFE, completed in second quarter 2024.
2023 versus 2022
Comparable earnings from continuing operations in 2023 were $278 million or $0.14 per common share higher than in 2022, and were primarily the net result of:
•changes in comparable EBITDA from continuing operations described above
•higher depreciation and amortization reflecting expansion facilities and new projects placed in service and the acquisition of the Texas Wind Farms, partially offset by the discontinuance of depreciation expense on TGNH assets in Mexico accounted for as leases
•higher interest expense primarily due to long-term debt issuances, net of maturities, the foreign exchange impact of a stronger U.S. dollar in 2023 compared to 2022 and higher interest rates on our long-term debt
•higher AFUDC predominantly due to the Southeast Gateway pipeline project, as well as the reactivation of AFUDC on the TGNH assets under construction, partially offset by projects placed in service
•risk management activities used to manage our foreign exchange exposure to net liabilities in Mexico and to U.S. dollar‑denominated income; and the revaluation of our peso-denominated net monetary liabilities to U.S. dollars
•higher interest income and other due to higher interest earned on short-term investments
•increased income tax expense due to the impact of higher comparable earnings subject to income tax, Mexico foreign exchange exposure and lower foreign income tax rate differentials, partially offset by lower flow-through income taxes and lower Mexico inflation adjustments
•higher net income attributable to non-controlling interests primarily due to the net effect of the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf and the acquisition of the Texas Wind Farms.
Comparable earnings per common share reflect the dilutive effect of common shares issued. Refer to the Financial condition section for additional information.

30 | TC Energy Management's discussion and analysis 2024

SUPPLEMENTARY FINANCIAL MEASURE
Net capital expenditures
Net capital expenditures represents capital costs incurred for growth projects, maintenance capital expenditures, contributions to equity investments and projects under development, adjusted for the portion attributed to non-controlling interests in the entities we control. Net capital expenditures reflect capital costs incurred during the period, excluding the impact of timing of cash payments. We use net capital expenditures as a key measure in evaluating our performance in managing our capital spending activities in comparison to our capital plan.
Net capital expenditures does not include an adjustment related to the CFE’s minority interest in TGNH capital expenditures until after the in-service of the projects included as part of the 2022 strategic alliance between TGNH and the CFE, including Villa de Reyes, Southeast Gateway and Tula. The CFE’s contribution in second quarter 2024 to obtain a 13.01 per cent equity interest in TGNH included consideration of its proportionate share of required capital contributions for approved projects. Net capital expenditures will be adjusted for any new capital projects approved in TGNH going forward.
OUTLOOK
Comparable EBITDA and comparable earnings - continuing operations
We expect our 2025 comparable EBITDA to be higher than 2024 comparable EBITDA due to the net impact of the following:
•new projects anticipated to be placed in service in 2025, including the Southeast Gateway pipeline, along with the full-year impact of projects placed in service in 2024
•higher contributions from the NGTL System resulting from the five-year negotiated revenue requirement settlement
•reduced generation from Bruce Power due to the commencement of the Unit 4 Major Component Replacement (MCR) outage.
Our 2025 comparable earnings per common share is expected to be lower than 2024 comparable earnings per common share considering the net impact of the following:
•increase in comparable EBITDA described above
•lower AFUDC due to the Southeast Gateway pipeline expected to be placed in service on May 1, 2025
•lower interest income as a result of lower cash balances and lower interest rates
•increased depreciation rates on the NGTL System related to the five-year negotiated revenue requirement settlement
•reduced capitalized interest due to the Coastal GasLink pipeline commercial in-service
•higher effective tax rates.
Consolidated capital expenditures
In 2024, we incurred approximately $8.2 billion in gross capital expenditures on our secured capital program and projects under development, as well as capitalized interest and AFUDC, where applicable. Net capital expenditures after adjusting for the capital expenditures attributable to the non-controlling interests of entities we control was $7.4 billion.
The majority of our 2025 capital program is focused on the advancement of secured projects including U.S. Natural Gas Pipelines projects, NGTL System expansions, the Southeast Gateway pipeline, Bruce Power MCR programs and normal course maintenance capital expenditures. Prior to adjustments for non-controlling interests, we expect to incur gross capital expenditures of approximately $6.1 to $6.6 billion in 2025. We anticipate our net capital expenditures in 2025 to be approximately $5.5 to $6.0 billion.
Refer to the Outlook section in each business segment for additional details on expected earnings and capital expenditures for 2025.
TC Energy Management's discussion and analysis 2024 | 31

CAPITAL PROGRAM
We are developing quality projects under our capital program. These long-life infrastructure assets are supported by long-term commercial arrangements with creditworthy counterparties and/or regulated business models and are expected to generate growth in earnings and cash flows.
Our capital program consists of approximately $25 billion of secured projects that represent commercially supported, committed projects that are either under construction or are in, or preparing to, commence the permitting stage.
Three years of maintenance capital expenditures for our businesses are included in the Secured projects table. Maintenance capital expenditures on our regulated Canadian and U.S. natural gas pipelines are added to rate base on which we have the opportunity to earn a return and recover these expenditures through current or future tolls, which is similar to our capacity capital projects on these pipelines.
During 2024, we placed approximately $6.8 billion of projects into service, which included natural gas pipeline capacity projects along our extensive North American asset footprint and our share of equity contributions related to the Coastal GasLink pipeline, as well as progress on the Bruce Power life extension program. In addition, approximately $2.3 billion of maintenance capital expenditures were incurred and $0.3 billion of modernization capital expenditures were placed in service.
All projects are subject to cost and timing adjustments due to factors including weather, market conditions, route refinement, land acquisition, permitting conditions, scheduling and timing of regulatory permits, as well as other potential restrictions and uncertainties, including inflationary pressures on labour and materials. Amounts exclude capitalized interest and AFUDC, where applicable.
32 | TC Energy Management's discussion and analysis 2024

Secured projects
Estimated and incurred project costs referred to in the following table include 100 per cent of the capital expenditures related to projects within entities that we own or partially own and fully consolidate, as well as our share of equity contributions to fund projects within our equity investments.
(billions of $)
Expected in-service date
 Estimated project cost
Project costs incurred
at December 31, 2024
Canadian Natural Gas Pipelines1
NGTL System
2026
 0.7 
2
 0.2 
2027+
 0.2 
2
 — 
Regulated maintenance capital expenditures
2025-2027
 2.5  — 
U.S. Natural Gas Pipelines
VR project
2025
 US 0.5  US 0.3 
WR project
2025
 US 0.7  US 0.3 
Heartland project
2027
 US 0.9  US 0.1 
Pulaski and Maysville projects
2029
 US 0.7  — 
Gillis Access – Extension
2026-2027
 US 0.4  US 0.1 
Southeast Virginia Energy Storage project
2030
 US 0.3  — 
Other capital
2025-2028
 US 1.5  US 0.4 
Regulated maintenance capital expenditures
2025-2027
 US 2.3  — 
Mexico Natural Gas Pipelines
Villa de Reyes – South section3
 —  US 0.4  US 0.3 
Tula4
 —  US 0.4  US 0.3 
Southeast Gateway
 2025 US 3.9  US 3.7 
Power and Energy Solutions
Bruce Power – Unit 3 MCR
2026
 1.1  0.9 
Bruce Power – Unit 4 MCR
2028
 0.9  0.2 
Bruce Power – life extension5

2025-2031
 1.8  0.6 
Other
Non-recoverable maintenance capital expenditures6
2025-2027
 0.4  — 
19.6  7.4 
Foreign exchange impact on secured projects7
 5.3  2.4 
Total secured projects (Cdn$) 24.9  9.8 
1Our share of committed equity to fund the estimated cost of the Coastal GasLink - Cedar Link project is $37 million. Refer to the Canadian Natural Gas Pipelines – Significant events section for additional information.
2Includes amounts related to projects within the Multi-Year Growth Plan (MYGP) that have received FID.
3We are working with the CFE on completing the remaining section of the Villa de Reyes pipeline. The in-service date will be determined upon resolution of outstanding stakeholder issues. Refer to the Mexico Natural Gas Pipelines – Significant events section for additional information.
4Estimated project cost as per contracts signed in 2022 as part of the TGNH strategic alliance between TC Energy and the CFE. We continue to evaluate the development and completion of the Tula pipeline, with the CFE, subject to a future FID and an updated cost estimate. Refer to the Mexico Natural Gas Pipelines – Significant events section for additional information.
5Reflects amounts to be invested under the Asset Management program, other life extension projects and the incremental uprate initiative. Refer to the Power and Energy Solutions – Significant events section for additional information.
6Includes non-recoverable maintenance capital expenditures from all segments and is primarily related to our Power and Energy Solutions and Corporate assets.
7Reflects U.S./Canada foreign exchange rate of 1.44 at December 31, 2024.
TC Energy Management's discussion and analysis 2024 | 33

Projects under development
In addition to our secured projects, we are pursuing a portfolio of quality projects in various stages of development across each of our business units. Projects under development have greater uncertainty with respect to timing and estimated project costs and are subject to corporate and regulatory approvals, unless otherwise noted. New growth opportunities will be assessed within our disciplined capital allocation framework in order to fit within our annual capital expenditure parameters. As these new opportunities advance and reach required milestones, they will be included in the Secured projects table.
Canadian Natural Gas Pipelines
We continue to focus on optimizing the utilization and value of our existing Canadian Natural Gas Pipelines assets, including sanctioned in-corridor expansions, providing connectivity to LNG export terminals, connecting growing WCSB gas supplies to domestic and export markets and other opportunities, including progressing our Multi-Year Growth Plan (MYGP). The MYGP is comprised of multiple distinct projects with targeted in-service dates between 2027 and 2030 that are subject to final corporate and regulatory approvals.
U.S. Natural Gas Pipelines
We are currently pursuing a variety of projects that are expected to replace, upgrade, expand and extend our U.S. Natural Gas Pipelines footprint. The enhanced facilities associated with these projects are expected to improve the reliability of our systems, reduce GHG emissions intensity and provide additional transportation capacity under long-term contracts. We continue to see growing demand across multiple segments, driving potential expansion projects to support new natural gas-fired power generation, coal to natural gas conversions, LDC growth and data centres. Our footprint is well positioned to supply natural gas through our existing utility customer base or by way of direct connections. Additional opportunities include RNG through direct interconnects, continued LNG development in proximity to our footprint and LDC peak day growth.
Power and Energy Solutions
Bruce Power
Life Extension Program
The continuation of Bruce Power’s life extension program will require the investment of our proportionate share of both the MCR program costs on Units 5, 7 and 8 and the remaining Asset Management program costs, which continue beyond the completion of the MCR program in 2033, extending the life of Units 3 to 8 and the Bruce Power site to 2064. Preparation work for the Unit 5, 7 and 8 MCRs is underway and future MCR investments will be subject to discrete decisions for each unit with specified off-ramps available to Bruce Power and the IESO. Refer to the Power and Energy Solutions – Significant events section for additional information.
The Unit 5 MCR final cost and schedule estimate was submitted to the IESO on January 31, 2025.
Energy Solutions
Ontario Pumped Storage
With our prospective partners, Saugeen Ojibway Nation, we continue to advance the Ontario Pumped Storage Project, an energy storage facility located in Meaford, Ontario. The 1,000 MW project is expected to provide enough electricity to power one million homes for up to 11 hours, while enhancing the reliability and efficiency of Ontario's electricity system.
Using water and gravity, the project is like a natural battery that will store surplus electricity when demand is low and later redeploy it during periods of high demand. The project will support the planned buildout of Ontario’s nuclear fleet and can deliver Ontario’s clean nuclear power on demand.
34 | TC Energy Management's discussion and analysis 2024

Alberta Carbon Grid
In June 2021, we announced a partnership with Pembina Pipeline Corporation to jointly develop a world-scale system which, when fully constructed, is expected to be capable of transporting and sequestering more than 20 million tonnes of CO2 annually. As an open-access system, the Alberta Carbon Grid (ACG) is intended to serve as the backbone for Alberta’s emerging carbon capture utilization and storage industry. In October 2022, ACG entered into a carbon sequestration evaluation agreement with the Government of Alberta to further evaluate one of the largest Areas of Interest (AOI) for safely storing carbon from industrial emissions in Alberta. ACG continues to progress an appraisal program needed to evaluate the suitability of our AOI, including the advancement and completion of well drilling and testing activities to support the development of a detailed Measurement, Monitoring and Verification plan required to apply for a sequestration permit. We are continuing to advance discussions on a commercial agreement with customers that aligns with our risk preferences.
Other Energy Solutions Projects
Our focus in Energy Solutions includes piloting new technologies like hydrogen and carbon capture for our natural gas business, continued partnerships and investments in emerging technologies and the selective development of decarbonization solutions for customers, allowing us to stay ahead of technological adoption trends. If successful, these technologies are expected to enable us to build capabilities that will allow us to reduce the emissions intensity from our existing assets, which will help enhance and preserve the value of our natural gas networks while also capitalizing on lower-carbon investment opportunities that are underpinned by commercial models that meet our risk preferences.

TC Energy Management's discussion and analysis 2024 | 35

NATURAL GAS PIPELINES BUSINESS
Our natural gas pipeline network transports natural gas from supply basins to local distribution companies, power generation plants, industrial facilities, interconnecting pipelines, LNG export terminals and other businesses across Canada, the U.S. and Mexico. Our network of pipelines taps into most major supply basins and transports over 30 per cent of continental daily natural gas needs through:
•wholly-owned natural gas pipelines – 63,322 km (39,345 miles)
•partially-owned natural gas pipelines – 30,365 km (18,868 miles).
In addition to our natural gas pipelines, we have regulated natural gas storage facilities in the U.S. with a total working gas capacity of 532 Bcf, making us one of the largest providers of natural gas storage and related services to key markets in North America.
Our Natural Gas Pipelines business is split into three operating segments representing its geographic diversity: Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines and Mexico Natural Gas Pipelines.
Strategy
Our strategy is to maximize the value of our existing natural gas pipeline systems in a safe and reliable manner while responding to the changing flow patterns of natural gas in North America. We also pursue new pipeline opportunities to add incremental value to our business.
Our key areas of focus include:
•primarily in-corridor expansion and extension of our existing significant North American natural gas pipeline footprint
•connections to new and growing industrial and electric power generation markets and LDCs
•expanding our systems in key locations in North America and developing new projects to provide connectivity to LNG export terminals, both operating and proposed
•connections to growing Canadian and U.S. shale gas and other supplies
•minimizing our GHG and methane emissions through operational excellence.
Each of these areas plays a critical role in meeting the transportation requirements for supply of and demand for natural gas in North America.
Our natural gas pipeline systems are helping solve the energy trilemma - energy security, affordability and sustainability. We believe natural gas provides a reliable, high-efficiency energy source that is helping to support the displacement of coal-fired power while backstopping the intermittency of renewable power sources across North America. We continue to improve operational efficiencies and factor ESG considerations into our decision making around new projects, modernization, maintenance, electrification and enhanced leak detection. Further, a growing number of RNG customers are connecting to our system. Our business model provides socioeconomic benefits as we work closely with Indigenous communities, community-based organizations, landowners, rights holders and other stakeholders in alignment with our values and sustainability commitments.

36 | TC Energy Management's discussion and analysis 2024

Recent highlights
Canadian Natural Gas Pipelines
•approximately $0.6 billion of capacity capital projects related to the NGTL System were placed into service in 2024
•Coastal GasLink pipeline was declared commercially in service in fourth quarter 2024
•Coastal GasLink LP approved the Cedar Link project in second quarter 2024
•construction activities commenced on the Valhalla North and Berland River (VNBR) project in fourth quarter 2024
•received Board of Directors’ approval to allocate approximately $3.3 billion of capital towards the MYGP for expansion facilities on the NGTL System, subject to final company and regulatory approvals
•achieved record throughput volumes on the NGTL System
•continued strong throughput and contracting on Canadian Mainline
•CER approved a five-year negotiated settlement on the NGTL System (2025-2029 NGTL Settlement).
U.S. Natural Gas Pipelines
•placed approximately US$1.9 billion of capital projects in service in 2024, including the Gillis Access project, Virginia Electrification and GTN XPress projects as well as completion of the Columbia Gas Modernization III program and maintenance capital
•sanctioned US$1.5 billion of capital projects including the Maysville and Pulaski projects on Columbia Gulf, Southeast Virginia Energy Storage project on Columbia Gas and the extension of Gillis Access
•Columbia Gas filed a Section 4 Rate Case with FERC in September 2024 requesting an increase to maximum transportation rates effective April 1, 2025, subject to refund. The rate case is progressing as expected as we continue to pursue a collaborative process through settlement negotiations
•the sale of our 61.7 per cent equity interest in PNGTS was completed on August 15, 2024
•achieved record throughput volumes on a number of our pipelines.
Mexico Natural Gas Pipelines
•the Southeast Gateway pipeline project is progressing according to planned milestones and we continue to be aligned with the CFE on finalizing the remaining project completion activities for achieving an in-service date of May 1, 2025
•the CFE became a partner in TGNH with a 13.01 per cent equity interest in second quarter 2024
•overall pipeline utilization continued to increase.
TC Energy Management's discussion and analysis 2024 | 37

UNDERSTANDING OUR NATURAL GAS PIPELINES BUSINESS
Natural gas pipelines move natural gas from major sources of supply to locations or markets that use natural gas to meet their energy needs.
Our natural gas pipelines business builds, owns and operates a network of natural gas pipelines across North America that connects gas production to interconnects, end-use markets and LNG export terminals. The network includes underground pipelines that transport natural gas predominantly under high pressure, compressor stations that act like pumps to move large volumes of natural gas along the pipeline, meter stations that record the amount of natural gas coming on the network at receipt locations and leaving the network at delivery locations and regulated natural gas storage facilities that provide services to customers and help maintain the overall balance of the pipeline systems.
Our major pipeline systems
The Natural Gas Pipelines map on page 41 shows our extensive pipeline network in North America that connects major supply sources and markets. The highlights shown on the map include:
Canadian Natural Gas Pipelines
NGTL and Foothills System: These are our natural gas gathering and transportation system for the WCSB, connecting most of the natural gas production in western Canada to domestic and export markets. We are well positioned to connect growing supply in northeast British Columbia and northwest Alberta. Our capital program for new pipeline facilities is driven by these two supply areas, along with growing demand for intra-Alberta firm transportation for electric power generation, oil sands development and petro-chemical feedstock, as well as to our major export points at the Empress and Alberta/British Columbia delivery locations. The NGTL System is also well positioned to connect WCSB supply to LNG export facilities on the Canadian west coast through future extensions or expansions of the system or future connections to other pipelines serving that area.
Canadian Mainline: This pipeline supplies markets in the Canadian Prairies, Ontario, Québec, the Canadian Maritimes, as well as to U.S. markets including the Midwest, Gulf Coast and U.S. Northeast from the WCSB and, through interconnects, from the Appalachian basin.
Coastal GasLink: This pipeline supplies WCSB natural gas from interconnections with the NGTL System and other pipelines to the LNG Canada facility on the coast of British Columbia. This pipeline will also feed the Cedar LNG project once built later this decade. We have a 35 per cent equity interest and are the operator of this pipeline.
U.S. Natural Gas Pipelines
Columbia Gas: This is our natural gas transportation system for the Appalachian basin, which contains the Marcellus and Utica shale plays, two of the largest natural gas shale plays in North America. Similar to our footprint in the WCSB, our Columbia Gas assets are well positioned to connect growing supply to markets in this area. This system also interconnects with other pipelines that provide access to key markets in the U.S. Northeast, the Midwest, the Atlantic coast and south to the Gulf of Mexico and its growing demand for natural gas to serve LNG exports. We have a 60 per cent ownership interest and are the operator of this pipeline.
ANR: This pipeline system connects supply basins and markets throughout the U.S. Midwest and south to the Gulf of Mexico. This includes connecting supply in Texas, Oklahoma, the Appalachian basin and the Gulf of Mexico to markets in Wisconsin, Michigan, Illinois and Ohio. In addition, ANR has bidirectional capability on its Southeast Mainline and delivers gas produced from the Appalachian basin to customers throughout the U.S. Gulf Coast region.
Columbia Gulf: This pipeline system transports growing Appalachian basin supplies to various U.S. Gulf Coast markets and LNG export terminals from its interconnections with Columbia Gas and other pipelines. We have a 60 per cent ownership interest and are the operator of this pipeline.
Other U.S. Natural Gas Pipelines: We have ownership interests in nine wholly-owned or partially-owned natural gas pipelines serving major markets in the U.S.
38 | TC Energy Management's discussion and analysis 2024

Mexico Natural Gas Pipelines
Sur de Texas: This offshore pipeline transports natural gas from Texas to power and industrial markets in the eastern and central regions of Mexico. The average volumes transported by this pipeline in 2024 supplied approximately 17 per cent of Mexico's total natural gas imports via pipelines. We have a 60 per cent equity interest and are the operator of this pipeline.
Northwest System: The Topolobampo and Mazatlán pipelines make up our Mexico northwest system. The system runs through the states of Chihuahua and Sinaloa, supplying power plants and industrial facilities, bringing natural gas to a region of the country that previously did not have access to it.
TGNH System: This system is located in the central region of Mexico and is comprised of the Tamazunchale pipeline and the Tula, Villa de Reyes and Southeast Gateway pipelines with sections that are either in-service or currently under construction. This system supplies, or will supply, several power plants and industrial facilities in Campeche, Yucatán, Veracruz, Tabasco, San Luis Potosí, Querétaro and Hidalgo. It has interconnects with upstream pipelines that bring in supply from the Agua Dulce and Waha hubs in Texas. The TGNH System is part of a strategic alliance with the CFE, Mexico’s state-owned electric utility, which holds a 13.01 per cent ownership interest in the system. We have an 86.99 per cent ownership interest and are the operator of these pipelines.
Guadalajara: This bidirectional pipeline connects imported LNG supply near Manzanillo and continental gas supply near Guadalajara to power plants and industrial customers in the states of Colima and Jalisco.
Regulation of tolls and cost recovery
Our natural gas pipelines are generally regulated by the CER in Canada and FERC in the U.S. In Mexico, the regulation of our natural gas pipelines is being transitioned from the CRE to a new regulatory body under the Secretaría de Energía (SENER). These entities regulate the construction, operation and requested abandonment of pipeline infrastructure.
Regulators in Canada, the U.S. and Mexico allow us to recover costs to operate the network by collecting tolls for services. These tolls generally include a return on our capital invested in the assets or rate base, as well as recovery of the rate base over time through depreciation. Other costs generally recovered through tolls include OM&A, taxes and interest on debt. The regulators review our costs to ensure they are reasonable and prudently incurred and approve tolls that provide a reasonable opportunity to recover those costs.
Business environment and strategic priorities
The North American natural gas pipeline network has been developed to connect diverse supply regions to domestic markets and to meet demand from LNG export facilities. Use and growth of this infrastructure is affected by changes in the location and relative cost of natural gas supplies, as well as changes in the location of markets and level of demand.
We have significant pipeline footprints that serve two of the most prolific supply regions of North America – the WCSB and the Appalachian basin. Our pipelines also source natural gas from other significant basins including the Rockies, Williston, Haynesville, Fayetteville and Anadarko basins, as well as the Gulf of Mexico. We expect continued growth in North American natural gas production to meet demand within growing domestic markets, particularly in the electric generation and industrial sectors which benefit from a relatively low natural gas price. In addition, North American supply is expected to benefit from increased natural gas demand in Mexico and growing access to international markets via LNG exports. We expect North American natural gas demand, including LNG exports, of approximately 150 Bcf/d by 2028, reflecting an increase of approximately     28 Bcf/d from 2023 levels.
As the world shifts toward a lower-carbon economy, we believe that further retirements of coal-fired power generation as well as export demand growth over the next five to 10 years will offer growth opportunities for base-load power from natural gas-fired generation. We expect that this projected growth in demand for natural gas, coupled with the anticipated increases in key producing areas like WCSB, onshore Gulf Coast, Appalachian and the Permian basin, will provide investment opportunities for pipeline infrastructure companies to build new facilities or increase utilization of their existing footprint. Modernizing our existing systems and assets and decarbonizing our energy consumption along our natural gas pipeline systems is expected to provide ongoing additional capital investment opportunities that will meet our risk preferences while supporting our GHG emissions intensity reduction goal.
TC Energy Management's discussion and analysis 2024 | 39

Changing demand
The abundant supply of natural gas has supported increased demand, particularly in the following areas:
•natural gas-fired power generation, including for use in emerging data centres
•global LNG exports
•petrochemical and industrial facilities
•Alberta oil sands.
Natural gas producers continue to progress opportunities to sell natural gas to global markets which involves connecting natural gas supplies to LNG export terminals, both operating and proposed, along the U.S. Gulf Coast and the east and west coasts of Canada, the U.S. and Mexico. The increasing export of natural gas to Mexico is driven by the CFE’s need to serve existing markets and requires pipelines to serve new regions. We believe that natural gas is a key energy transition fuel for Mexico.
Overall, we are forecasting significant natural gas demand growth in the future to support economic expansion and industrial load growth, conversion to lower GHG emission-intensive fuels for industrial and power generation use and LNG export prospects. The demand created by these new markets provides additional opportunities for us to build new pipeline infrastructure and to increase throughput on our existing pipelines.
Commodity prices
The profitability of our natural gas pipelines business is not directly tied to commodity prices given we are a transporter of the commodity and the transportation tolls are not tied to the price of natural gas. However, the cyclical supply and demand nature of commodities and related pricing can have an indirect impact on our business where producers may choose to accelerate or delay development of gas reserves or, similarly on the demand side, projects requiring natural gas may be accelerated or delayed depending on market or price conditions.
More competition
Changes in supply and demand levels and locations have resulted in increased competition to provide transportation services throughout North America. Our well-distributed footprint of natural gas pipelines, particularly in the low-cost WCSB and the Appalachian basin, both of which are connected to North American demand centres, has placed us in a strong competitive position. Incumbent pipelines benefit from the connectivity and economies of scale afforded by the base infrastructure, as well as existing right-of-way and operational synergies given the increasing challenges of siting and permitting new pipeline construction and expansions. We have and will continue to offer competitive services to capture growing supply and North American demand that now includes access to global markets through LNG exports.
Strategic priorities
Our pipelines deliver the natural gas that millions of individuals and businesses across North America rely on for their energy needs. We are focused on capturing opportunities resulting from growing natural gas supply and connecting new markets while satisfying increasing demand for natural gas within existing markets. We are also focused on adapting our existing assets to changing natural gas flow dynamics and supporting our corporate-level sustainability commitments and targets.
Our goal is to place all of our projects into service on time and on budget while ensuring the safety of our people, the environment and the general public impacted by the construction and operation of these facilities. In 2025, we will continue to focus on the execution of our existing capital program that includes completing construction on our Southeast Gateway pipeline in Mexico, advancing the Cedar Link project which is an expansion of the Coastal GasLink pipeline, investment in the NGTL System and the initiation and completion of new U.S. pipeline projects. We will remain focused on capital discipline as we continue to pursue the next wave of growth opportunities.
Our marketing entities will complement our natural gas pipeline operations and generate non-regulated revenues by managing the procurement of natural gas supply and pipeline transportation capacity for natural gas customers within our pipeline corridors.
40 | TC Energy Management's discussion and analysis 2024

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TC Energy Management's discussion and analysis 2024 | 41

We are the operator of all of the following natural gas pipelines and regulated natural gas storage assets except for Iroquois.
Length Description
Ownership
Canadian pipelines      
1 NGTL System
24,233 km
(15,058 miles)
Receives, transports and delivers natural gas within Alberta and British Columbia, and connects with Canadian Mainline, Coastal GasLink, Foothills and third-party pipelines.
 100  %
2 Canadian Mainline
14,087 km
(8,753 miles)
Transports natural gas from the Alberta/Saskatchewan border and the Ontario/U.S. border to serve Canadian and U.S. markets.
 100  %
3 Foothills
1,289 km
(801 miles)
 Transports natural gas from central Alberta to the U.S. border for export to the U.S. Midwest, Pacific Northwest, California and Nevada. 100  %
4
Coastal GasLink
671 km
(417 miles)
Transports natural gas from the Montney gas producing region to LNG Canada's liquefaction facility near Kitimat, British Columbia.
 35  %
5 Trans Québec & Maritimes (TQM)
648 km
(403 miles)
Connects with the Canadian Mainline near the Ontario/Québec border to transport natural gas to the Montréal to Québec City corridor and interconnects with a third-party pipeline at the U.S. border.
 50  %
6 Ventures LP
133 km
(83 miles)
 Transports natural gas to the oil sands region near Fort McMurray, Alberta. 100  %
7
Great Lakes Canada
60 km
(37 miles)
 Transports natural gas from the Great Lakes system in the U.S. to a point near Dawn, Ontario through a connection at the U.S. border underneath the St. Clair River. 100  %
U.S. pipelines and gas storage assets      
8 Columbia Gas
18,692 km
(11,615 miles)
 Transports natural gas primarily from the Appalachian basin to markets and pipeline interconnects throughout the U.S. Northeast, Midwest and Atlantic regions. 60  %
8a
 Columbia Storage 285 Bcf
Provides regulated underground natural gas storage service from several facilities (not all shown) to customers in key eastern markets. We own a 60 per cent interest in the 273 Bcf Columbia Storage facility and a 50 per cent interest in the 12 Bcf Hardy Storage facility.
 Various
9
ANR1
 15,075 km
(9,367 miles)		 Transports natural gas from various supply basins to markets throughout the U.S. Midwest and U.S. Gulf Coast. 100  %
9a
 ANR Storage 247 Bcf Provides regulated underground natural gas storage service from several facilities (not all shown) to customers in key mid-western markets.  
10 Columbia Gulf 5,419 km
(3,367 miles)		 Transports natural gas to various markets and pipeline interconnects in the southern U.S. and U.S. Gulf Coast. 60  %
11 Great Lakes 3,404 km
(2,115 miles)		 Connects with the Canadian Mainline near Emerson, Manitoba and to Great Lakes Canada near St Clair, Ontario, plus interconnects with ANR at Crystal Falls and Farwell in Michigan, to transport natural gas to eastern Canada and the U.S. Midwest. 100  %
12 Northern Border 2,272 km
(1,412 miles)		 Transports WCSB, Bakken and Rockies natural gas from connections with Foothills and Bison to U.S. Midwest markets. 50  %
13 Gas Transmission Northwest (GTN)
2,216 km
(1,377 miles)
 Transports WCSB and Rockies natural gas to Washington, Oregon and California. Connects with Tuscarora and Foothills. 100  %
14 Iroquois 669 km
(416 miles)		 Connects with the Canadian Mainline and serves markets in New York. 50  %
15 Tuscarora 491 km
(305 miles)		 Transports natural gas from GTN at Malin, Oregon to markets in northeastern California and northwestern Nevada. 100  %
42 | TC Energy Management's discussion and analysis 2024

Length Description
Ownership
16 Bison 488 km
(303 miles)		 Transports natural gas from the Powder River basin in Wyoming to Northern Border in North Dakota. 100  %
17 Millennium 424 km
(263 miles)
Transports natural gas primarily sourced from the Marcellus shale play to markets across southern New York and the lower Hudson Valley, as well as to New York City through its pipeline interconnections.
 47.5  %
18 Crossroads 325 km
(202 miles)		 Interstate natural gas pipeline operating in Indiana and Ohio with multiple interconnects to other pipelines. 100  %
19
North Baja1
 138 km
(86 miles)		 Transports natural gas between Arizona and California and connects with a third-party pipeline on the California/Mexico border. 100  %
20
Gillis Access
68 km
(42 miles)
A pipeline system that connects supplies from the Haynesville basin at Gillis, Louisiana to markets elsewhere in Louisiana.
100  %
Mexico pipelines
21 Sur de Texas 770 km
(478 miles)		 Offshore pipeline that transports natural gas from the U.S./ Mexican border near Brownsville, Texas, to Mexican power plants in Altamira, Tamaulipas and Tuxpan, Veracruz, where it interconnects with the Tamazunchale and Tula pipelines and other third-party facilities. 60  %
22 Topolobampo 572 km
(355 miles)		 Transports natural gas to El Oro and Topolobampo, Sinaloa, from interconnects with third-party pipelines in El Encino, Chihuahua and El Oro. 100  %
23 Mazatlán 430 km
(267 miles)
Transports natural gas from El Oro to Mazatlán, Sinaloa, interconnects with third-party pipelines and connects to the Topolobampo pipeline at El Oro.
 100  %
24 Tamazunchale 370 km
(230 miles)
Transports natural gas from Naranjos, Veracruz and Higueros (Sur de Texas-Tuxpan System) to Tamazunchale, San Luis Potosi and on to El Sauz, Querétaro in central Mexico.
 86.99  %
25
Villa de Reyes – North and Lateral sections
316 km
(196 miles)
 The north and lateral sections of the Villa de Reyes pipeline are interconnected to our Tamazunchale pipeline and third-party systems, supporting gas deliveries to power plants in Villa de Reyes, San Luis Potosí and Salamanca, Guanajuato. 86.99  %
26 Guadalajara 313 km
(194 miles)		 Bidirectional pipeline that connects imported LNG supply near Manzanillo and continental gas supply near Guadalajara to power plants and industrial customers in the states of Colima and Jalisco. 100  %
27
Tula – East section
 114 km
(71 miles)		 The east section of the Tula pipeline transports natural gas from Sur de Texas to power plants in Tuxpan, Veracruz. 86.99  %
Under construction
Canadian pipelines
NGTL System 2025+ Facilities2,3
50 km
(31 miles)
The VNBR project, along with other facilities expected to be placed in service in 2026.
 100  %
Coastal GasLink – Cedar Link project2,3
n/a
The Cedar Link project is an expansion of the Coastal GasLink pipeline that is expected to enable delivery of up to 0.4 Bcf/d of natural gas to the Cedar LNG facility. This includes the addition of a new compressor station, connector pipeline and meter station to Coastal GasLink's existing pipeline infrastructure, which is expected to be placed in service in 2028.
 35  %
TC Energy Management's discussion and analysis 2024 | 43

Under construction (continued) Length Description Ownership
U.S. pipelines
East Lateral XPress1,2
 n/a An expansion project on Columbia Gulf through compressor station modifications and additions expected to be placed in service in 2025. 60  %
VR Project1,2
 n/a
A delivery market project on Columbia Gas that will replace and upgrade certain facilities while improving reliability and reducing emissions, which is expected to be placed in service in 2025.
 60  %
WR Project1,2
 n/a
A delivery market project on ANR that will replace and upgrade certain facilities while improving reliability and reducing emissions, which is expected to be placed in service in 2025.
 100  %
Ventura XPress Project1,2
 n/a
A project on ANR that will replace and upgrade certain facilities improving base system reliability, which is expected to be placed in service in 2025.
 100  %
Mexico pipelines
28 Southeast Gateway 715 km
(444 miles)
Offshore pipeline that will connect to the Tula pipeline and transport gas to delivery points in Coatzacoalcos, Veracruz and Paraíso, Tabasco in Mexico’s southeast region, which is expected to be placed in service on May 1, 2025.
 86.99  %
29
Villa de Reyes – South section
110 km
(68 miles)
This pipeline section will connect to the operational north and lateral sections of the Villa de Reyes pipeline and to the Tula pipeline.
86.99  %
Permitting and pre-construction phase
Canadian pipelines
NGTL System – MYGP2,3,4
n/a
A plan of multiple distinct projects for expansion facilities on the NGTL System with targeted in-service dates between 2027 and 2030.
 100  %
U.S. pipelines
Bison XPress Project1,2
n/a
A project with Northern Border, a 50 per cent owned subsidiary, and Bison, a wholly-owned subsidiary, that will replace and upgrade certain facilities while improving reliability, which is expected to be placed in service in 2026.
 Various
Heartland Project1,2
 n/a
An expansion project on ANR that will increase capacity and improve system reliability with upgrades to compression facilities, expected to be placed in service in 2027.
 100  %
Gillis Access – Extension2,3
 63 km
(39 miles)
An extension of Gillis Access to further connect supplies from Haynesville basin at Gillis with anticipated in-service dates starting in late 2026.
 100  %
Pulaski Project2,3
64 km
(40 miles)
A pipeline extension project on Columbia Gulf designed to serve existing power plants. The project is expected to be placed in service in 2029.
 60  %
Maysville Project2,3
64 km
(40 miles)
A pipeline extension project on Columbia Gulf designed to serve existing power plants. The project is expected to be placed in service in 2029.
 60  %
Southeast Virginia Energy Storage Project2
1.1 Bcf
An LNG storage facility located on our Columbia Gas system in southeast Virginia designed to serve an existing LDC's growing market. The project is expected to be placed in service in 2030.
 60  %

44 | TC Energy Management's discussion and analysis 2024


Permitting and pre-construction phase (continued)
Length
Description
Ownership
Mexico pipelines
30
Tula3
100 km
(62 miles)
TC Energy and the CFE are assessing options to complete the remaining sections of the pipeline, which are subject to an FID.
 86.99  %
1Includes compressor station modifications, additions and/or expansion projects with no additional pipe length.
2Facilities and some pipelines are not shown on the map.
3Final pipe lengths are subject to change during construction and/or final design considerations.
4Includes projects within the MYGP that have received FID.
TC Energy Management's discussion and analysis 2024 | 45

Canadian Natural Gas Pipelines
UNDERSTANDING OUR CANADIAN NATURAL GAS PIPELINES SEGMENT
The Canadian Natural Gas Pipelines business is subject to regulation by various federal and provincial governmental agencies. The CER has jurisdiction over our regulated Canadian natural gas interprovincial pipeline systems, while provincial regulators have jurisdiction over pipeline systems operating entirely within a single province. All of our major Canadian natural gas pipeline assets are regulated by the CER with the exception of the Coastal GasLink pipeline, which was declared commercially in service in fourth quarter 2024 and is regulated by the BC Energy Regulator (formerly the BC Oil & Gas Commission).
For the interprovincial natural gas pipelines it regulates, the CER approves tolls, facilities and services that are in the public interest and provide a reasonable opportunity for the pipeline to recover its costs to operate the pipeline. Included in the overall toll is a return on the investment we have made in the assets, referred to as the return on equity. Equity is generally 40 per cent of the deemed capital structure, with the remaining 60 per cent debt. Typically, tolls are based on the cost of providing service, including the cost of financing, divided by a forecast of volumes. Any variance in either costs or the actual volumes transported can result in an over-collection or under-collection of revenues that is normally trued up the following year in the calculation of the tolls for that period. The return on equity, however, would continue to be earned at the rate approved by the CER.
Subject to approval by the CER, we and our customers can also establish settlement arrangements that may have elements that vary from the typical toll-setting process. Settlements can include longer terms and mechanisms such as incentive agreements that can have an impact on the actual return on equity achieved. Examples include fixing the OM&A component in determining revenue requirements where variances are to the pipeline's account or shared between the pipeline and shippers.
The NGTL System operated under the previous five-year revenue requirement settlement for 2020-2024, which included an incentive mechanism for certain operating costs and the opportunity to increase depreciation rates if tolls fall below specified levels. As of January 1, 2025, the NGTL System is operating under a new five-year revenue requirement settlement. Refer to the Canadian Natural Gas Pipelines – Significant events section for additional information. The Canadian Mainline is operating under the 2021-2026 Mainline settlement, which includes an incentive to decrease costs and increase revenues.
SIGNIFICANT EVENTS
NGTL System
In the year ended December 31, 2024, the NGTL System placed approximately $0.6 billion of capacity projects in service.
2023 NGTL System Intra-Basin Expansion
The NGTL System Intra-Basin Expansion consists of 23 km (14 miles) of new pipeline and two new compressor stations. All assets have been placed in service, with a capital cost for the expansion of $0.5 billion.
NGTL System Revenue Requirement Settlement and Multi-Year Growth Plan
On September 26, 2024, the CER approved a five-year negotiated revenue requirement settlement on the NGTL System (2025-2029 NGTL Settlement) commencing on January 1, 2025.
The 2025-2029 NGTL Settlement enables an investment framework that supports our Board of Directors' approval to allocate approximately $3.3 billion of capital towards progression of the MYGP for expansion facilities on the NGTL System. It is comprised of multiple distinct projects with targeted in-service dates between 2027 and 2030, subject to final company and regulatory approvals. The completion of the MYGP is expected to enable approximately 1.0 Bcf/d of incremental system throughput.
This settlement maintains an ROE of 10.1 per cent on 40 per cent deemed common equity while increasing NGTL System depreciation rates, with an incentive that allows the NGTL System the opportunity to further increase depreciation rates if tolls fall below specified levels, or if growth projects are undertaken. It also introduces a new incentive mechanism to reduce both physical emissions and emissions compliance costs, which builds on the incentive mechanism for certain operating costs where variances from projected amounts and emissions savings are shared with our customers. A provision for review by customers exists in the settlement if tolls exceed a pre-determined level or if final company approvals of the MYGP are not obtained.
Sale of Equity Interest in the NGTL System and Foothills Pipeline Assets
The previously announced equity interest purchase agreement in respect of the sale by TC Energy of a 5.34 per cent interest in the NGTL System and Foothills Pipeline assets to an Indigenous-owned investment partnership was terminated by TC Energy on February 6, 2025.
46 | TC Energy Management's discussion and analysis 2024

Valhalla North and Berland River Project
The VNBR project will serve aggregate system requirements and connect migrating supply to key demand markets, designed to provide incremental capacity on the NGTL System of approximately 428 TJ/d (400 MMcf/d). With an estimated capital cost of $0.5 billion, the project consists of approximately 33 km (21 miles) of new pipeline, one new non-emitting electric compressor unit and associated facilities. Construction activities commenced in late 2024 with anticipated in-service dates commencing in second quarter 2026.
Coastal GasLink
Coastal GasLink Pipeline
The Coastal GasLink pipeline is a 671 km (417 mile) pipeline that transports natural gas from a receipt point in the Dawson Creek area of British Columbia to LNG Canada's (LNGC) natural gas liquefaction facility near Kitimat, B.C. Transportation service on the pipeline is underpinned by 25-year TSAs (with renewal provisions) with each of the five LNGC participants (LNGC Participants). We hold a 35 per cent ownership interest in Coastal GasLink LP, the entity that owns the Coastal GasLink pipeline. Additionally, we hold a 100 per cent ownership interest in the general partner of Coastal GasLink LP, the entity that is contracted to develop, construct and operate the pipeline.
The Coastal GasLink pipeline project achieved mechanical completion in 2023 and began delivering commissioning gas to the LNGC facility in late third quarter 2024. Post-construction reclamation activities are expected to be complete in 2025 and the project remains on track with its capital cost estimate of approximately $14.5 billion.
Coastal GasLink LP continues to pursue cost recovery, including certain arbitration proceedings which involve claims by, and the defense of certain claims against, Coastal GasLink LP. With the exception of settlements made with respect to certain contractor disputes, these claims have not yet been conclusively determined, but our expectation is that these proceedings are likely to result in net cost recoveries. Refer to Note 31, Commitments, contingencies and guarantees, of our 2024 Consolidated financial statements for additional information.
In June 2024, Coastal GasLink LP successfully completed a $7.15 billion refinancing of its existing construction credit facility through a private placement bond offering of senior secured notes to Canadian and U.S. investors. Proceeds from the offering were used to repay the majority of the outstanding $8.0 billion balance on Coastal GasLink LP’s construction credit facility. The remaining balance on the credit facility was settled through the use of proceeds from the unwinding of certain hedging arrangements associated with the construction facility.
In November 2024, Coastal GasLink LP executed a commercial agreement with LNGC and LNGC Participants that declared commercial in-service for the pipeline, allowing for the collection of tolls from customers retroactive to October 1, 2024. The agreement also includes a one-time payment of $199 million from LNGC Participants to TC Energy in recognition of the completion of certain work and the final settlement of costs. The payment is to be made by LNGC Participants upon the earlier of three months after the declared in-service of the LNGC facility, or December 15, 2025. The payment accrues in full to TC Energy in accordance with the contractual terms between the Coastal GasLink LP partners and has been accounted for as an         in-substance distribution from Coastal GasLink LP.
In December 2024, following the commercial in-service of the pipeline, Coastal GasLink LP repaid the $3,147 million balance owing to TC Energy under the subordinated loan agreement. Our share of equity contributions required by Coastal GasLink LP to fund repayment of the loan amounted to $3,137 million. At December 31, 2024, our total share of partner equity contributions to fund the capital cost of the project was $5.3 billion. While unused capacity of $228 million remains available under the subordinated loan agreement, we do not anticipate that Coastal GasLink LP will draw on a significant portion of the remaining availability.
TC Energy Management's discussion and analysis 2024 | 47

Cedar Link Expansion
In June 2024, Coastal GasLink LP sanctioned the Cedar Link project following a positive FID for the construction of the Cedar LNG facility by the Cedar LNG joint venture partners, Haisla Nation and Pembina Pipeline Corporation. The Cedar LNG facility is a proposed floating liquefied natural gas facility to be constructed in Kitimat, British Columbia. The Cedar Link project is an expansion of the Coastal GasLink pipeline that is expected to enable delivery of up to 0.4 Bcf/d of natural gas to the Cedar LNG facility. With an estimated cost of $1.2 billion, the expansion project includes the addition of a new compressor station, connector pipeline and meter station to the existing Coastal GasLink pipeline infrastructure.
Funding for the expansion will be provided through project-level credit facilities of up to $1.4 billion secured by Coastal GasLink LP in June 2024, equity funding to be provided by Coastal GasLink LP partners, including us, and the recovery of construction carrying costs from LNGC Participants who have elected to make payments on a quarterly basis throughout construction. The incremental funds available through the project-level credit facilities and recovery of carrying charges provide additional contingency to mitigate future funding requirements for Coastal GasLink LP should costs exceed initial estimates of $1.2 billion. TC Energy has entered into an equity contribution agreement to fund up to a maximum of $37 million for its proportionate share of the equity requirements related to the Cedar Link project.
All major regulatory permits have been received and construction began in July 2024. The planned in-service date for the Cedar Link project is 2028, subject to the completion of plant commissioning activities at the Cedar LNG facility.
Indigenous Equity Option
In March 2022, we announced the signing of option agreements to sell up to a 10 per cent equity interest in Coastal GasLink LP to Indigenous communities across the project corridor, from our current 35 per cent equity ownership. The equity option is exercisable after commercial in-service of the Coastal GasLink pipeline, subject to customary regulatory approvals and consents, including the consent of LNGC. As a result of the commercial agreement with LNGC and LNGC Participants, which has allowed for an earlier commercial in-service than the LNGC plant, we are actively collaborating with the Indigenous communities to establish a mutually agreeable timeframe in which the option can be exercised.
48 | TC Energy Management's discussion and analysis 2024

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA and comparable EBIT (our non-GAAP measures) to segmented earnings (losses)(the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of $) 2024 2023 2022
NGTL System 2,393  2,201  1,853 
Canadian Mainline 787  789  770 
Other Canadian pipelines1
 208  345  183 
Comparable EBITDA 3,388  3,335  2,806 
Depreciation and amortization (1,382) (1,325) (1,198)
Comparable EBIT 2,006  2,010  1,608 
Specific items:
Gain on sale of non-core assets 10  —  — 
Coastal GasLink impairment charge —  (2,100) (3,048)
Segmented earnings (losses)
 2,016  (90) (1,440)
1Includes results from Foothills, Ventures LP, Great Lakes Canada and our proportionate share of income related to investments in TQM and Coastal GasLink, as well as general and administrative and business development costs related to our Canadian Natural Gas Pipelines.
In 2024, Canadian Natural Gas Pipelines segmented earnings were $2.0 billion compared to segmented losses of $0.1 billion and $1.4 billion in 2023 and 2022, respectively, and included the following specific items, which have been excluded from our calculation of comparable EBITDA and comparable EBIT:
•a pre-tax gain on sale of non-core assets of $10 million in second quarter 2024
•a pre-tax impairment charge in 2023 of $2.1 billion (2022 – $3.0 billion) related to our equity investment in Coastal GasLink LP. Refer to Note 7, Coastal GasLink, of our 2024 Consolidated financial statements for additional information.
Net income and comparable EBITDA for our rate-regulated Canadian natural gas pipelines are primarily affected by our approved ROE, investment base, the level of deemed common equity and incentive earnings. Changes in depreciation, financial charges and income taxes also impact comparable EBITDA, but do not have a significant impact on net income as they are almost entirely recovered in revenues on a flow-through basis.
Net income and average investment base
year ended December 31
(millions of $) 2024 2023 2022
Net income
  NGTL System 775  770  708 
  Canadian Mainline 244  230  223 
Average investment base
  NGTL System 19,334  19,008  17,493 
  Canadian Mainline 3,697  3,709  3,735 
TC Energy Management's discussion and analysis 2024 | 49

Net income for the NGTL System increased by $5 million in 2024 compared to 2023 and increased by $62 million in 2023 compared to 2022 mainly due to a higher average investment base resulting from continued system expansions, partially offset by an incentive loss. The NGTL System was operating under the 2020-2024 Revenue Requirement Settlement, which included an approved ROE of 10.1 per cent on 40 per cent deemed common equity. This settlement provided the NGTL System the opportunity to increase depreciation rates if tolls fall below specified levels and an incentive mechanism for certain operating costs where variances from projected amounts are shared with our customers. Refer to the Canadian Natural Gas Pipelines - Significant events section for additional information on the 2025 - 2029 NGTL Settlement.
Net income for the Canadian Mainline increased by $14 million in 2024 compared to 2023 and increased by $7 million in 2023 compared to 2022 mainly as a result of higher incentive earnings. The Canadian Mainline is operating under the 2021-2026 Mainline Settlement, which includes an approved ROE of 10.1 per cent on 40 per cent deemed common equity and an incentive to decrease costs and increase revenues on the pipeline under a beneficial sharing mechanism with our customers.
Comparable EBITDA
Comparable EBITDA for Canadian Natural Gas Pipelines was $53 million higher in 2024 compared to 2023 primarily due to the net effect of:
•higher flow-through income taxes, depreciation and financial charges, as well as higher rate-base earnings on the NGTL System due to continued system expansions
•higher flow-through income taxes, financial charges and depreciation, as well as higher rate-base earnings on Foothills primarily due to the NGTL System/Foothills West Path Delivery Program completed in 2023
•earnings from Coastal GasLink in 2023 related to the recognition of a $200 million incentive payment upon meeting certain milestones.
Comparable EBITDA for Canadian Natural Gas Pipelines in 2023 was $529 million higher than 2022 primarily due to the net effect of:
•higher flow-through financial charges, depreciation and income taxes, as well as higher rate-base earnings on the NGTL System
•earnings from Coastal GasLink related to the recognition of a $200 million incentive payment upon meeting certain milestones, partially offset by lower development fee revenue resulting from timing of revenue recognition
•higher flow-through depreciation, financial charges and higher incentive earnings, partially offset by lower flow-through income taxes on the Canadian Mainline.
Depreciation and amortization
Depreciation and amortization was $57 million higher in 2024 compared to 2023, primarily reflecting    incremental depreciation on the NGTL System from expansion facilities that were placed in service. Depreciation and amortization was $127 million higher in 2023 compared to 2022 due to higher depreciation on the NGTL System from expansion facilities that were placed in service and on the Canadian Mainline due to assets placed in service on a section with higher depreciation rates per the terms of the 2021-2026 Mainline Settlement.
50 | TC Energy Management's discussion and analysis 2024

OUTLOOK
Comparable EBITDA and comparable earnings
Net income for Canadian rate-regulated pipelines is affected by changes in investment base, ROE and deemed capital structure, as well as by the terms of toll settlements approved by the CER. Under the current regulatory model, earnings from Canadian rate-regulated natural gas pipelines are not materially affected by short-term fluctuations in the commodity price of natural gas, changes in throughput volumes or changes in contracted capacity levels.
Canadian Natural Gas Pipelines comparable EBITDA in 2025 is expected to be higher than 2024 mainly due to higher contributions from the NGTL System resulting from the 2025-2029 NGTL Settlement. Due to the flow-through treatment of certain costs on our Canadian rate-regulated pipelines, changes in these costs can impact our comparable EBITDA despite having no significant effect on comparable earnings. We expect our comparable earnings in 2025 for the NGTL System and the Canadian Mainline to be consistent with 2024.
Capital expenditures
We incurred $1.3 billion of capital expenditures in 2024 in our Canadian Natural Gas Pipelines business on growth projects and maintenance capital expenditures. We expect to incur approximately $1.3 billion in 2025, primarily on NGTL System expansion projects and maintenance capital expenditures, all of which are immediately reflected in investment base and related earnings.
We also made a net contribution of $0.6 billion to our investment in Coastal GasLink LP in 2024, which was declared commercially in service in fourth quarter 2024. Significant equity contributions are not anticipated in 2025.
TC Energy Management's discussion and analysis 2024 | 51

U.S. Natural Gas Pipelines
UNDERSTANDING OUR U.S. NATURAL GAS PIPELINES SEGMENT
The U.S. interstate natural gas pipeline business is subject to regulation by various federal, state and local governmental agencies. FERC, however, has comprehensive jurisdiction over our U.S. interstate natural gas business. FERC approves maximum transportation rates that are cost-based and are designed to recover the pipeline's investment, operating expenses and a reasonable return for our investors. In the U.S., we have the ability to contract for negotiated or discounted rates with shippers.
FERC does not require U.S. interstate pipelines to calculate rates annually, nor do they generally allow for the collection or refund of the variance between actual and expected revenues and costs into future years. This difference in U.S. regulation from the Canadian regulatory environment puts our U.S. pipelines at risk for the difference in expected and actual costs and revenues between rate cases. If revenues no longer provide a reasonable opportunity to recover our costs, we can file with FERC for a new determination of rates, subject to any moratorium in effect. Similarly, FERC or our shippers may institute proceedings to lower rates if they consider the return on capital invested to be unjust or unreasonable.
Similar to Canada, we can also establish settlement arrangements with our U.S. shippers that are ultimately subject to approval by FERC. Rate case moratoriums for a period of time, before either we or the shippers can file for a rate review, are common for a settlement in that they provide some certainty for shippers in terms of rates, eliminate the costs associated with frequent rate proceedings for all parties and can provide an incentive for pipelines to lower costs.
PHMSA Pipeline Safety Regulations
Most of our U.S. natural gas pipeline systems are subject to federal pipeline safety statutes and regulations enacted and administered by PHMSA. PHMSA has recently and will continue to, produce new rules affecting numerous aspects of operation and maintenance of our pipeline system. PHMSA’s priorities are generally dictated by legislation which is influenced by numerous stakeholders and informed by learnings from recent industry incidents and stakeholder priorities. When PHMSA implements new rules, TC Energy seeks recovery of additional expenditures driven by such rules in future rate cases and modernization settlements.
SIGNIFICANT EVENTS
Portland Natural Gas Transmission System
On March 4, 2024, we announced that TC Energy and its partner Northern New England Investment Company, Inc., a subsidiary of Énergir, entered into a purchase and sale agreement to sell PNGTS to BlackRock, through a fund managed by its Diversified Infrastructure business, and investment funds managed by Morgan Stanley Infrastructure Partners (the Purchaser). On         August 15, 2024, we completed the sale of PNGTS for a gross purchase price of approximately $1.6 billion (US$1.1 billion), which included US$250 million of senior notes outstanding held at PNGTS and assumed by the Purchaser. A pre-tax gain of $572 million (US$408 million) and an after-tax gain of $456 million (US$323 million) were recognized for the year ended December 31, 2024. We are providing customary transition services and will continue to work jointly with the Purchaser to facilitate the safe and orderly transition of this natural gas system. Refer to Note 30, Strategic alliance, acquisitions and dispositions, of our 2024 Consolidated financial statements for additional information.
Gillis Access Project
In March 2024, the Gillis Access project, a 68 km (42 mile) greenfield pipeline system that connects gas production sourced from the Gillis hub to downstream markets in southeast Louisiana, was placed in service. The capital cost of this project was approximately US$0.3 billion.
In February 2023, we approved the 63 km (39 mile), 1.4 Bcf/d extension of the Gillis Access project to further connect supplies from Haynesville basin at Gillis. Effective September 1, 2024, all remaining shipper conditions have expired and the project expanded to 1.9 Bcf/d. The project has anticipated in-service dates starting in late 2026 and total estimated costs of         US$0.4 billion.
Columbia Gas Section 4 Rate Case
In September 2024, Columbia Gas filed a Section 4 Rate Case with FERC requesting an increase to the maximum transportation rates expected to become effective April 1, 2025, subject to refund. We will pursue a collaborative process to find a mutually beneficial outcome with our customers through settlement.
52 | TC Energy Management's discussion and analysis 2024

Southeast Virginia Energy Storage Project
In November 2024, we approved the US$0.3 billion Southeast Virginia Energy Storage Project. This is an LNG peaking facility in southeast Virginia that will serve an existing LDC's growing winter peak day load and mitigate its peak day pricing exposure, as well as increase operational flexibility on the Columbia Gas system. The project has an anticipated in-service date of 2030.
Pulaski and Maysville Projects
In November 2024, we approved the Pulaski and Maysville projects on our Columbia Gulf System. These mainline extension projects off Columbia Gulf will facilitate full coal-to-gas conversion at two existing power plants and are each expected to provide 0.2 Bcf/d of capacity for incremental gas-fired generation. The projects have anticipated in-service dates in 2029 and total estimated costs of US$0.7 billion.
GTN XPress Project
In December 2024, the GTN XPress project, an expansion of the GTN system that will provide for the transport of incremental contracted export capacity facilitated by the NGTL System/Foothills West Path Delivery Program, was placed in service. The capital cost of this project was approximately US$0.1 billion.
TC Energy Management's discussion and analysis 2024 | 53

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA and comparable EBIT (our non-GAAP measures) to segmented earnings (losses) (the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of US$, unless otherwise noted) 2024 2023 2022
Columbia Gas1
 1,600  1,530  1,511 
ANR 642  650  582 
Columbia Gulf1
 235  208  207 
Great Lakes
 204  183  178 
GTN
 188  202  184 
PNGTS1,2
 66  104  101 
Other U.S. pipelines3
 359  371  379 
Comparable EBITDA 3,294  3,248  3,142 
Depreciation and amortization (697) (692) (681)
Comparable EBIT 2,597  2,556  2,461 
Foreign exchange impact 959  895  742 
Comparable EBIT (Cdn$)
 3,556  3,451  3,203 
Specific items:
Gain on sale of PNGTS 572  —  — 
Gain on sale of non-core assets 38  —  — 
Great Lakes goodwill impairment charge —  —  (571)
Risk management activities (113) 80  (15)
Segmented earnings (losses) (Cdn$)
 4,053  3,531  2,617 
1Includes non-controlling interest. Refer to the Corporate - Financial results section for additional information.
2The sale of PNGTS was completed on August 15, 2024. Refer to the U.S. Natural Gas Pipelines – Significant events section for additional information.
3Reflects comparable EBITDA from our ownership in our mineral rights business (CEVCO), North Baja, Gillis Access, Tuscarora, Bison, Crossroads and our share of equity income from Northern Border, Iroquois, Millennium and Hardy Storage, our U.S. natural gas marketing business, as well as general and administrative and business development costs related to our U.S. natural gas pipelines.
U.S. Natural Gas Pipelines segmented earnings in 2024 increased by $522 million compared to 2023 and increased by $914 million in 2023 compared to 2022 and included the following specific items, which have been excluded from our calculation of comparable EBITDA and comparable EBIT:
•a pre-tax gain of $572 million related to the sale of PNGTS on August 15, 2024
•a pre-tax gain on sale of a non-core asset of $38 million in second quarter 2024
•a pre-tax goodwill impairment charge of $571 million related to Great Lakes in first quarter 2022
•unrealized gains and losses from changes in the fair value of derivatives used in our U.S. natural gas marketing business.
A stronger U.S. dollar in 2024 and 2023 had a positive impact on the Canadian dollar equivalent segmented earnings from our U.S. dollar-denominated operations. Refer to the Foreign exchange section for additional information.
Earnings from our U.S. Natural Gas Pipelines operations are generally affected by contracted volume levels, volumes delivered and the rates charged, as well as by the cost of providing services. Columbia Gas and ANR results are also affected by the contracting and pricing of their natural gas storage capacity and incidental commodity sales. Natural gas pipeline and storage volumes and revenues are generally higher in the winter months because of the seasonal nature of the business.
54 | TC Energy Management's discussion and analysis 2024

Comparable EBITDA for U.S. Natural Gas Pipelines was US$46 million higher in 2024 than 2023 primarily due to the net effect of:
•incremental earnings from growth and modernization projects placed in service, as well as increased earnings from additional contract sales on ANR and Great Lakes
•increased equity earnings from Northern Border
•decreased earnings due to higher operational costs, reflective of increased system utilization across our footprint
•decreased earnings as a result of the sale of our 61.7 per cent equity interest in PNGTS, which was completed on     August 15, 2024
•lower realized earnings related to our U.S. natural gas marketing business primarily due to lower margins
•reduced earnings from our mineral rights business due to lower commodity prices.
Comparable EBITDA for U.S. Natural Gas Pipelines was US$106 million higher in 2023 than 2022 primarily due to the net effect of:
•incremental earnings from growth and modernization projects placed in service and additional contract sales on Columbia Gas, ANR and Great Lakes
•a net increase in earnings from ANR following the FERC-approved settlement for higher transportation rates effective August 2022, partially offset by decreased earnings due to the sale of natural gas from certain gas storage facilities in 2022
•higher realized earnings related to our U.S. natural gas marketing business primarily due to higher margins
•increased equity earnings from Iroquois and Northern Border
•decreased earnings due to higher operational costs, reflective of increased system utilization across our footprint, as well as higher property taxes related to projects in service
•reduced earnings from our mineral rights business due to lower commodity prices.
Depreciation and amortization
Depreciation and amortization was US$5 million higher in 2024 compared to 2023 and US$11 million higher in 2023 compared to 2022. The increase in depreciation is primarily due to new projects placed in service, partially offset by the impact of the sale of PNGTS in 2024.
OUTLOOK
Comparable EBITDA
Our U.S. natural gas pipelines are largely backed by long-term take-or-pay contracts that are expected to deliver stable and consistent financial performance. Our ability to retain customers and recontract or sell capacity at favourable rates is influenced by prevailing market conditions and competitive factors, including alternatives available to end-use customers in the form of competing natural gas pipelines and supply sources, as well as broader conditions that impact demand from certain customers or market segments. Comparable EBITDA is also affected by operational and other costs, which can be impacted by safety, environmental and other regulatory decisions, as well as customer credit risk.
U.S. Natural Gas Pipelines comparable EBITDA in 2025 is expected to be slightly higher than 2024 due to an anticipated increase in transportation rates on Columbia Gas, which is dependent on the outcome of the Section 4 Rate Case filed with FERC. In addition, revenues are expected to increase following the completion of expansion projects in 2025 on the Columbia Gas, Columbia Gulf and ANR systems, as well as full year in-service of the Gillis Access project. Our pipeline systems continue to see historically strong demand for service and we anticipate that during 2025, our assets will maintain the high utilization levels experienced in 2024. These positive results are expected to be partially offset by higher operational costs, reflective of continued increases to system utilization across our footprint, the impact of the sale of our 61.7 per cent equity interest in PNGTS in 2024 and an anticipated increase in property taxes from capital projects placed in service.
Capital expenditures
We incurred a total of US$2.2 billion of capital expenditures in 2024 on our U.S. natural gas pipelines and expect to incur approximately US$2.5 billion in 2025 primarily on our Columbia Gas, ANR and Columbia Gulf expansion projects and Bison XPress equity contributions, as well as Columbia Gas and ANR maintenance capital expenditures, the return on and recovery of which, is expected to be reflected in future tolls. We expect net capital expenditures in 2025 to be approximately US$2.0 billion after considering capital expenditures attributable to the non-controlling interests of entities we control.
TC Energy Management's discussion and analysis 2024 | 55

Mexico Natural Gas Pipelines
UNDERSTANDING OUR MEXICO NATURAL GAS PIPELINES SEGMENT
For over a decade, Mexico has been undergoing a significant transition from fuel oil and diesel as its primary energy sources for electric generation to using natural gas. As a result, new natural gas pipeline infrastructure has been and continues to be required to meet the growing demand for natural gas. The CFE, Mexico's state-owned electric utility, is the primary counterparty on all of our existing pipelines under long-term contracts, which are predominately denominated in U.S. dollars. These fixed-rate contracts are generally designed to recover the cost of service and provide a return on and of invested capital. As the pipeline developer and operator, we are generally at risk for operating and construction costs. Our Mexico pipelines also have regulatory approved tariffs, services and related rates for other potential users.
SIGNIFICANT EVENTS
TGNH
Strategic Alliance with the CFE
In August 2022, we announced a strategic alliance with Mexico’s state-owned electric utility, the CFE, for the development of new natural gas infrastructure in central and southeast Mexico. In connection with the strategic alliance, we reached an FID to develop and construct the Southeast Gateway pipeline, a 1.3 Bcf/d, 715 km (444 mile) offshore natural gas pipeline to serve the southeast region of Mexico. We continue to be aligned with the CFE on finalizing the remaining project completion activities for achieving an in-service date of May 1, 2025. The estimated project cost for the Southeast Gateway pipeline is approximately US$3.9 billion, which is lower than the initial cost estimate of US$4.5 billion.
During second quarter 2024, upon the CFE’s equity injection of US$340 million as well as non-cash consideration in recognition of the completion of certain contractual obligations, including land acquisition and permitting support, the CFE became a partner in TGNH with a 13.01 per cent equity interest. Provided that the CFE's contractual commitments are met related to land acquisition, community relations and permitting support, the CFE's equity in TGNH would build up to a maximum of 15 per cent with the in-service of the Southeast Gateway pipeline and will increase to approximately 35 per cent upon expiry of the contract in 2055. Refer to Note 30, Strategic alliance, acquisitions and dispositions, of our Consolidated financial statements for additional information.
Tula
In third quarter 2022, we placed the east section of the Tula pipeline into commercial service and we reached an agreement with the CFE to jointly develop and complete the remaining segments of the Tula pipeline, with the central segment subject to an FID. Due to the delay of an FID, recording AFUDC on the assets under construction for the Tula pipeline project was suspended in late 2023.
Villa de Reyes
We placed the north and lateral sections of the Villa de Reyes pipeline into commercial service in third quarter 2022 and third quarter 2023, respectively. We continue to work with our partner, the CFE, to complete the south section of the Villa de Reyes pipeline. The in-service date will be determined upon resolution of outstanding stakeholder issues.
56 | TC Energy Management's discussion and analysis 2024

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA and comparable EBIT (our non-GAAP measures) to segmented earnings (losses) (the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of US$, unless otherwise noted) 2024 2023 2022
TGNH1,2
 231  232  164 
Sur de Texas3
 220  75  112 
Topolobampo 156  157  161 
Guadalajara 56  61  73 
Mazatlán 67  71  67 
Comparable EBITDA 730  596  577 
Depreciation and amortization (67) (66) (76)
Comparable EBIT 663  530  501 
Foreign exchange impact 244  186  153 
Comparable EBIT (Cdn$)
 907  716  654 
Specific item:
Expected credit loss provision on net investment in leases
  and certain contract assets in Mexico2
 22  80  (163)
Segmented earnings (losses) (Cdn$)
 929  796  491 
1Includes the operating sections of the Tamazunchale, Villa de Reyes and Tula pipelines.
2Includes non-controlling interest. Refer to the Corporate - Financial results section for additional information.
3Represents equity income from our 60 per cent interest and fees earned from the construction and operation of the pipeline.
Mexico Natural Gas Pipelines segmented earnings in 2024 increased by $133 million compared to 2023 and increased by $305 million in 2023 compared to 2022 and included the impact of a $22 million unrealized recovery in 2024 (2023 – $80 million unrealized recovery; 2022 – $163 million unrealized loss) on the expected credit loss provision related to the TGNH net investment in leases and certain contract assets in Mexico, which we have excluded from our calculation of comparable EBITDA and comparable EBIT. Refer to Note 28, Risk management and financial instruments, of our 2024 Consolidated financial statements for additional information.
A stronger U.S. dollar in 2024 and 2023 had a positive impact on the Canadian dollar equivalent segmented earnings from our U.S. dollar-denominated operations in Mexico. Refer to the Foreign exchange section for additional information.
Comparable EBITDA for Mexico Natural Gas Pipelines increased by US$134 million in 2024 compared to 2023 mainly due to the net effect of:
•higher equity earnings in Sur de Texas primarily due to foreign exchange impacts upon the revaluation of peso-denominated liabilities as a result of a weaker Mexican peso and lower income tax expense mainly due to foreign exchange impacts. We use foreign exchange derivatives to manage this exposure, the impact of which is recognized in Foreign exchange (gains) losses, net in the Consolidated statement of income. Refer to the Foreign exchange section for additional information
•lower earnings from Guadalajara primarily due to lower fixed revenue in accordance with the current transportation contract and higher operating costs.
TC Energy Management's discussion and analysis 2024 | 57

Comparable EBITDA for Mexico Natural Gas Pipelines increased by US$19 million in 2023 compared to 2022 primarily due to:
•higher earnings in TGNH primarily related to the commercial in-service of the north section of the Villa de Reyes pipeline and the east section of the Tula pipeline in third quarter 2022, as well as the commercial in-service of the lateral section of the Villa de Reyes pipeline in third quarter 2023
•lower earnings from Guadalajara primarily due to lower fixed revenue in accordance with the current transportation contract and higher operating costs associated with a disruption of service due to a weather event
•lower equity earnings in Sur de Texas primarily due to foreign exchange impacts upon the revaluation of peso-denominated liabilities as a result of a stronger Mexican peso and increased interest expense due to higher interest rates. We use foreign exchange derivatives to manage this exposure, the impact of which is recognized in Foreign exchange (gains) losses, net in the Consolidated statement of income.
Depreciation and amortization
Depreciation and amortization was generally consistent in 2024 compared to 2023. Depreciation and amortization was US$10 million lower in 2023 compared to 2022 due to the change to lease accounting for Tamazunchale subsequent to the execution of the TGNH TSA with the CFE in mid-2022. Under sales-type lease accounting, our in-service TGNH pipeline assets are reflected on our Consolidated balance sheet within net investment in leases with no depreciation expense being recognized.
OUTLOOK
Comparable EBITDA
Mexico Natural Gas Pipelines comparable EBITDA reflects long-term, stable, principally U.S. dollar-denominated transportation contracts that are affected by the cost of providing service and includes our share of equity income from our 60 per cent equity interest in the Sur de Texas pipeline. Due to the long-term nature of the underlying transportation contracts, comparable EBITDA is generally consistent year-over-year except when new assets are placed in service. Comparable EBITDA for 2025 is expected to be higher than 2024 due to the Southeast Gateway project that is expected to be placed into commercial service on May 1, 2025.
Capital expenditures
We incurred US$1.5 billion of capital expenditures in 2024 primarily related to the construction of the Southeast Gateway and Villa de Reyes pipelines. We expect to incur approximately US$0.4 billion in 2025 to finalize construction of the Southeast Gateway and Villa de Reyes pipelines.
58 | TC Energy Management's discussion and analysis 2024

NATURAL GAS PIPELINES – BUSINESS RISKS
The following are risks specific to our Natural Gas Pipelines business. Refer to page 102 for information about general risks related to TC Energy as a whole, including other operational, safety and financial risks, as well as our approach to risk management.
Production levels within supply basins
The NGTL System and our pipelines downstream depend largely on supply from the WCSB. Columbia Gas and its connecting pipelines largely depend on Appalachian supply. We continue to monitor any changes in our customers' natural gas production plans and how these may impact our existing assets and new project schedules. There is competition amongst pipelines to connect to major basins. An overall decrease in production and/or increased competition for supply could reduce throughput on our connected pipelines that, in turn, could negatively impact overall revenues generated. The WCSB and Appalachian basins are two of the most prolific and cost-competitive basins in North America and have considerable natural gas reserves. However, the amount actually produced depends on many variables including the price of natural gas and natural gas liquids, basin-on-basin competition, pipeline and gas-processing tolls, demand within the basin, changes in policy and regulations and the overall value of the reserves, including liquids content.
Market access
We compete for market share with other natural gas pipelines. New supply basins are being developed closer to markets we have historically served and may reduce the throughput and/or distance of haul on our existing pipelines and impact revenues. New markets, including those created by LNG export facilities developed to access global natural gas demand, can lead to increased revenues through higher utilization of existing facilities and/or demand for new infrastructure. The long-term competitiveness of our pipeline systems and the avoidance of bypass pipelines will depend on our ability to adapt to changing flow patterns by offering competitive transportation services to the market. As part of our annual strategic planning process, we evaluate the resilience of our asset portfolio over a range of potential energy supply and demand outcomes.
Competition for greenfield pipeline expansion
We face competition from other pipeline companies seeking to invest in greenfield natural gas pipeline development opportunities. This competition could result in fewer available projects that meet our investment hurdles or projects that proceed with lower overall financial returns. While renewable deployments are expected to garner an increasing portion of future energy needs, including in the power generation sector, aggregate natural gas demand across all sectors, including LNG exports, is still projected to grow under the most aggressive renewable deployment forecasts. The reliability of natural gas is an important factor in the successful wide-scale deployment of renewables with more intermittent capabilities.
Demand for pipeline capacity
Demand for pipeline capacity ultimately drives the sale of pipeline transportation services and is impacted by supply and market competition, variations in economic activity, weather variability, natural gas pipeline and storage competition, energy conservation, as well as demand for and prices of alternative sources of energy. Renewal of expiring contracts and the opportunity to charge a competitive toll depends on the overall demand for transportation service. A decrease in the level of demand for our pipeline transportation services could adversely impact revenues, although overall utilization of our pipeline capacity continues to grow and warrant further investment and expansion.
Commodity prices
The cyclical supply and demand nature of commodities and related pricing can have a secondary impact on our business where our shippers may choose to accelerate or delay certain projects. This can impact the timing of demand for transportation services and/or new natural gas pipeline infrastructure. Disruptions in the energy supply chain can result in price volatility and a decline in natural gas prices that could impact our shippers' financial condition and their ability to meet their transportation service cost obligations.
TC Energy Management's discussion and analysis 2024 | 59

Regulatory risk
Decisions and evolving policies by regulators and other government authorities, including changes in regulation, can impact the approval, timing, construction, operation and financial performance of our natural gas pipelines. There is a risk that decisions are delayed or are not favourable and could therefore adversely impact construction costs, in-service dates, anticipated revenues and the opportunity to further invest in our systems. There is also risk of a regulator disallowing recovery of a portion of our costs, now or at some point in the future.
The regulatory approval process for larger infrastructure projects, including the time it takes to receive a decision, could be delayed or lead to an unfavourable decision due to evolving public opinion and government policy related to natural gas pipeline infrastructure development. If regulatory decisions are subsequently challenged in courts, this could result in further impacts to project costs and schedule delays.
Increased scrutiny of construction and operations processes by the regulator or other enforcing agencies has the potential to delay construction, increase operating costs or require additional capital investment. There is a risk of an adverse impact to income if these costs are not fully recoverable and/or reduce the competitiveness of tolls charged to customers.
We continuously manage these risks by monitoring legislative and regulatory developments and decisions to determine the possible impact on our natural gas pipelines business and developing rate, facility and tariff applications that account for and mitigate these risks where possible.
Governmental risk
Shifts in government policy or changes in government can impact our ability to grow our business. More complex regulatory processes, broader consultation requirements, more restrictive emissions and/or carbon pricing policies and changes to environmental regulations can impact our opportunities for continued growth. We are committed to working with all levels of government to ensure our business benefits and risks are understood and mitigation strategies are implemented.
Construction and operations
Constructing and operating our pipelines to ensure transportation services are provided safely and reliably is essential to the success of our business. Interruptions in our pipeline operations impacting throughput capacity may result in reduced revenues and can affect corporate reputation, as well as customer and public confidence in our operations. We manage this by investing in a highly skilled workforce, hiring third-party inspectors during construction, operating prudently, monitoring our pipeline systems continuously, using risk-based preventive maintenance programs and making effective capital investments. We use pipeline inspection equipment to regularly check the integrity of our pipelines and repair or replace sections when necessary. We also calibrate meters regularly to ensure accuracy and employ robust reliability and integrity programs to maintain compression equipment and safe and reliable operations.
60 | TC Energy Management's discussion and analysis 2024

Power and Energy Solutions
The Power and Energy Solutions business consists of power generation, non-regulated natural gas storage assets, as well as emerging technologies that can provide lower carbon solutions for our customers and industry.
Our Power and Energy Solutions business includes approximately 4,650 MW of generation powered by nuclear, natural gas, wind and solar. These generation assets are generally supported by long-term contracts. Our Canadian power infrastructure assets are located in Alberta, Ontario, Québec and New Brunswick while our U.S. power infrastructure assets are located in Texas. Additionally, we have approximately 400 MW of PPAs in Canada and approximately 350 MW of PPAs in the U.S. from wind and solar facilities.
We also own and operate approximately 118 Bcf of non-regulated natural gas storage capacity in Alberta.
Strategy
Our strategy is to maximize the value of our existing portfolio through maintaining safety and operational excellence while enhancing the life cycle and reliability of our assets and expanding profit margins through cost efficiency and revenue enhancement. Beyond our existing portfolio, we will focus our capital investment in sectors and projects that offer commercial frameworks consistent with TC Energy's value proposition, namely long-term contracts and rate regulation. In the long term, we believe there will be a growing need for a reliable supply of resources as the energy mix evolves. We are positioning ourselves to play a vital role in decarbonizing energy sources and will continue to build expertise and capabilities in emerging technologies and markets that we believe will fit these criteria in the future and have synergies with our natural gas business.
Recent highlights
•Bruce Power completed planned outages on Unit 1 and Unit 7 and completed a Vacuum Building inspection where Units 5, 6 and 8 were also shut down in 2024. On January 31, 2025, Unit 4 was removed from service to commence its MCR program
•The Unit 5 MCR final cost and schedule estimate was submitted to the IESO on January 31, 2025
•Executed contract extensions of five years at Mackay River and 10 years at Grandview cogeneration plants
•TC Energy and prospective partners Saugeen Ojibway Nation will advance pre-development work on the Ontario Pumped Storage Project following the Ontario Government's recent announcement on January 24, 2025 to invest up to $285 million. With the Ontario Government’s investment, the project can now advance critical development work, including the completion of a detailed cost estimate, the commencement of federal and provincial environmental assessments, advanced design and engineering and continued community engagement. It is expected that the Board of Directors, Saugeen Ojibway Nation and the Ontario Government will each make a final decision on the project following further definition and completion of a detailed cost estimate.
TC Energy Management's discussion and analysis 2024 | 61

UNDERSTANDING OUR POWER AND ENERGY SOLUTIONS BUSINESS
Canadian Power
Canadian Power Generation & Marketing
We own and operate approximately 1,200 MW of power supply in Canada, excluding our investment in Bruce Power. In Alberta we own five facilities: four natural gas-fired cogeneration and one solar. We exercise a disciplined operating strategy to maximize revenues. Our marketing group sells uncommitted power while also buying and selling power and natural gas to maximize earnings. To reduce commodity price exposure associated with uncontracted power, we sell a portion of this output in forward sales markets when acceptable contract terms are available while the remainder is retained to be sold in the spot market or under short-term forward arrangements. The objective of this strategy is to maintain adequate power supply to fulfill our sales obligations if we have unexpected plant outages and enable us to capture opportunities to increase earnings in periods of high spot prices. Our two eastern Canadian natural gas-fired cogeneration assets, Bécancour and Grandview, are fully contracted.
Bruce Power
Bruce Power is a nuclear power generation facility located near Tiverton, Ontario and is comprised of eight nuclear units with a combined capacity of approximately 6,580 MW. Bruce Power leases the facilities from OPG, has no spent fuel risk and will return the facilities to OPG for decommissioning at the end of the lease. We have a 48.3 per cent equity interest in Bruce Power.
Results from Bruce Power will fluctuate primarily due to units being offline for the MCR program and the frequency, scope and duration of planned and unplanned maintenance outages.
Through a long-term agreement with the IESO, Bruce Power has begun to progress a series of incremental life-extension investments to extend the operating life of the facility to 2064. This agreement represents an extension and material amendment to the earlier agreement that led to the refurbishment of Units 1 and 2 at the site. Under the amended agreement, which took economic effect in 2016, Bruce Power began investing in life extension activities for Units 3 through 8 to support the long-term refurbishment programs. Investment in the Asset Management program is designed to result in near-term life extensions of each of the six units up to the planned major refurbishment outages and beyond. The Asset Management program includes the one-time refurbishment or replacement of systems, structures or components that are not within the scope of the MCR program, which focuses on the actual replacement of the key, life-limiting reactor components. The MCR program is designed to add 30 years of operational life to each of the six units.
The Unit 6 MCR, the first of the six-unit MCR life extension program, was completed in third quarter 2023. The Unit 3 MCR, the second unit in the MCR program, commenced in first quarter 2023 and has an expected completion in 2026. The Unit 4 MCR final cost and schedule estimate was approved by the IESO on February 8, 2024. Unit 4 was removed from service on January 31, 2025 to commence its MCR program with expected completion in 2028. Investments in the remaining three units' MCR programs are expected to continue through 2033. The Unit 5 MCR final cost and schedule estimate was submitted to the IESO on January 31, 2025. Future MCR investments will be subject to discrete decisions for each unit with specified off-ramps available for Bruce Power and the IESO.
Along with the MCR life extension program, Bruce Power’s Project 2030 has a goal of achieving site peak output (capability) of 7,000 MW by 2033 in support of the province of Ontario's climate change targets and future clean energy needs. Project 2030 is focused on continued asset optimization, innovation and leveraging new technology, which could include integration with storage and other forms of energy, to increase site capability. Project 2030 is being implemented in three stages with the first two stages and Stage 3a fully approved for execution. The program commenced in 2019 with a site capability of 6,430 MW and closed out 2024 at approximately 6,580 MW; a net gain of approximately 150 MW. Upon completion of Stage 1, 2 and 3a, the site is projected to reach 6,840 MW. All three stages are being implemented in parallel to the MCR program.
As part of the life extension and refurbishment agreement, Bruce Power receives a uniform contract price for all units which includes certain flow-through items such as fuel and lease expense recovery. The contract also provides for payment if the IESO requests a reduction in Bruce Power’s generation to balance the supply of and demand for, electricity and/or manage other operating conditions of the Ontario power grid. The amount of the reduction is considered deemed generation, for which Bruce Power is paid the contract price.
62 | TC Energy Management's discussion and analysis 2024

The contract price is subject to adjustments for the return of and on capital invested at Bruce Power under the Asset Management and MCR programs, along with various other pricing adjustments that allow for a better matching of revenues and costs over the long term. As part of the amended agreement, Bruce Power is also required to share operating cost efficiencies with the IESO for better than planned performance. These efficiencies are reviewed every three years and paid out on a monthly basis over the subsequent three-year period. No operating cost efficiencies for the 2022 to 2024 period have been provided for at December 31, 2024 and no operating cost efficiencies were realized for the 2019 to 2021 period.
Bruce Power is a global supplier of Cobalt-60, a medical isotope used in the sterilization of medical equipment and to treat certain types of cancer. Cobalt-60 is produced during Bruce Power’s generation of electricity, harvested during certain planned maintenance outages and provided for medical use in the treatment of brain tumours and breast cancer. In addition, Bruce Power plans to expand Lutetium-177 isotope production used in the treatment of prostate cancer and neuroendocrine tumours. This project was undertaken with a Canadian-based nuclear medicine partnership and the Saugeen Ojibway Nation, on whose traditional territory the Bruce Power facilities are located. Furthermore, Bruce Power and its partners in the production of medical isotopes have committed to building a hot cell facility in Bruce County, expediting their ability to process short-lived lutetium-177 to ensure it reaches cancer patients around the world in a timely fashion.
Power Purchase Agreements – Canada
We have approximately 400 MW of wind and solar generation PPAs and associated environmental attributes in Alberta. These PPAs allow us to generate incremental earnings by offering renewable power products to our customers.
U.S. Power
Power Generation & Marketing – U.S.
We own approximately 300 MW of wind generation located in Texas which operate in the Electric Reliability Council of Texas (ERCOT) and Southwest Power Pool (SPP) markets. A portion of this power generation is sold under a long-term, fixed price contract.
Our U.S. Power and emissions commercial trading and marketing business optimizes the value of our assets and leverages physical and financial products in the power and environmental markets with a focus on risk management.
Power Purchase Agreements – U.S.
We have approximately 350 MW of wind generation PPAs and associated environmental attributes in the U.S. These PPAs allow us to generate incremental earnings by offering renewable power products to our customers.
Other Energy Solutions
Canadian Natural Gas Storage
We own and operate 118 Bcf of non-regulated natural gas storage capacity in Alberta. This business operates independently from our regulated natural gas transmission and U.S. storage businesses.
Our Canadian natural gas storage business helps balance seasonal and short-term supply and demand while also adding flexibility to the delivery of natural gas to markets in Alberta and the rest of North America. Market volatility creates arbitrage opportunities and our natural gas storage facilities also give us and our customers the ability to capture value from short-term price movements. The natural gas storage business is affected by changes in seasonal natural gas price spreads which are generally determined by the differential in natural gas prices between the traditional summer injection and winter withdrawal seasons. In addition, the business may be affected by pipeline restrictions in Alberta which limit the ability to capture price differentials.
Our natural gas storage business contracts with third parties, typically participants in the Alberta and interconnected gas markets, for a fixed fee to provide natural gas storage services on a short, medium and/or long-term basis.
We also enter proprietary natural gas storage transactions which include a forward purchase of our own natural gas to be injected into storage and a simultaneous forward sale of natural gas for withdrawal at a later period, typically during the winter withdrawal season. By matching purchase and sales volumes on a back-to-back basis, we lock in future positive margins, effectively eliminating our exposure to changes in natural gas prices for these transactions.
TC Energy Management's discussion and analysis 2024 | 63

ar_powerandstoragex1024xv1a.jpg
64 | TC Energy Management's discussion and analysis 2024

Power and Energy Solutions assets currently have a combined power generation capacity, net to TC Energy, of 4,652 MW. We operate each facility except for Bruce Power.
  Generating
 capacity (MW)		 Type of fuel Description Ownership
Power assets
1 
Bruce Power1
3,180
 nuclear Eight operating reactors in Tiverton, Ontario. Bruce Power leases the nuclear facilities from OPG. 48.3  %
2  Bécancour 550  natural gas Cogeneration plant in Trois-Rivières, Québec. Power generation has been suspended since 2008 although we continue to receive PPA capacity payments while generation is suspended. 100  %
3  Mackay River 207  natural gas Cogeneration plant in Fort McMurray, Alberta. 100  %
4 
Fluvanna2
 155 
wind
Wind farm located near Scurry County, Texas.
 100  %
5 
Blue Cloud2
 148 
wind
Wind farm located near Bailey County, Texas.
 100  %
6  Bear Creek 100  natural gas Cogeneration plant in Grande Prairie, Alberta. 100  %
7  Carseland 95  natural gas Cogeneration plant in Carseland, Alberta. 100  %
8  Grandview 90  natural gas Cogeneration plant in Saint John, New Brunswick. 100  %
9  Saddlebrook Solar 81  solar Hybrid solar generation facility near Aldersyde, Alberta. 100  %
10  Redwater 46  natural gas Cogeneration plant in Redwater, Alberta. 100  %
Canadian non-regulated natural gas storage
11  Crossfield 68 Bcf   Underground facility connected to the NGTL System near Crossfield, Alberta. 100  %
12  Edson 50 Bcf   Underground facility connected to the NGTL System near Edson, Alberta. 100  %
Under construction
Other energy solutions
13 
Lynchburg
 RNG RNG production facility in Lynchburg, Tennessee. 30  %
1Our share of power generation capacity.
2TC Energy owns 100 per cent of the Class B Membership Interests and has a tax equity investor that owns 100 per cent of the Class A Membership Interests, to which a percentage of earnings, tax attributes and cash flows are allocated under the provisions of each tax equity agreement.
TC Energy Management's discussion and analysis 2024 | 65

SIGNIFICANT EVENTS
Bruce Power Life Extension
On January 31, 2025, Unit 4 was removed from service to commence its MCR program, with a return to service expected in 2028.
The Unit 5 MCR final cost and schedule estimate was submitted to the IESO on January 31, 2025.
Uprate Initiative
On November 19, 2024, we announced that Bruce Power is progressing with Stage 3a of Project 2030, which is designed to provide incremental capacity of approximately 90 MW at the site. TC Energy’s share of the capital required is approximately $175 million. Bruce Power will not be requesting an incremental capital call for this stage. By optimizing its existing Units through this program, when complete, Project 2030 is expected to increase the Bruce Power site peak output to 7,000 MW. All of this output will be sold under Bruce Power’s long-term contract with the IESO.
Ontario Pumped Storage
TC Energy and prospective partners Saugeen Ojibway Nation will advance pre-development work on the Ontario Pumped Storage Project following the Ontario Government's recent announcement on January 24, 2025 to invest up to $285 million. With the Ontario Government’s investment, the project can now advance critical development work, including the completion of a detailed cost estimate, the commencement of federal and provincial environmental assessments, advanced design and engineering and continued community engagement.
It is expected that TC Energy's Board of Directors, Saugeen Ojibway Nation and the Ontario Government will each make a final decision on the project following further definition and completion of a detailed cost estimate.


66 | TC Energy Management's discussion and analysis 2024

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA and comparable EBIT (our non-GAAP measures) to segmented earnings (losses)(the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of $) 2024 2023 2022
Bruce Power1
 890  680  552 
Canadian Power
 273  334  322 
Natural Gas Storage and other2
 51  6  33 
Comparable EBITDA 1,214  1,020  907 
Depreciation and amortization (101) (92) (72)
Comparable EBIT 1,113  928  835 
Specific items:
Project Tundra impairment charge (36) —  — 
Bruce Power unrealized fair value adjustments 8  7  (17)
Risk management activities 17  69  15 
Segmented earnings (losses)
 1,102  1,004  833 
1Includes our share of equity income from Bruce Power.
2Includes non-controlling interest in the Texas Wind Farms, which comprises Class A Membership Interests. Refer to the Corporate - Financial results section for additional information.
Power and Energy Solutions segmented earnings increased by $98 million in 2024 compared to 2023 and increased by
$171 million in 2023 compared to 2022 and included the following specific items, which have been excluded from our calculation of comparable EBITDA and comparable EBIT:
•a pre-tax impairment charge of $36 million related to development costs incurred on Project Tundra, a next-generation technology carbon capture and storage project, following our decision to end our collaboration on the project
•our proportionate share of Bruce Power's unrealized gains and losses on funds invested for post-retirement benefits and risk management activities
•unrealized gains and losses from changes in the fair value of derivatives used to reduce commodity exposures.
Comparable EBITDA for Power and Energy Solutions increased by $194 million in 2024 compared to 2023 primarily due to the net effect of:
•higher contributions from Bruce Power primarily due to higher generation resulting from fewer outage days in 2024 and a higher contract price, partially offset by increased operating expenses and higher depreciation expense. Additional financial and operating information on Bruce Power is provided below
•increased Natural Gas Storage and other results primarily due to higher realized Alberta natural gas storage spreads and higher contributions from our U.S. marketing business, partially offset by increased business development costs in 2024
•decreased Canadian Power financial results primarily from lower realized power prices, partially offset by lower natural gas fuel costs.
Comparable EBITDA for Power and Energy Solutions increased by $113 million in 2023 compared to 2022 primarily due to the net effect of:
•higher contributions from Bruce Power primarily due to a higher contract price, reduced outage costs with fewer planned outage days and lower depreciation expense, partially offset by lower generation and increased operating expenses
•increased Canadian Power financial results primarily from lower natural gas fuel costs and higher realized power prices
•decreased Natural Gas Storage and other results due to increased business development costs.
Depreciation and amortization
Depreciation and amortization increased by $9 million in 2024 compared to 2023 and increased by $20 million in 2023 compared to 2022 and were primarily due to the acquisition of the Texas Wind Farms in the first half of 2023.
TC Energy Management's discussion and analysis 2024 | 67

Bruce Power results
Bruce Power results reflect our proportionate share. Comparable EBITDA and comparable EBIT are non-GAAP measures. Refer to page 24 for more information on non-GAAP measures we use. The following is our proportionate share of the components of comparable EBITDA and comparable EBIT.
year ended December 31
(millions of $, unless otherwise noted) 2024 2023 2022
Items included in comparable EBITDA and comparable EBIT are comprised of:
Revenues1
 2,242  1,941  1,848 
Operating expenses (984) (917) (924)
Depreciation and other (368) (344) (372)
Comparable EBITDA and comparable EBIT2
 890  680  552 
Bruce Power – other information      
Plant availability3,4
 92  % 92  % 86  %
Planned outage days4
 160  106  302 
Unplanned outage days 32  62  34 
Sales volumes (GWh)5
 22,209  20,447  20,610 
Realized power price per MWh6
 $100  $94  $89 
1Net of amounts recorded to reflect operating cost efficiencies shared with the IESO, if applicable.
2Represents our 48.3 per cent ownership interest and internal costs supporting our investment in Bruce Power. Excludes unrealized gains and losses on funds invested for post-retirement benefits and risk management activities.
3The percentage of time the plant was available to generate power, regardless of whether it was running.
4Excludes MCR outage days.
5Sales volumes include deemed generation.
6Calculation based on actual and deemed generation. Realized power price per MWh includes realized gains and losses from contracting activities and cost flow-through items. Excludes unrealized gains and losses on contracting activities and non-electricity revenues.
Bruce Power's 2024 planned maintenance, on Units 5 to 8, excluding the MCR program, was completed in second quarter. A planned outage on Unit 4 was completed in second quarter 2023 and on Unit 8 in fourth quarter 2023. In 2022, planned maintenance was completed on all units.
OUTLOOK
Comparable EBITDA
Power and Energy Solutions comparable EBITDA in 2025 is expected to be lower than 2024 primarily from decreased Bruce Power equity income due to the removal of Unit 4 from service on January 31, 2025 to commence its MCR outage, partially offset by a higher contract price and fewer non-MCR planned outage days. Lower Alberta power prices and higher natural gas prices in 2025 are expected to reduce contributions from Canadian Power. These reductions are expected to be partially offset by lower business development activities in 2025.
Planned maintenance at Bruce Power in 2025 is currently scheduled to begin on Unit 5 in the first quarter and on Unit 2 in the third quarter. The average 2025 plant availability percentage, excluding the Unit 3 and Unit 4 MCR programs, is expected to be in the low-90 per cent range.
Capital expenditures
We incurred $0.8 billion of capital expenditures in 2024 primarily on our share of the Unit 3 MCR program at Bruce Power and maintenance capital projects across the segment. We expect to incur approximately $0.9 billion in 2025 primarily related to our share of Bruce Power's Unit 3 and Unit 4 MCR programs.
68 | TC Energy Management's discussion and analysis 2024

BUSINESS RISKS
The following are risks specific to our Power and Energy Solutions business. Refer to page 102 for information about general risks related to TC Energy as a whole, including other operational, safety and financial risks, as well as our approach to risk management.
Fluctuating power and natural gas market prices
Much of the physical power generation and fuel used in our power operations is currently exposed to commodity price volatility. These exposures are partially mitigated through long-term contracts and hedging activities including selling and purchasing power and natural gas in forward markets. As contracts expire, new contracts are entered into at prevailing market prices.
Our two eastern Canadian natural gas-fired assets are fully contracted and not materially impacted by fluctuating spot power and natural gas prices. As the contracts on these assets expire it is uncertain if we will be able to re-contract on similar terms and may face future commodity exposure.
Our natural gas storage business is subject to fluctuating seasonal natural gas price spreads which are generally determined by the differential in natural gas prices between the traditional summer injection and winter withdrawal seasons. In addition, the business may be affected by pipeline restrictions in Alberta which limit the ability to capture price differentials.
Plant availability
Operating our plants to ensure services are provided safely and reliably as well as optimizing and maintaining their availability are essential to the continued success of our Power and Energy Solutions business. Unexpected outages or extended planned outages at our power plants can increase maintenance costs as well as lower plant output, revenues and margins. We may also have to buy power or natural gas on the spot market to meet our delivery obligations. We manage this risk by investing in a highly skilled workforce, operating prudently, running comprehensive risk-based preventive maintenance programs and making effective capital investments.
Regulatory
We operate in Canada and the U.S. in both regulated and deregulated power markets. These markets are subject to various federal, provincial and state regulations. As power markets evolve, there is the potential for regulatory bodies to implement new rules that could negatively affect us as a generator and marketer of electricity. These may be in the form of market rule or market design changes, changes in the interpretation and application of market rules by regulators, price caps, emission controls, emissions costs, cost allocations to generators and out-of-market actions taken by others to build excess generation, all of which may negatively affect the price of power. In addition, our development projects rely on an orderly permitting process and any disruption to that process can have negative effects on project schedules and costs. We are an active participant in formal and informal regulatory proceedings and take legal action where required.
Compliance
Market rules, regulations and operating standards apply to our power business based on the jurisdictions in which they operate. Our trading and marketing activities may be subject to fair competition and market conduct requirements as well as specific rules that apply to physical and financial transactions in deregulated markets. Similarly, our generators may be subject to specific operating and technical standards relating to maintenance activities, generator availability and delivery of power and power-related products. While significant efforts are made to ensure we comply with all applicable statutory requirements, situations including unforeseen operational challenges, lack of rule clarity and the ambiguous and unpredictable application of requirements by regulators and market monitors occasionally arise and create compliance risk. Deemed contravention of these requirements may result in mandatory mitigation activities, monetary penalties, imposition of operational limitations, or even prosecution.
Weather
Significant changes in temperature and weather, including the potential impacts of climate change, have many effects on our business, ranging from the impact on demand, availability and commodity prices, to efficiency and output capability. Extreme temperature and weather can affect market demand for power and natural gas and can lead to significant price volatility, as well as restrict the availability of natural gas and power if demand is higher than supply. Fluctuations in seasonal weather patterns or temperature can affect the efficiency and production of our natural gas-fired power plants.
TC Energy Management's discussion and analysis 2024 | 69

Competition
We face various competitive forces that impact our existing assets and prospects for growth. For instance, our existing power plants will compete over time with new power capacity. New supply could come in several forms including supply that employs more efficient power generation technologies or additional supply from regional power transmission interconnections. We also face competition from other power companies in Canada and the U.S., as well as in the development of greenfield power plants. Traditional and non-traditional participants are entering the growing lower-carbon economy in North America and, as a result, we face competition in building lower-carbon energy solutions.
Execution and capital costs
We make substantial capital commitments developing power generation infrastructure based on the assumption that these assets will deliver an attractive return on investment. While we carefully consider the scope and expected costs of our capital projects, we are exposed to execution and capital cost overrun risk which may impact our return on these projects. We mitigate this risk by implementing comprehensive project governance and oversight processes and through the structuring of engineering, procurement and construction contracts with reputable counterparties.
70 | TC Energy Management's discussion and analysis 2024

Corporate
SIGNIFICANT EVENTS
NGTL System Ownership Transfer
On April 1, 2024, ownership of the NGTL System was transferred from Nova Gas Transmission Ltd. to NGTL GP Ltd. on behalf of NGTL Limited Partnership as part of an ordinary course corporate reorganization to support business optimization and facilitate future minority ownership of the NGTL System, including participation from Indigenous groups. Refer to the Canadian Natural Gas Pipelines – Significant events section for additional information. The reorganization will not impact the operations of the NGTL System. As a limited partnership, NGTL LP is not subject to Canadian corporate income taxes. The related income tax obligations are those of the partners.
For the year ended December 31, 2024, we incurred costs of $42 million after tax related to the NGTL System Ownership Transfer, which has been excluded from comparable measures.
2016 Columbia Pipeline Acquisition Lawsuit
In 2023, the Delaware Chancery Court (the Court) issued its decision in the class action lawsuit commenced by former shareholders of Columbia Pipeline Group Inc. (CPG) related to the acquisition of CPG by TC Energy in 2016. The Court found that the former CPG executives breached their fiduciary duties, that the former CPG Board breached its duty of care in overseeing the sale process and that TC Energy aided and abetted those breaches.
On May 15, 2024, the Court allocated responsibility for the total sale process damages of US$398 million in the amount of 50 per cent to the former Columbia CEO and CFO, collectively, and 50 per cent to TC Energy. Pursuant to the Final Order and Judgment (Final Judgment), TC Energy’s allocated share of the sale process claim damages is US$199 million, plus US$153 million in interest as of June 14, 2024. The Court also entered judgment related to a disclosure claim for which TC Energy’s allocated share of damages is US$84 million, plus US$64 million in interest as of June 14, 2024. The damages for the two claims are not cumulative and TC Energy would only be required to pay the greater of the sale process damages and disclosure claim damages after final determination of those amounts on appeal, including any additional interest assessed to the date of payment.
TC Energy disagrees with many of the Court’s findings and believes the Court’s ruling departs from established Delaware law. TC Energy has filed a notice of appeal, which is scheduled to be heard by the Delaware Supreme Court on March 12, 2025. A final decision is expected in mid-2025. During the appeal process, in lieu of paying the judgment, TC Energy posted an appeal bond in the amount of US$380 million, which approximates the amount of the Final Judgment plus nine months of post-judgment interest. Our legal assessment is that it is not probable that TC Energy will incur a loss upon completion of the appeal process, and therefore, we have not accrued a provision for this claim at December 31, 2024.
Focus Project
In late 2022, we launched the Focus Project to identify opportunities to improve safety, productivity and cost-effectiveness. To date, we have designed and implemented a broad set of initiatives to further enhance safety, as well as improve operational and financial performance over the long term.
The expected impacts of project initiatives have been included in our outlook for 2025 and no significant incremental project costs are expected beyond 2024. The program will wind down in 2025 as we finalize implementation of certain initiatives. The core elements of the project are embedded into our business processes to sustain performance improvements over the long term.
For the year ended December 31, 2024 we have incurred pre-tax costs of $45 million (2023 – $124 million) for the Focus Project primarily related to severance costs, of which $24 million (2023 – $65 million, primarily external consulting) was recorded in Plant operating costs and other in the Consolidated statement of income and was excluded from comparable measures. An additional $14 million for the year ended December 31, 2024 (2023 – $23 million) was recorded in Plant operating costs and other with offsetting revenues related to costs recoverable through regulatory and commercial tolling structures, the net effect of which had no impact on net income. For the year ended December 31, 2024, $7 million (2023 – $36 million) was allocated to capital projects.
TC Energy Management's discussion and analysis 2024 | 71

Asset Divestiture Program
Our asset divestiture program, which included completing the sale of PNGTS and the CFE’s equity injection resulting in a 13.01 per cent equity interest in TGNH in 2024, as well as the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf in 2023, collectively contributed to our deleveraging goal. Any further capital rotation opportunities will be assessed in the normal course of our business.
2024 Canadian Legislation
On June 20, 2024, two pieces of Canadian legislation, Bill C-59 and Bill C-69 were enacted into law, which, among other things, included the excessive interest and financing expenses limitation (EIFEL) rules and the Global Minimum Tax Act. We do not expect a material impact on our financial performance and cash flows as a result of the new legislation.
TC Energy has disallowed interest expense related to the EIFEL legislation and expects further restrictions on interest deductibility. However, through on-going monitoring and management, we expect the disallowed interest to be utilized. We will also continue to monitor developments related to EIFEL legislation and assess its impacts to the business.
72 | TC Energy Management's discussion and analysis 2024

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA and comparable EBIT (our non-GAAP measures) to segmented earnings(losses)(the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of $) 2024
2023¹
2022¹
Comparable EBITDA
 (63) (73) (72)
Depreciation and amortization (5) (6) (7)
Comparable EBIT
 (68) (79) (79)
Specific items:
Third-party settlement (34) —  — 
Focus Project costs (24) (65) — 
NGTL System ownership transfer costs (10) —  — 
Foreign exchange gains – inter-affiliate loans2
 —  —  28 
Segmented earnings (losses) (136) (144) (51)
1Prior year results have been recast to reflect continuing operations only.
2Reported in Income (loss) from equity investments in the Consolidated statement of income.
In 2024, Corporate segmented losses were $136 million compared to $144 million and $51 million in 2023 and 2022, respectively, and included the following specific items which have been excluded from our calculation of comparable EBITDA and comparable EBIT:
•a pre-tax expense of $34 million (US$25 million) in 2024 related to a non-recurring third-party settlement
•a pre-tax charge of $24 million recorded in 2024 (2023 – $65 million) related to Focus Project costs. Refer to the Corporate – Significant events section for additional information
•a pre-tax charge of $10 million in 2024 related to the NGTL System Ownership Transfer. Refer to the Corporate – Significant events section for additional information
•foreign exchange gains in 2022 on our proportionate share of peso-denominated inter-affiliate loans to the Sur de Texas joint venture from its partners up to March 15, 2022 when the peso-denominated inter-affiliate loans were fully repaid upon maturity. These foreign exchange gains were recorded in Income from equity investments in the Corporate segment and were excluded from our calculation of comparable EBITDA and comparable EBIT as they were fully offset by corresponding foreign exchange losses on the inter-affiliate loan receivable included in Foreign exchange gains (losses), net. Refer to the Other information – Related party transactions section for additional information.
Comparable EBITDA for Corporate was a loss of $63 million in 2024 compared to a loss of $73 million in 2023, primarily due to shared costs in 2024 and 2023 related to TC Energy's corporate services and governance functions that were not allocated to discontinued operations in accordance with U.S. GAAP. Refer to the Discontinued operations section for additional information. Comparable EBITDA for Corporate in 2023 was generally consistent compared to 2022.
Depreciation and amortization
Depreciation and amortization was generally consistent between 2024 and 2023 and between 2023 and 2022.
TC Energy Management's discussion and analysis 2024 | 73

OTHER INCOME STATEMENT ITEMS
Interest expense
year ended December 31
(millions of $) 2024
2023¹
2022¹
Interest expense on long-term debt and junior subordinated notes
      
Canadian dollar-denominated (856) (895) (776)
U.S. dollar-denominated (1,855) (1,692) (1,267)
Foreign exchange impact (685) (592) (383)
  (3,396) (3,179) (2,426)
Other interest and amortization expense (147) (261) (189)
Capitalized interest 191  187  27 
Interest expense allocated to discontinued operations
 176  287  288 
Interest expense included in comparable earnings
 (3,176) (2,966) (2,300)
Specific items:
Net gain on debt extinguishment 228  —  — 
Risk management activities
 (71) —  — 
Interest expense
 (3,019) (2,966) (2,300)
1Prior year results have been recast to reflect continuing operations only.
Interest expense increased by $53 million in 2024 compared to 2023 and increased by $666 million in 2023 compared to 2022. The following specific items have been removed from our calculation of interest expense included in comparable earnings:
•pre-tax net gain on debt extinguishment of $228 million was recorded related to the purchase and cancellation of certain senior unsecured notes and medium term notes and the retirement of outstanding callable notes in October 2024. Refer to the Financial condition section for additional information
•unrealized gains and losses on derivatives used to manage our interest rate risk. Refer to the Other information - Financial risks and financial instruments sections for additional information.
Interest expense included in comparable earnings in 2024 increased by $210 million compared to 2023 primarily due to the net effect of:
•long-term debt issuances and maturities
•interest expense allocated to discontinued operations for nine months in 2024 compared to a full year in 2023. Refer to the Discontinued operations section for additional information
•the foreign exchange impact from a stronger U.S. dollar on translation of U.S. dollar-denominated interest expense
•reduced levels of short-term borrowing.
Interest expense included in comparable earnings in 2023 increased by $666 million compared to 2022 mainly due to the net effect of:
•long-term debt issuances and maturities
•the foreign exchange impact from a stronger U.S. dollar on translation of U.S. dollar-denominated interest expense
•higher interest rates on our long-term debt that bears interest at a floating rate
•higher capitalized interest, largely due to funding related to our investment in Coastal GasLink LP. Refer to Note 7, Coastal GasLink, of our 2024 Consolidated financial statements for additional information.
Refer to the Financial condition section for additional information.
74 | TC Energy Management's discussion and analysis 2024

Allowance for funds used during construction
year ended December 31
(millions of $) 2024 2023 2022
Allowance for funds used during construction
Canadian dollar-denominated 34  102  157 
U.S. dollar-denominated 546  350  161 
Foreign exchange impact 204  123  51 
Allowance for funds used during construction 784  575  369 
AFUDC increased by $209 million in 2024 compared to 2023. The decrease in Canadian dollar-denominated AFUDC is primarily related to NGTL System expansion projects placed in service. The increase in U.S. dollar-denominated AFUDC is primarily due to capital expenditures on the Southeast Gateway pipeline project and U.S. natural gas pipeline projects in 2024, partially offset by the suspension of AFUDC on the assets under construction for the Tula pipeline project due to the delay of an FID and placing the lateral section of Villa de Reyes pipeline in service in August 2023.    
AFUDC increased by $206 million in 2023 compared to 2022. The decrease in Canadian dollar-denominated AFUDC is primarily related to NGTL System expansion projects placed in service. The increase in U.S. dollar-denominated AFUDC is the result of the reactivation of AFUDC on the TGNH assets under construction following the new TSA with the CFE, as well as capital expenditures on the Southeast Gateway pipeline project in 2023, partially offset by projects placed in service on our U.S. natural gas pipelines. Effective November 1, 2023, AFUDC was suspended on the assets under construction for the Tula pipeline project, due to the delay of an FID.
Foreign exchange gains (losses), net
year ended December 31
(millions of $) 2024 2023 2022
Foreign exchange gains (losses), net included in comparable earnings
 (85) 118  (8)
Specific items:
Foreign exchange gains (losses), net – intercompany loan1
 204  (44) — 
Foreign exchange losses – inter-affiliate loan
—  —  (28)
Risk management activities (266) 246  (149)
Foreign exchange gains (losses), net (147) 320  (185)
1     Includes non-controlling interest. Refer to Net (income) loss attributable to non-controlling interests for additional information.
Foreign exchange losses, net were $147 million in 2024 compared to foreign exchange gains, net of $320 million in 2023 and foreign exchange losses, net of $185 million in 2022. The following specific items have been removed from our calculation of Foreign exchange gains (losses), net included in comparable earnings:
•unrealized foreign exchange gains and losses on the peso-denominated intercompany loan between TCPL and TGNH beginning in second quarter 2023
•foreign exchange losses on the peso-denominated inter-affiliate loan receivable from the Sur de Texas joint venture until March 15, 2022, when it was fully repaid upon maturity. The interest income and interest expense on the peso-denominated inter-affiliate loan was included in comparable earnings with all amounts offsetting and resulting in no impact on consolidated net income. Refer to the Other information – Related party transactions section for additional information
•unrealized gains and losses from changes in the fair value of derivatives used to manage our foreign exchange risk. Refer to the Other information – Financial risks and Financial instruments sections for additional information.
TC Energy Management's discussion and analysis 2024 | 75

Foreign exchange losses, net included in comparable earnings were $85 million in 2024 compared to foreign exchange gains, net of $118 million in 2023. The change was primarily due to the net effect of:
•risk management activities used to manage our foreign exchange exposure to net liabilities in Mexico and to U.S. dollar‑denominated income
•foreign exchange gains in 2024 compared to foreign exchange losses in 2023 on the revaluation of our peso-denominated net monetary liabilities to U.S. dollars
•a net realized gain in the second quarter 2024 on the partial repayment of the peso-denominated intercompany loan between TCPL and TGNH.
Foreign exchange gains, net included in comparable earnings were $118 million in 2023 compared to foreign exchange losses, net of $8 million in 2022. The change was primarily due to the net effect of:
•risk management activities used to manage our foreign exchange exposure to net liabilities in Mexico and to U.S. dollar‑denominated income
•higher foreign exchange losses on the revaluation of our peso-denominated net monetary liabilities to U.S. dollars.
Interest income and other
year ended December 31
(millions of $) 2024
2023¹
2022¹
Interest income and other
 324  272  140 
1Prior year results have been recast to reflect continuing operations only.
Interest income and other increased by $52 million in 2024 compared to 2023 due to higher interest earned on short-term investments and a reduction in insurance-related provisions.
Interest income and other increased by $132 million in 2023 compared to 2022 due to higher interest earned on short-term investments and the change in fair value of other restricted investments, partially offset by lower interest income in 2023 due to the repayment of the inter-affiliate loan receivable from Sur de Texas joint venture in July 2022.

76 | TC Energy Management's discussion and analysis 2024

Income tax (expense) recovery
year ended December 31
(millions of $) 2024

2023¹
2022¹
Income tax (expense) recovery included in comparable earnings
 (772) (890) (660)
Specific items:
Gain on sale of PNGTS (116) —  — 
Revaluation of deferred tax balances
 (96) —  — 
Net gain on debt extinguishment (50) —  — 
Foreign exchange gains (losses), net – intercompany loan
 10  —  — 
Gain on sale of non-core assets 15  —  — 
Expected credit loss provision on net investment in leases
  and certain contract assets in Mexico		 (7) (25) 49 
Third-party settlement 8  —  — 
Project Tundra impairment charge 9  —  — 
Focus Project costs 6  17  — 
NGTL System ownership transfer costs (32) —  — 
Coastal GasLink impairment charge —  157  405 
Great Lakes goodwill impairment charge —  —  40 
Settlement of Mexico prior years' income tax assessments —  —  (196)
Bruce Power unrealized fair value adjustments (2) (2) 4 
Risk management activities 105  (99) 36 
Income tax (expense) recovery
 (922) (842) (322)
1Prior year results have been recast to reflect continuing operations only.
Income tax expense in 2024 increased by $80 million compared to 2023 and increased by $520 million in 2023 compared to 2022.
In addition to the income tax impacts on other specific items referenced elsewhere in this MD&A, Income tax (expense) recovery also includes the following specific items, which have been removed from our calculation of Income tax (expense) recovery included in comparable earnings:
2024
•a deferred income tax expense of $96 million resulting from the revaluation of remaining deferred tax balances following the Spinoff Transaction.
2023
•a $157 million income tax recovery related to the impairment of our equity investment in Coastal GasLink LP.
2022
•a $405 million income tax recovery related to the impairment of our equity investment in Coastal GasLink LP, net of certain unrealized tax losses not recognized
•$196 million expense related to the settlement of prior years' income tax assessments related to our operations in Mexico.
Income tax expense included in comparable earnings in 2024 decreased by $118 million compared to 2023 primarily due to Mexico foreign exchange exposure and lower earnings subject to income tax, partially offset by lower foreign income tax rate differentials and higher flow-through income taxes. Refer to the Foreign exchange section for additional information.
Income tax expense included in comparable earnings in 2023 increased by $230 million compared to 2022 primarily due to higher earnings subject to income tax, Mexico foreign exchange exposure and lower foreign income tax rate differentials, partially offset by lower flow-through income taxes and lower Mexico inflationary adjustments. Refer to the Foreign exchange section for additional information.
TC Energy Management's discussion and analysis 2024 | 77

Net (income) loss attributable to non-controlling interests
year ended December 31
Non-Controlling Interests
Ownership at 
December 31, 2024
 2024 2023 2022
(millions of Canadian $)
Columbia Gas and Columbia Gulf1
 40  % (571) (143) — 
PNGTS2
 nil (30) (41) (37)
Texas Wind Farms3
 100  % 29  38  — 
TGNH4
 13.01  % (48) —  — 
Net (income) loss attributable to non-controlling interests included in comparable earnings
 (620) (146) (37)
Specific item:
Foreign exchange (gains) losses, net – intercompany loan (61) —  — 
Net (income) loss attributable to non-controlling interests
 (681) (146) (37)
1On October 4, 2023, we completed the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf to Global Infrastructure Partners.
2The sale of PNGTS was completed on August 15, 2024. Refer to the U.S. Natural Gas Pipelines – Significant events section for additional information.
3Tax equity investors own 100 per cent of the Class A Membership Interests, to which a percentage of earnings, tax attributes and cash flows are allocated. We own 100 per cent of the Class B Membership Interests.
4In second quarter 2024, the CFE became a partner in TGNH with a 13.01 per cent equity interest in TGNH. Refer to the Mexico Natural Gas Pipelines – Significant events section for additional information.
Net income attributable to non-controlling interests increased by $535 million in 2024 compared to 2023 and includes the non-controlling interest portion of the unrealized foreign exchange gains and losses on the TGNH peso-denominated intercompany loan payable to TCPL, which has been removed from our calculation of Net (income) loss attributable to non-controlling interests included in comparable earnings. Net income attributable to non-controlling interests included in comparable earnings increased by $474 million primarily due to the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf to Global Infrastructure Partners in fourth quarter 2023 and the 13.01 per cent non-controlling equity interest in TGNH to the CFE, which was completed in second quarter 2024. Refer to the Mexico Natural Gas Pipelines – Significant events section for additional information.
Net income attributable to non-controlling interests increased by $109 million in 2023 compared to 2022 due to the net effect of the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf and the acquisition of the Texas Wind Farms.
Preferred share dividends
year ended December 31
(millions of $) 2024 2023 2022
Preferred share dividends (104) (93) (107)
Preferred share dividends increased by $11 million in 2024 compared to 2023 primarily due to the dividend rate resets on Series 7 preferred shares and Series 9 preferred shares on April 30, 2024 and October 30, 2024, respectively. Preferred share dividends decreased $14 million in 2023 compared to 2022 primarily due to the redemption of preferred shares in 2022, partially offset by higher floating dividend rates on certain series of preferred shares.
78 | TC Energy Management's discussion and analysis 2024

Foreign exchange
Foreign exchange related to U.S. dollar-denominated operations
Certain of our businesses generate all or most of their earnings in U.S. dollars and, since we report our financial results in Canadian dollars, changes in the value of the U.S. dollar against the Canadian dollar directly affect our comparable EBITDA and may also impact comparable earnings. As our U.S. dollar-denominated operations continue to grow, this exposure increases. A portion of the U.S. dollar-denominated comparable EBITDA exposure is naturally offset by U.S. dollar-denominated amounts below comparable EBITDA within Depreciation and amortization, Interest expense and other income statement line items. A portion of the remaining exposure is actively managed on a rolling forward basis up to three years using foreign exchange derivatives; however, the natural exposure beyond that period remains. The net impact of the U.S. dollar movements on comparable earnings during the year ended December 31, 2024, after considering natural offsets and economic hedges, was not significant.
The components of our financial results denominated in U.S. dollars are set out in the table below, including our U.S. Natural Gas Pipelines and Mexico Natural Gas Pipelines operations. Comparable EBITDA is a non-GAAP measure.
Pre-tax U.S. dollar-denominated income and expense items - from continuing operations
year ended December 31
(millions of US$) 2024
2023¹
2022¹
Comparable EBITDA
U.S. Natural Gas Pipelines 3,294  3,248  3,142 
Mexico Natural Gas Pipelines2
 730  596  602 
4,024  3,844  3,744 
Depreciation and amortization (764) (758) (757)
Interest on long-term debt and junior subordinated notes (1,855) (1,692) (1,267)
Interest expense allocated to discontinued operations
 125  189  182 
Allowance for funds used during construction 546  350  161 
Net income (loss) attributable to non-controlling interests included in comparable earnings and other
 (481) (156) (101)
1,595  1,777  1,962 
Average exchange rate – U.S. to Canadian dollars
 1.37  1.35  1.30 
1     Prior year results have been recast to reflect continuing operations only.
2    Excludes interest expense on our inter-affiliate loans with the Sur de Texas joint venture which was fully offset in Interest income and other. These inter-affiliate loans were fully repaid in 2022.
Foreign exchange related to Mexico Natural Gas Pipelines
Changes in the value of the Mexican peso against the U.S. dollar can affect our comparable earnings as a portion of our Mexico Natural Gas Pipelines monetary assets and liabilities are peso-denominated, while our financial results are denominated in U.S. dollars for our Mexico operations. These peso-denominated balances are revalued to U.S. dollars, creating foreign exchange gains and losses that are included in Income (loss) from equity investments, Foreign exchange (gains) losses, net and Net income (loss) attributable to non-controlling interests in the Consolidated statement of income.
In addition, foreign exchange gains or losses calculated for Mexico income tax purposes on the revaluation of U.S. dollar‑denominated monetary assets and liabilities result in a peso‑denominated income tax exposure for these entities, leading to fluctuations in Income from equity investments and Income tax expense. This exposure increases as our U.S. dollar‑denominated net monetary liabilities grow.
The above exposures are managed using foreign exchange derivatives, although some unhedged exposure remains. The impacts of the foreign exchange derivatives are recorded in Foreign exchange (gains) losses, net in the Consolidated statement of income. Refer to the Other information – Financial risks and Financial instruments sections for additional information.
TC Energy Management's discussion and analysis 2024 | 79

The period end exchange rates for one U.S. dollar to Mexican pesos were as follows:
December 31, 2024 20.87 
December 31, 2023 16.91 
December 31, 2022 19.50 
A summary of the impacts of transactional foreign exchange gains and losses from changes in the value of the Mexican peso against the U.S. dollar and associated derivatives is set out in the table below:
year ended December 31
(millions of $) 2024 2023 2022
Comparable EBITDA – Mexico Natural Gas Pipelines1
 115  (83) (32)
Foreign exchange gains (losses), net included in comparable earnings (53) 224  54 
Income tax (expense) recovery included in comparable earnings 110  (133) (11)
Net (income) loss attributable to non-controlling interests included in comparable earnings2
 (11) —  — 
161  8  11 
1Includes the foreign exchange impacts from the Sur de Texas joint venture recorded in Income (loss) from equity investments in the Consolidated statement of income.
2Represents the non-controlling interest portion related to TGNH. Refer to the Corporate - Financial results section for additional information.
80 | TC Energy Management's discussion and analysis 2024

Financial condition
We strive to maintain financial strength and flexibility in all parts of the economic cycle. We rely on our operating cash flows to sustain our business, pay dividends and fund a portion of our growth. In addition, we access capital markets and engage in portfolio management activities to meet our financing needs and to manage our capital structure and credit ratings. More information on how our credit ratings can impact our financing costs, liquidity and operations is available in our Annual Information Form available on SEDAR+ (www.sedarplus.ca).
We believe we have the financial capacity to fund our existing capital program through predictable and growing cash flows from continuing operations, access to capital markets, portfolio management activities, joint ventures, asset-level financing, cash on hand and substantial committed credit facilities. Annually, in the fourth quarter, we renew and extend our credit facilities as required.
Financial Plan
Our capital program is comprised of approximately $25 billion of secured projects, as well as our projects under development, which are subject to key corporate and regulatory approvals. As discussed throughout this Financial condition section, our capital program is expected to be financed through our growing internally-generated cash flows and a combination of other funding options which may include:
•senior debt
•hybrid securities
•preferred shares
•asset divestitures and capital rotation
•project financing
•potential involvement of strategic or financial partners.
In addition, we may access additional funding options, as deemed appropriate, including common shares issued from treasury under our DRP and discrete common equity issuances.
Balance sheet analysis - from continuing operations
At December 31, 2024, excluding discontinued operations, our current assets totaled $5.5 billion and current liabilities amounted to $10.3 billion, leaving us with a working capital deficit of $4.8 billion compared to $0.8 billion at December 31, 2023. Our working capital deficiency is considered to be in the normal course of business and is managed through:
•our ability to generate predictable and growing cash flows from operations
•a total of $8.0 billion of committed revolving credit facilities available for short-term borrowing capacity, of which $7.6 billion of short-term borrowing capacity remains available, net of $0.4 billion backstopping outstanding commercial paper balances. We also have arrangements in place for a further $2.0 billion of demand credit facilities on which $1.1 billion remains available as of December 31, 2024
•additional $2.2 billion committed revolving credit facilities at certain of our subsidiaries and affiliates, on which no amounts have been drawn
•our access to capital markets, including through securities issuances, incremental credit facilities, capital rotation and DRP, if deemed appropriate.
Our total assets from continuing operations at December 31, 2024 were $117.9 billion compared to $109.5 billion at December 31, 2023. The increase primarily reflects our capital spending program, increased equity investments and a stronger U.S. dollar at December 31, 2024 compared to December 31, 2023 on translation of our U.S. dollar-denominated assets, partially offset by depreciation and working capital.
At December 31, 2024 our total liabilities from continuing operations were $79.6 billion, compared to $82.1 billion at December 31, 2023 due to the net effect of a reduction in debt, working capital and a stronger U.S. dollar at December 31, 2024 compared to December 31, 2023 on translation of our U.S. dollar-denominated liabilities.
TC Energy Management's discussion and analysis 2024 | 81

Consolidated capital structure - from continuing operations
The following table summarizes the components of our capital structure for continuing operations.
at December 31 Per cent
of total 		Per cent
 of total
(millions of $, unless otherwise noted) 2024 2023
Notes payable 387  1  —  — 
Long-term debt, including current portion 47,931  49  52,914  54 
Cash and cash equivalents (801) (1) (3,678) (4)
47,517  49  49,236  50 
Junior subordinated notes 11,048  11  10,287  10 
Preferred shares 2,499  3  2,499  3 
Common shareholders' equity 25,093  26  27,054  27 
Non-controlling interests 10,768  11  9,455  10 
96,925  100  98,531  100 
Provisions of various trust indentures and credit arrangements with certain of our subsidiaries can restrict those subsidiaries' ability and, in certain cases, our ability to declare and pay dividends or make distributions under certain circumstances. In the opinion of management, these provisions do not currently restrict our ability to declare or pay dividends. These trust indentures and credit arrangements also require us to comply with various affirmative and negative covenants and maintain certain financial ratios. We were in compliance with all of our financial covenants at December 31, 2024.
Cash flows1,2
The following tables summarize our consolidated cash flows.
year ended December 31
(millions of $) 2024 2023 2022
Net cash provided by operations 7,696  7,268  6,375 
Net cash (used in) provided by investing activities (6,909) (12,287) (7,009)
Net cash (used in) provided by financing activities (3,874) 8,093  487 
(3,087) 3,074  (147)
Effect of foreign exchange rate changes on cash and cash equivalents 210  (16) 94 
Increase (decrease) in cash and cash equivalents
 (2,877) 3,058  (53)
1    Includes continuing and discontinued operations.
2    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
82 | TC Energy Management's discussion and analysis 2024

Cash provided by operating activities1,2
year ended December 31
(millions of $) 2024 2023 2022
Net cash provided by operations 7,696  7,268  6,375 
Increase (decrease) in operating working capital
 (199) (207) 639 
Funds generated from operations
 7,497  7,061  7,014 
Specific items:
Liquids Pipelines business separation costs, net of current income tax 185  40  — 
Current income tax (recovery) expense on sale of PNGTS and non-core assets 148  —  — 
Third-party settlement, net of current income tax 26  —  — 
Focus Project costs, net of current income tax 21  54  — 
NGTL System ownership transfer costs 10  —  — 
Current income tax (recovery) expense on risk management activities 9  —  — 
Current income tax (recovery) expense on Keystone XL asset impairment charge and other (3) (14) 96 
Current income tax (recovery) expense on Keystone regulatory decisions (3) 53  27 
Current income tax expense on disposition of equity interest3
 —  736  — 
Milepost 14 insurance expense —  36  — 
Settlement of Mexico prior years' income tax assessments —  —  196 
Keystone XL preservation and other, net of current income tax —  14  20 
Comparable funds generated from operations
 7,890  7,980  7,353 
1    Includes continuing and discontinued operations.
2    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Refer to the Discontinued operations section for additional information.
3    Current income tax expense related to applying an approximate 24 per cent tax rate to the tax gain on sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf. This is offset by a corresponding deferred tax recovery resulting in no net impact to tax expense.
Net cash provided by operations
Net cash provided by operations increased by $428 million in 2024 compared to 2023 primarily due to higher funds generated from operations.
Net cash provided by operations increased by $893 million in 2023 compared to 2022 primarily due to the amount and timing of working capital changes and higher funds generated from operations.
Comparable funds generated from operations
Comparable funds generated from operations, a non-GAAP measure, helps us assess the cash generating ability of our businesses by excluding the timing effects of working capital changes, as well as the cash impact of our specific items.
Comparable funds generated from operations decreased by $90 million in 2024 compared to 2023 primarily due to lower comparable earnings, partially offset by increased distributions from our equity investments.
Comparable funds generated from operations increased by $627 million in 2023 compared to 2022 primarily due to higher comparable EBITDA, increased distributions from our equity investments, higher interest earned on short-term investments and net realized gains on derivatives used to manage our foreign exchange exposures, partially offset by higher interest expense.
TC Energy Management's discussion and analysis 2024 | 83

Cash (used in) provided by investing activities1
year ended December 31
(millions of $) 2024 2023 2022
Capital spending2
Capital expenditures (6,308) (8,007) (6,678)
Capital projects in development (50) (142) (49)
Contributions to equity investments
 (1,546) (4,149) (2,234)
(7,904) (12,298) (8,961)
Proceeds from sales of assets, net of transaction costs 791  33  — 
Other distributions from equity investments
 549  23  1,433 
Deferred amounts and other (352) 2  (41)
Keystone XL contractual recoveries 7  10  571 
Acquisitions, net of cash acquired —  (307) — 
Loans to affiliate (issued) repaid, net —  250  (11)
Net cash (used in) provided by investing activities (6,909) (12,287) (7,009)
1    Includes continuing and discontinued operations.
2    Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments net of Other distributions from equity investments of $3.1 billion in 2024 in the Canadian Natural Gas Pipelines segment (2023 - nil, 2022 - $1.2 billion in the Corporate segment). Refer to Note 5, Segmented information, Note 7, Coastal GasLink and Note 12, Loans receivable from affiliates, of our 2024 Consolidated financial statements for additional information.
Net cash used in investing activities decreased from $12.3 billion in 2023 to $6.9 billion in 2024 primarily as a result of decreased capital spending and lower contributions to equity investments primarily related Coastal GasLink LP and in part by higher proceeds from the sales of assets and distributions from equity investments.
Net cash used in investing activities increased from $7.0 billion in 2022 to $12.3 billion in 2023 as a result of higher contributions to equity investments primarily related to Coastal GasLink LP, as well as increased capital spending in 2023.
Capital spending1
The following table summarizes capital spending by segment.
year ended December 31
(millions of $) 2024 2023 2022
Canadian Natural Gas Pipelines 2,100  6,184  4,719 
U.S. Natural Gas Pipelines 2,575  2,660  2,137 
Mexico Natural Gas Pipelines 2,228  2,292  1,027 
Power and Energy Solutions 824  1,080  894 
Corporate 50  33  41 
7,777  12,249  8,818 
Discontinued operations
 127  49  143 
7,904  12,298  8,961 
1Capital spending reflects cash flows associated with our Capital expenditures, Capital projects in development and Contributions to equity investments net of Other distributions from equity investments of $3.1 billion in 2024 in the Canadian Natural Gas Pipelines segment (2023 - nil, 2022 - $1.2 billion in the Corporate segment). Refer to Note 5, Segmented information, Note 7, Coastal GasLink and Note 12, Loans receivable from affiliates, of our 2024 Consolidated financial statements for additional information.
84 | TC Energy Management's discussion and analysis 2024

Capital expenditures
Capital expenditures in 2024 were incurred primarily for the advancement of the Southeast Gateway pipeline, Columbia Gas and ANR projects, the NGTL System expansion as well as maintenance capital expenditures. Lower capital expenditures in 2024 compared to 2023 reflect reduced spending on NGTL System expansion and the Southeast Gateway pipeline.
Capital projects in development
Costs incurred during 2024 on Capital projects in development were primarily attributable to spending on projects in the Power and Energy Solutions segment.
Contributions to equity investments
Contributions to equity investments decreased in 2024 compared to 2023 mainly due to lower funds advanced to Coastal GasLink LP through the subordinated loan agreement.
On December 17, 2024, following the declared commercial in-service of the pipeline, Coastal GasLink LP repaid the $3,147 million balance owing to us under the subordinated loan agreement. Our share of equity contributions required to fund Coastal GasLink LP's repayment of the outstanding loan balance amounted to $3,137 million. The Contributions to equity investments and Other distributions from equity investments with respect to these activities are presented above on a net basis, although they are reported on a gross basis in our Consolidated statement of cash flows. Refer to Note 7, Coastal GasLink, of our 2024 Consolidated financial statements for additional information.
Contributions to equity investments increased in 2023 compared to 2022 mainly due to the draws of $2,520 million on the subordinated loan by Coastal GasLink LP in 2023 which were accounted for as in-substance equity contributions.
As part of refinancing activities with the Sur de Texas joint venture, on March 15, 2022, our peso-denominated inter-affiliate loan was fully repaid upon maturity in the amount of $1.2 billion and was subsequently replaced with a new U.S. dollar-denominated inter-affiliate loan of an equivalent $1.2 billion. The Contributions to equity investments and Other distributions from equity investments with respect to these refinancing activities are presented above on a net basis, although they are reported on a gross basis in our Consolidated statement of cash flows. Refer to the Other Information – Related party transactions section for additional information.
Proceeds from sales of assets
In 2024, TC Energy and its partner, Northern New England Investment Company, Inc., a subsidiary of Énergir, completed the sale of PNGTS to a third party. Our share of the proceeds was $743 million (US$546 million), net of transaction costs.
In 2024, we also completed the sale of other non-core assets for gross proceeds of $48 million.
In 2023, we completed the sale of a 20.1 per cent equity interest in Port Neches Link LLC to its joint venture partner, Motiva Enterprises, for gross proceeds of $33 million (US$25 million). As part of the Spinoff Transaction on October 1, 2024, our remaining interest in Port Neches Link LLC was transferred to South Bow.
Other distributions from equity investments
Other distributions from equity investments primarily relate to distributions from Millennium as a result of its debt financing program in 2024, as well as the return of capital from our equity investment in Iroquois.
In 2022, other distributions from equity investments primarily relates to our proportionate share of the Sur de Texas debt repayments. Subsequent to the refinancing activities with the joint venture discussed above, on July 29, 2022, the joint venture
entered into an unsecured term loan agreement with third parties, the proceeds of which were used to fully repay the
U.S. dollar-denominated inter-affiliate loan with TC Energy.
Acquisitions
In 2023, we acquired 100 per cent of the Class B Membership Interests in the Fluvanna Wind Farm located in Scurry County, Texas for US$99 million, before post-closing adjustments. We also acquired 100 per cent of the Class B Membership Interests in the Blue Cloud Wind Farm located in Bailey County, Texas for US$125 million, before post-closing adjustments.
Loans to affiliate
Loans to affiliate (issued) repaid, net, represent issuances and repayments on the subordinated demand revolving credit facility and the subordinated loan agreement that we entered with Coastal GasLink LP to provide additional liquidity and funding to the Coastal GasLink project. Refer to the Other Information – Related party transactions section for additional information.
TC Energy Management's discussion and analysis 2024 | 85

Cash (used in) provided by financing activities1
year ended December 31
(millions of $) 2024 2023 2022
Notes payable issued (repaid), net
 341  (6,299) 766 
Long-term debt issued, net of issue costs 8,089  15,884  2,508 
Long-term debt repaid (9,273) (3,772) (1,338)
Disposition of equity interest, net of transaction costs 419  5,328  — 
Junior subordinated notes issued, net of issue costs 1,465  —  1,008 
Cash transferred to South Bow, net of debt settlement (244) —  — 
Dividends and distributions paid (4,807) (3,052) (3,385)
Contributions from non-controlling interests
 21  —  — 
Common shares issued, net of issue costs 88  4  1,905 
Preferred shares redeemed —  —  (1,000)
Gains (losses) on settlement of financial instruments 27  —  23 
Net cash (used in) provided by financing activities (3,874) 8,093  487 
1    Includes continuing and discontinued operations.
Net cash provided by financing activities decreased by $12.0 billion in 2024 compared to 2023 primarily due to lower issuances and higher repayments of long-term debt, the receipt of the $5.3 billion (US$3.9 billion) proceeds in 2023 upon sale of a     40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf, as well as higher dividends and distributions paid in 2024, partially offset by net issuances of notes payable in 2024 compared to net repayments in 2023.
Net cash provided by financing activities increased by $7.6 billion in 2023 compared to 2022 primarily due to higher net issuances of long-term debt and repayments of notes payable, as well as the receipt of the $5.3 billion (US$3.9 billion) proceeds upon sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf.
The principal transactions reflected in our financing activities are discussed in further detail below.
Long-term debt issued
The following table outlines significant long-term debt issuances in 2024.
(millions of Canadian $, unless otherwise noted)
Company Issue date Type Maturity date Amount Interest rate
TRANSCANADA PIPELINES LIMITED
August 2024
Term Loan1
 August 2024 US 1,242  Floating
COLUMBIA PIPELINES OPERATING COMPANY LLC
September 2024 Senior Unsecured Notes October 2054 US 400  5.70  %
COLUMBIA PIPELINES HOLDING COMPANY LLC
September 2024
 Senior Unsecured Notes
October 2031
 US 400  5.10  %
January 2024
 Senior Unsecured Notes
January 2034
 US 500  5.68  %
1    In August 2024, TCPL entered into a term loan to facilitate the Spinoff Transaction and, in August 2024, the term loan was fully repaid and retired upon delivery of senior unsecured notes issued by 6297782 LLC, which was a wholly-owned subsidiary of TC Energy at the time. Refer to the Discontinued operations section for additional information.
86 | TC Energy Management's discussion and analysis 2024

Long-term debt retired/repaid
The following table outlines significant long-term debt retired/repaid in 2024.
(millions of Canadian $, unless otherwise noted)
Company
Retirement/repayment date
Type Amount
Interest rate
TRANSCANADA PIPELINES LIMITED
October 2024 Senior Unsecured Notes US 1,250  1.00  %
October 2024
Senior Unsecured Notes1
 US 850  6.20  %
October 2024
Senior Unsecured Notes2
 US 739  2.50  %
October 2024
Senior Unsecured Notes2
 US 441  4.88  %
October 2024
Senior Unsecured Notes1
 US 400  Floating
October 2024
Senior Unsecured Notes2
 US 313  4.75  %
October 2024
Senior Unsecured Notes2
 US 201  5.00  %
October 2024
Senior Unsecured Notes2
 US 180  5.10  %
October 2024
Medium Term Notes1
 600  5.42  %
October 2024
Medium Term Notes2
 575  4.18  %
October 2024
Medium Term Notes1
 400  Floating
August 2024
Term Loan3
 US 1,242  Floating
June 2024
Medium Term Notes
 750  Floating
NOVA GAS TRANSMISSION LTD.
March 2024 Debentures 100  9.90  %
ANR PIPELINE COMPANY
February 2024 Senior Unsecured Notes US 125  7.38  %
TC ENERGÍA MEXICANA, S. DE R.L. DE C.V.
Various 2024
Senior Unsecured Term Loan
 US 430  Floating
Various 2024 Senior Unsecured Revolving Credit Facility US 185  Floating
1In October 2024, callable notes were retired at par.
2In October 2024, TCPL purchased and cancelled notes at a 7.73 per cent weighted average discount, as a settlement of the cash tender offers.
3In August 2024, TCPL entered into a term loan to facilitate the Spinoff Transaction and, in August 2024 the term loan was fully repaid and retired upon delivery of senior unsecured notes issued by 6297782 LLC, which was a wholly-owned subsidiary of TC Energy at the time. Refer to the Discontinued operations section for additional information.
In October 2024, TCPL commenced and completed our cash tender offers to purchase and cancel certain senior unsecured notes and medium term notes at a 7.73 per cent weighted average discount. In addition, the Company repaid and retired outstanding callable notes at par. These extinguishments of debt resulted in a pre-tax net gain of $228 million, primarily due to the fair value discount and recognition of unamortized debt issue costs related to these notes. The net gain on debt extinguishment was recorded in Interest expense, in the Consolidated statement of income and has been excluded from comparable measures.
For more information about long-term debt and junior subordinated notes issued and long-term debt repaid in 2024, 2023 and 2022, refer to the notes to our 2024 Consolidated financial statements.
TC Energy Management's discussion and analysis 2024 | 87

Dividend reinvestment plan
Under the DRP, eligible holders of common and preferred shares of TC Energy can reinvest their dividends and make optional cash payments to obtain additional TC Energy common shares. From August 31, 2022 to July 31, 2023, common shares were issued from treasury at a discount of two per cent to market prices over a specified period.
Commencing with the dividends declared on July 27, 2023, common shares purchased under TC Energy's DRP are acquired on the open market at 100 per cent of the weighted average purchase price.
Share information
at February 7, 2025  
Common Shares issued and outstanding
  1.0 billion  
Preferred Shares issued and outstanding convertible to
Series 1 18.4 million Series 2 preferred shares
Series 2 3.6 million Series 1 preferred shares
Series 3 10 million Series 4 preferred shares
Series 4 4 million Series 3 preferred shares
Series 5 12.1 million Series 6 preferred shares
Series 6 1.9 million Series 5 preferred shares
Series 7 24 million Series 8 preferred shares
Series 9 16.7 million Series 10 preferred shares
Series 10 1.3 million
Series 9 preferred shares
Series 11 10 million Series 12 preferred shares
Options to buy common shares outstanding exercisable
4.4 million 3.1 million
On December 31, 2024, 42,200 Series 1 preferred shares were converted, on a one-for-one basis, into Series 2 preferred shares and 3,889,020 Series 2 preferred shares were converted, on a one-for-one basis, into Series 1 preferred shares.
On October 30, 2024, 1,297,203 Series 9 preferred shares were converted, on a one-for-one basis, into Series 10 preferred shares.
For more information on preferred shares refer to the notes to our 2024 Consolidated financial statements.
88 | TC Energy Management's discussion and analysis 2024

Dividends
year ended December 31 2024 2023 2022
Dividends declared
per common share1
 $3.7025  $3.72  $3.60 
per Series 1 preferred share $0.86975  $0.86975  $0.86975 
per Series 2 preferred share $1.68134  $1.62659  $0.82611 
per Series 3 preferred share $0.4235  $0.4235  $0.4235 
per Series 4 preferred share $1.52046  $1.46703  $0.66655 
per Series 5 preferred share $0.48725  $0.48725  $0.48725 
per Series 6 preferred share $1.55132  $1.55993  $0.80668 
per Series 7 preferred share $1.36613  $0.97575  $0.97575 
per Series 9 preferred share $1.02288  $0.9405  $0.9405 
per Series 10 preferred share
 $0.39807  —  — 
per Series 11 preferred share $0.83775  $0.83775  $0.83775 
per Series 15 preferred share —  —  $0.30625 
1    Dividends declared for fourth quarter 2024 reflect TC Energy’s proportionate allocation following the Spinoff Transaction.
Commencing with the dividends payable on January 31, 2025 to shareholders of record at the close of business on     December 31, 2024, the amounts reflect TC Energy’s proportionate allocation following the Spinoff Transaction. Refer to the Discontinued operations section for additional information.
On February 14, 2025, we announced a quarterly dividend on our outstanding common shares of $0.85 per common share for the quarter ending March 31, 2025, which represents an increase of 3.3 per cent from TC Energy's proportionate allocation of the dividend following the Spinoff Transaction. This equates to an annual dividend of $3.40 per common share.
Credit facilities
We have several committed credit facilities that support our commercial paper programs and provide short-term liquidity for general corporate purposes. In addition, we have demand credit facilities that are also used for general corporate purposes, including issuing letters of credit and providing additional liquidity.
At February 7, 2025, total committed revolving and demand credit facilities were $12.2 billion. These unsecured credit facilities included the following:
(billions of Canadian $, unless otherwise noted)
Borrower Description Matures Total facilities
Unused
capacity1
   
Committed, syndicated, revolving, extendible, senior unsecured credit facilities:
TCPL Supports commercial paper program and for general corporate purposes
December 2029
 3.0  2.2 
TCPL / TCPL USA
Supports commercial paper programs and for general corporate purposes of the borrowers, guaranteed by TCPL
December 2025
 US 1.0  US 0.2 
TCPL / TCPL USA
 Supports commercial paper programs and for general corporate purposes of the borrowers, guaranteed by TCPL
December 2027
 US 2.5  US 2.5 
Columbia Pipelines Holding Company LLC2
 Supports commercial paper program and general corporate purposes of the borrower
December 2027
 US 1.5  US 1.5 
Demand senior unsecured revolving credit facilities:
TCPL / TCPL USA Supports the issuance of letters of credit and provides additional liquidity; TCPL USA facility guaranteed by TCPL Demand 2.0 
3
 1.1 
3
1Unused capacity is net of commercial paper outstanding and facility draws.
2Columbia Pipelines Holding Company LLC is a partially owned subsidiary of TC Energy with 40 per cent non-controlling interest.
3Or the U.S. dollar equivalent.
TC Energy Management's discussion and analysis 2024 | 89

Contractual obligations
Our contractual obligations include our notes payable, long-term debt and junior subordinated notes, operating leases, purchase obligations and other liabilities incurred in our business such as cash contributions to the employee pension and post-retirement benefit plans.
Payments due (by period)
at December 31, 2024 Total < 1 year 1 - 3 years 4 - 5 years > 5 years
(millions of $)
Notes payable 387  387  —  —  — 
Long-term debt and junior subordinated notes1
 59,319  2,955  5,968  7,416  42,980 
Operating leases2
 614  73  139  127  275 
Purchase obligations and other3
 5,024  1,407  949  526  2,142 
  65,344  4,822  7,056  8,069  45,397 
1Excludes issuance costs and fair value adjustments.
2Includes future payments for corporate offices, various premises, services, equipment, land and lease commitments from corporate restructuring. Some of our operating leases include the option to renew the agreement for one to 25 years.
3Includes an estimated $110 million related to the transfer of pension assets to South Bow. The final transfer will be adjusted for investment returns and benefit payments from October 1, 2024, to the transfer date. Refer to the Obligations - pension and other post-retirement benefit plans section for more information.
Notes payable
Total notes payable outstanding at December 31, 2024 was $387 million (2023 – nil).
Long-term debt and junior subordinated notes
At December 31, 2024, we had $47.9 billion (2023 – $52.9 billion) of long-term debt and $11.0 billion (2023 – $10.3 billion) of junior subordinated notes.
We attempt to ladder the maturity profile of our debt. The weighted-average maturity of our junior subordinated notes and long‑term debt, excluding call features is approximately 18 years.
At December 31, 2024, scheduled interest payments related to our long-term debt and junior subordinated notes were as follows:
at December 31, 2024 Total < 1 year 1 - 3 years 4 - 5 years > 5 years
(millions of $)
Long-term debt 25,071  2,379  4,308  3,729  14,655 
Junior subordinated notes 50,755  660  1,557  1,742  46,796 
  75,826  3,039  5,865  5,471  61,451 
Purchase obligations
We have purchase obligations that are transacted at market prices and in the normal course of business, including long-term natural gas transportation and purchase arrangements.
Capital expenditure commitments include obligations related to the construction of growth projects and are based on the projects proceeding as planned. Changes to these projects, including cancellation, would reduce or possibly eliminate these commitments as a result of cost mitigation efforts.
We have entered into PPAs with solar and wind-power generating facilities ranging from 2025 to 2038, that require the purchase of generated energy and associated environmental attributes. At December 31, 2024, the total planned capacity secured under the PPAs is approximately 750 MW with the generation subject to operating availability and capacity factors. These PPAs do not meet the definition of a lease or derivative. Future payments and their timing cannot be reasonably estimated as they are dependent on when certain underlying facilities are placed in service and the amount of energy generated. Certain of these purchase commitments have offsetting sale PPAs for all or a portion of the related output from the facility.
90 | TC Energy Management's discussion and analysis 2024

At December 31, 2024, payments for purchase obligations and other were as follows:
at December 31, 2024 Total < 1 year 1 - 3 years 4 - 5 years > 5 years
(millions of $)
Canadian Natural Gas Pipelines          
Transportation by others1
 168  34  57  40  37 
Transportation by others - TQM1,2
 2,598  148  302  300  1,848 
Capital spending3
 253  246  4  2  1 
U.S. Natural Gas Pipelines
Transportation by others1
 628  159  230  93  146 
Capital spending3
 418  314  89  15  — 
Mexico Natural Gas Pipelines
Capital spending3
 207  207  —  —  — 
Power and Energy Solutions    
Capital spending3
 166  125  32  9  — 
Other
 226  30  46  40  110 
Corporate    
Capital spending3
 7  7  —  —  — 
South Bow pension plan assets held in trust4
 110  —  110  —  — 
Other
 243  137  79  27  — 
  5,024  1,407  949  526  2,142 
1Demand rates are subject to change. The contractual obligations in the table are based on demand volumes only and exclude variable charges incurred when volumes flow.
2Includes 100 per cent of the contracted obligation for the Canadian Mainline to transport volumes for its shippers utilizing the TQM pipeline to 2042, which we have a 50 per cent ownership interest in. The cost of the contracts flow through to the Canadian Mainline shippers and is determined based on the revenue requirement outlined in the current 2024-2025 TQM settlement agreement.
3    Amounts are primarily for expenditures for capital projects. Amounts are estimates and are subject to variability based on timing of construction and project requirements.
4    Related to the transfer of pension assets to South Bow. The final transfer will be adjusted for investment returns and benefit payments from October 1, 2024, to the transfer date. Refer to the Obligations - pension and other post-retirement benefit plans section for more information.
TC Energy Management's discussion and analysis 2024 | 91

GUARANTEES
Sur de Texas
We and our partner on the Sur de Texas pipeline, IEnova, have jointly guaranteed the financial performance of the entity which owns the pipeline. Such agreements include a guarantee and a letter of credit which are primarily related to the delivery of natural gas. The guarantee has terms that can be renewed in June 2025, with the annual option to extend for one year periods ending in 2053.
At December 31, 2024, our share of potential exposure under the Sur de Texas pipeline guarantees was estimated to be         $93 million with a carrying amount of less than $1 million.
Bruce Power
We and our joint venture partner on Bruce Power, BPC Generation Infrastructure Trust, have each severally guaranteed certain contingent financial obligations of Bruce Power related to a lease agreement. The Bruce Power guarantee has a term that can be renewed in December 2027 and is extendable for any number of successive two-year periods, with a final renewal period of three years ending in 2065.
At December 31, 2024, our share of the potential exposure under the Bruce Power guarantee was estimated to be $88 million with no carrying amount.
Other jointly-owned entities
We and our partners in certain other jointly-owned entities have also guaranteed (jointly, severally, jointly and severally, or exclusively) the financial performance of these entities. Such agreements include guarantees and letters of credit which are primarily related to delivery of natural gas. The guarantees have terms ranging to 2032.
Our share of the potential exposure under these assurances was estimated at December 31, 2024 to be approximately $59 million with a carrying amount of $1 million. In certain cases, if we make a payment that exceeds our ownership interest, the additional amount must be reimbursed by our partners.
OBLIGATIONS – PENSION AND OTHER POST-RETIREMENT BENEFIT PLANS
In 2024, we made no funding contributions to our defined benefit pension plans (DB Plans), $8 million for other post-retirement benefit plans and $71 million for the savings plan and defined contribution plans. Total letters of credit provided for the funding of solvency requirements to the Canadian DB plan at December 31, 2024 was $111 million (2023 – $244 million;
2022 – $322 million).
In 2025, we expect to make no contributions for the DB Plans, funding contributions of approximately $6 million for other     post-retirement benefit plans and approximately $71 million for the savings plans and defined contribution pension plans. We do not expect to issue additional letters of credit to the Canadian DB Plan for the funding of solvency requirements.
The net benefit cost for our DB Plans and other post-retirement plans decreased to $19 million in 2024 from $20 million in 2023 primarily due to a change in Canadian post-retirement benefits.
South Bow - transition of pension assets
As part of the Spinoff Transaction, certain TC Energy employees became employees of South Bow. Prior to the Spinoff Transaction, these employees in Canada and the U.S. participated in the DB Plans, DC Plans and savings plans, as applicable. As part of the Spinoff Transaction, the benefit obligations under the DB Plans in respect of the employees moving from TC Energy to South Bow were transferred to South Bow. An asset transfer application related to the Canadian DB Plan will be prepared in early 2025 outlining the proposed transfer of assets from TC Energy to South Bow. The Canadian DB Plan's assets to be transferred to South Bow are subject to regulatory approval and will be transferred when approval is received. As of December 31, 2024, these assets remain in the TC Energy DB Plan trust and have been reflected as Long-term assets of discontinued operations and a corresponding obligation to South Bow has been reflected as Long-term liabilities of discontinued operations on the Consolidated balance sheet. The assets related to the U.S. DB Plan were fully transferred to South Bow as at December 31, 2024.
92 | TC Energy Management's discussion and analysis 2024

Future net benefit costs and the amount we will need to contribute to fund our plans will depend on a range of factors including:
•interest rates
•actual returns on plan assets
•changes to actuarial assumptions and plan design
•actual plan experience versus projections
•amendments to pension plan regulations and legislation.
We do not expect future increases in the level of funding needed to maintain our plans to have a material impact on our liquidity or financial condition.
TC Energy Management's discussion and analysis 2024 | 93

Discontinued operations
On July 27, 2023, TC Energy announced plans to separate into two independent, investment-grade, publicly listed companies through the Spinoff Transaction. TC Energy shareholders voted to approve the spinoff in June 2024 and, on October 1, 2024, TC Energy completed the spinoff of its Liquids Pipelines business into the new public company, South Bow Corporation. TC Energy shareholders as of September 25, 2024 received one new TC Energy common share and 0.2 of a South Bow common share in exchange for each TC Energy common share held. TC Energy common shares resumed regular way trading on the TSX and NYSE on October 2, 2024. South Bow's common shares commenced regular way trading on the TSX on October 2, 2024 and on the NYSE on October 8, 2024, under the ticker symbol SOBO. Refer to Note 4, Discontinued operations, for additional information.
Agreements
TC Energy and South Bow have executed a series of agreements to outline the parameters and guidelines that govern their ongoing relationship and to specify the separation of assets and liabilities between the two corporations. A Transition Services Agreement has been established, the primary purpose of which is to specify certain services that TC Energy will provide to South Bow, for compensation, for a period of up to two years. These services primarily include access to and support of systems that South Bow will continue to use until it has fully implemented new systems to support its business processes and warehouse management services.
As part of the Spinoff Transaction, a Tax Matters Agreement was executed to govern TC Energy and South Bow's tax rights and obligations after the Spinoff Transaction. The agreement imposes certain restrictions on both TC Energy and South Bow in order to preserve the tax-free status of the spinoff and allocates tax liabilities in the event the Spinoff Transaction is not tax-free.
TC Energy and South Bow entered into a Separation Agreement setting forth the terms of the separation of the Liquids Pipelines business from the business of TC Energy, including the transfer of certain assets related to the Liquids Pipelines business from TC Energy to South Bow and the allocation of certain liabilities and obligations related to the Liquids Pipelines business between TC Energy and South Bow. The Separation Agreement provides, among other things, that TC Energy will indemnify South Bow for 86 per cent of total net liabilities and costs arising from the Milepost 14 incident that occurred on the Keystone Pipeline System in December 2022 and the existing variable toll disputes on the Keystone Pipeline System (excluding any future impacts to the variable toll after October 1, 2024) subject to a maximum liability to South Bow of $30 million, in aggregate, for those two matters. Due to the inherent uncertainties of the final amounts to be settled under these indemnities, any amounts that may ultimately be payable in respect of these net liabilities to South Bow could differ materially from those reported at     December 31, 2024.
Milepost 14 Incident
In December 2022, a pipeline incident occurred in Washington County, Kansas on the Keystone Pipeline System, releasing 12,937 barrels of crude oil. In June 2023, we completed the recovery of all released volumes and in October 2023, we returned Mill Creek to its natural flowing state. South Bow will maintain the commitment for long-term reclamation and environmental monitoring activities.
At December 31, 2023, we accrued a life-to-date environmental liability for the Milepost 14 incident of $794 million, before expected insurance recoveries and not including potential fines and penalties, which were indeterminable. Prior to the Spinoff Transaction, for the nine months ended September 30, 2024, amounts paid for the environmental remediation liability were $92 million (twelve months ended December 31, 2023 – $676 million). For the year ended December 31, 2024, we received $99 million (2023 – $575 million) from insurance policies related to the costs for environmental remediation.
We received insurance proceeds of $36 million related to the Milepost 14 incident that were collected from our wholly-owned captive insurance subsidiary and resulted in an impact to net income in the consolidated financial results of TC Energy. This amount has been excluded from comparable measures from discontinued operations. As part of the Separation Agreement, all future insurance recoveries will remain with TC Energy.
In fourth quarter 2024, we recorded a pre-tax expense of $37 million for our current estimate of potential incremental costs related to the Milepost 14 incident, which has been excluded from comparable measures from discontinued operations. This amount represents our 86 per cent share pursuant to the indemnity provisions in the Separation Agreement.

94 | TC Energy Management's discussion and analysis 2024

CER and FERC Proceedings
In 2019 and 2020, three Keystone customers initiated complaints before FERC and the CER regarding certain costs within the variable toll calculation. In December 2022, the CER issued a decision in respect of the complaint that resulted in an adjustment to previously charged tolls of $38 million, of which $27 million pertained to amounts reflected in 2021 and 2020 and was excluded from comparable measures from discontinued operations. The CER has established a proceeding to consider Keystone’s compliance filing required by the decision regarding the allocation of costs for drag reducing agent in the variable toll.
On July 25, 2024, FERC released its Order on Initial Decision in respect of the complaint. For the year ended December 31, 2024, we recognized an additional pre-tax charge of $12 million (2023 – $67 million including carrying charges) with respect to the decision, which has been excluded from comparable measures from discontinued operations. On October 8, 2024, South Bow submitted a compliance filing, which is subject to final FERC approval.
Subsequent rulings from both the CER and FERC, if any, will be subject to the indemnity provisions as outlined in the Separation Agreement.
Separation Costs
Liquids Pipelines business separation costs primarily include internal costs related to separation activities, legal, income tax, audit and other consulting fees, insurance provisions and net financial charges related to debt issued and held in escrow. For the years ended December 31, 2024 and 2023, Liquids Pipelines business separation costs of $197 million ($167 million after tax) and $40 million ($34 million after tax), respectively, were included in Net income (loss) from discontinued operations, net of tax in the Consolidated statement of income and have been excluded from our calculation of comparable measures from discontinued operations.
South Bow Debt
On August 28, 2024, South Bow Canadian Infrastructure Holdings Ltd. and 6297782 LLC, which were wholly-owned subsidiaries of TC Energy at the time, completed an offering of approximately $7.9 billion Canadian-dollar equivalent of senior unsecured notes and junior subordinated notes. Approximately $6.2 billion Canadian-dollar equivalent of the net proceeds was placed in escrow pending the completion of the Spinoff Transaction on October 1, 2024 and US$1.3 billion of senior unsecured notes were used to repay a TCPL term loan. Upon completion of the Spinoff Transaction, the escrowed funds were released to South Bow and used to repay indebtedness owed by South Bow and its subsidiaries to TC Energy and its subsidiaries. Liquids Pipelines business separation costs also included interest expense of $42 million and interest income of $28 million related to senior unsecured notes and junior subordinated notes issued on August 28, 2024 and held in escrow, which have been excluded from our calculation of comparable measures from discontinued operations.
Presentation of Discontinued Operations
Upon completion of the Spinoff Transaction, the Liquids Pipelines business was accounted for as a discontinued operation. Our presentation of discontinued operations includes revenues and expenses directly attributable to the Liquids Pipelines business. As such, the results of discontinued operations excludes shared costs related to TC Energy’s corporate services and governance functions that had provided support, and whose costs had been historically allocated, to the Liquids Pipelines segment. Depreciation expense related to Corporate shared assets has also been excluded from the results of discontinued operations. We have elected to allocate a portion of the interest expense incurred at the corporate level to discontinued operations. In 2024, discontinued operations represented nine months of Liquids Pipelines earnings compared to a full year of Liquids Pipelines earnings in 2023 and 2022. Prior year amounts have been recast to present the Liquids Pipelines business as a discontinued operation.

TC Energy Management's discussion and analysis 2024 | 95

RESULTS FROM DISCONTINUED OPERATIONS
year ended December 31
(millions of $, except per share amounts)
2024¹
2023²
2022²
Segmented earnings (losses) from discontinued operations
 716  1,039  1,182 
Interest expense
 (218) (297) (288)
Interest income and other 21  (30) 6 
Income (loss) from discontinued operations before income taxes
 519  712  900 
Income tax (expense) recovery
 (124) (100) (267)
Net income (loss) from discontinued operations, net of tax
 395  612  633 
Net income (loss) per common share from discontinued operations – basic
 $0.38  $0.60  $0.63 
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
Net income (loss) from discontinued operations, net of tax in 2024 was $395 million or $0.38 per share (2023 – $612 million or $0.60 per share; 2022 – $633 million or $0.63 per share), a decrease of $217 million or $0.22 per share compared to 2023 and a decrease of $21 million or $0.03 per share in 2023 compared to 2022.
NON-GAAP MEASURES
This MD&A references non-GAAP measures, which are described on page 24. These measures do not have any standardized meaning as prescribed by GAAP and therefore may not be comparable to similar measures presented by other entities.
The following specific items were recognized in Net income (loss) from discontinued operations, net of tax and were excluded from comparable earnings from discontinued operations:
2024
•a pre-tax charge of $197 million (after-tax $167 million) from Liquids Pipelines business separation costs related to the Spinoff Transaction, of which $173 million was recognized in segmented earnings (losses) from discontinued operations, $42 million was recorded in interest expense and $18 million was recorded in interest income
•a pre-tax expense of $37 million (after-tax $28 million) related to our current estimate of potential incremental costs resulting from the Milepost 14 incident. This amount represents our 86 per cent share pursuant to the indemnity provisions in the Separation Agreement
•a pre-tax expense of $21 million (after-tax $16 million) related to Keystone XL asset disposition and termination activities
•a pre-tax charge of $12 million (after-tax $10 million) as a result of the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods.
2023
•a pre-tax charge of $67 million (after-tax $52 million) as a result of the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods, which consists of a one-time pre-tax charge of $57 million and included accrued pre-tax carrying charges of $10 million
•a pre-tax charge of $40 million(after-tax $34 million) from Liquids Pipelines business separation costs related to the Spinoff Transaction
•a pre-tax accrued insurance expense of $36 million (after-tax $36 million) related to the Milepost 14 incident
•pre-tax preservation and other costs of $18 million (after-tax $14 million) related to the preservation and storage of the Keystone XL pipeline project assets
•a pre-tax recovery of $4 million (after-tax $18 million) related to the net impact of a U.S. minimum tax recovery on the 2021 Keystone XL asset impairment charge and other and a gain on the sale of Keystone XL project assets, offset partially by adjustments to the estimate for contractual and legal obligations related to termination activities.
96 | TC Energy Management's discussion and analysis 2024

2022
•a pre-tax recovery of $118 million (after-tax expense $5 million) related to the net impact of a U.S. minimum tax on the 2021 Keystone XL asset impairment charge and other, partially offset by a gain on the sale of Keystone XL project assets and adjustments to the estimate for contractual and legal obligations related to termination activities
•a pre-tax charge of $27 million (after-tax $20 million) due to the CER decision on Keystone issued in December 2022 in respect of a tolling-related complaint pertaining to amounts reflected in prior periods
•pre-tax preservation and other costs of $25 million (after-tax $19 million) related to the preservation and storage of the Keystone XL pipeline project assets.
Reconciliation of net income (loss) from discontinued operations, net of tax to comparable earnings from discontinued operations
year ended December 31
(millions of $, except per share amounts)
2024¹
2023²
2022²
Net income (loss) from discontinued operations, net of tax
 395  612  633 
Specific items (pre tax):
Liquids Pipelines business separation costs
 197  40  — 
Milepost 14 incremental costs
 37  —  — 
Keystone XL asset impairment charge and other 21  (4) (118)
Keystone regulatory decisions 12  67  27 
Milepost 14 insurance expense
 —  36  — 
Keystone XL preservation and other —  18  25 
Risk management activities
 (67) 34  (20)
Taxes on specific items3
 (30) (47) 114 
Comparable earnings from discontinued operations
 565  756  661 
Net income (loss) per common share from discontinued operations
 $0.38  $0.60  $0.63 
Specific items (net of tax)
 0.16  0.14  0.03 
Comparable earnings per common share from discontinued operations
 $0.54  $0.74  $0.66 
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3    Refer to page 101 for additional information.
TC Energy Management's discussion and analysis 2024 | 97

Comparable EBITDA to comparable earnings - from discontinued operations
Comparable EBITDA from discontinued operations represents segmented earnings (losses) from discontinued operations adjusted for the specific items described above and excludes charges for depreciation and amortization.
year ended December 31
(millions of $, except per share amounts)
2024¹
2023²
2022²
Comparable EBITDA from discontinued operations 1,145  1,516  1,418 
Depreciation and amortization (253) (332) (322)
Interest expense included in comparable earnings3
 (176) (287) (288)
Interest income and other included in comparable earnings4
 3  6  6 
Income tax (expense) recovery included in comparable earnings5
 (154) (147) (153)
Comparable earnings from discontinued operations
 565  756  661 
Comparable earnings per common share from discontinued operations
 $0.54  $0.74  $0.66 
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3    Excludes pre-tax Liquids Pipelines business separation costs of $42 million related to interest expense on the South Bow debt issuance in third quarter 2024 and carrying charges of $10 million for the year ended December 31, 2023 as a result of a pre-tax charge related to the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods.
4    Excludes pre-tax income of $18 million for the year ended December 31, 2024 related to the net impact of interest income on proceeds from the South Bow debt issuance on August 28, 2024, which were held in escrow and insurance provisions as well as a $36 million pre-tax insurance expense recorded in 2023 related to the Milepost 14 incident.
5    Excludes the impact of income taxes related to the specific items mentioned above as well as a $14 million U.S. minimum tax recovery in 2023 on the Keystone XL asset impairment charge and other related to the termination of the Keystone XL pipeline project and a $123 million income tax expense in 2022 as part of the Keystone XL asset impairment charge and other.
Comparable EBITDA from discontinued operations
Comparable EBITDA from discontinued operations was $371 million lower in 2024 compared to 2023 primarily due to the net effect of:
•nine months of Liquids Pipelines earnings included in 2024 compared to a full year of Liquids Pipelines earnings in 2023
•higher contracted and uncontracted volumes across the Keystone Pipeline System in 2024
•lower contributions from the liquids marketing business due to lower realized margins.
Comparable EBITDA from discontinued operations was $98 million higher in 2023 compared to 2022 primarily due to the net effect of:
•higher contracted and uncontracted volumes across the Keystone Pipeline System
•higher contributions from the Port Neches Link Pipeline System which began operations in March 2023.
Comparable earnings from discontinued operations
Comparable earnings from discontinued operations in 2024 were $191 million or $0.20 per common share lower than in 2023, and were primarily due to the impact of nine months of Liquids Pipelines business earnings in 2024 compared to a full year in 2023.
Comparable earnings from discontinued operations in 2023 were $95 million or $0.08 per common share higher than in 2022, and were primarily due to changes in comparable EBITDA from discontinued operations described above.
98 | TC Energy Management's discussion and analysis 2024

FINANCIAL RESULTS
The following is a reconciliation of comparable EBITDA from discontinued operations and comparable EBIT from discontinued operations (our non-GAAP measures) to segmented earnings (losses) from discontinued operations (the most directly comparable GAAP measure). Refer to page 24 for more information on non-GAAP measures we use.
year ended December 31
(millions of $)
2024¹
2023²
2022²
Keystone Pipeline System
 1,098  1,453  1,356 
Intra-Alberta pipelines3
 52  70  71 
Other
 (5) (7) (9)
Comparable EBITDA from discontinued operations
 1,145  1,516  1,418 
Depreciation and amortization (253) (332) (322)
Comparable EBIT from discontinued operations
 892  1,184  1,096 
Specific items (pre tax):
Liquids Pipelines business separation costs (173) (40) — 
Milepost 14 incremental costs (37) —  — 
Keystone XL asset impairment charge and other (21) 4  118 
Keystone regulatory decisions (12) (57) (27)
Keystone XL preservation and other —  (18) (25)
Risk management activities
 67  (34) 20 
Segmented earnings (losses) from discontinued operations
 716  1,039  1,182 
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3    Intra-Alberta pipelines includes Grand Rapids and White Spruce.
Segmented earnings from discontinued operations decreased by $323 million in 2024 compared to 2023 and decreased by     $143 million in 2023 compared to 2022 and included the specific items mentioned in the table above, which have been excluded from our calculation of comparable EBITDA from discontinued operations and comparable EBIT from discontinued operation. Refer to page 96 for additional information.
A stronger U.S. dollar in 2024 and 2023 had a positive impact on the Canadian dollar equivalent segmented earnings from our U.S. operations compared to 2023 and 2022, respectively.
Depreciation and amortization
Depreciation and amortization was $79 million lower in 2024 compared to 2023 due to nine months of Liquids Pipelines operations in 2024 compared to a full year of Liquids Pipelines operations in 2023 and $10 million higher in 2023 compared to 2022 primarily as a result of a stronger U.S. dollar.
TC Energy Management's discussion and analysis 2024 | 99

OTHER INCOME STATEMENT ITEMS
Interest expense
year ended December 31
(millions of $)
2024¹
2023²
2022²
Interest expense included in comparable earnings from discontinued operations
 (176) (287) (288)
Specific items:
Liquids Pipelines business separation costs (42) —  — 
Keystone regulatory decisions —  (10) — 
Interest expense from discontinued operations3
 (218) (297) (288)
1    Represents nine months of Liquids Pipelines allocated interest expense in 2024 compared to a full year of Liquids Pipelines allocated interest expense in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3    We have elected to allocate a portion of the interest expense incurred at the corporate level to discontinued operations. Refer to page 95 for additional information.
Interest expense included in comparable earnings from discontinued operations decreased by $111 million in 2024 compared to 2023 due to nine months of interest expense included in 2024 compared to a full year in 2023 and was generally consistent in 2023 compared to 2022.
Interest income and other
year ended December 31
(millions of $)
2024¹
2023²
2022²
Interest income and other included in comparable earnings
from discontinued operations
 3 6 6
Specific items:
Liquids Pipelines business separation costs 18 —  — 
Milepost 14 insurance expense
 —  (36) — 
Interest income and other from discontinued operations
 21 (30) 6
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
Interest income and other included in comparable earnings from discontinued operations was generally consistent in 2024 compared to 2023 and in 2023 compared to 2022.
100 | TC Energy Management's discussion and analysis 2024

Income tax (expense) recovery
year ended December 31
(millions of $)
2024¹
2023²
2022²
Income tax (expense) recovery included in comparable earnings from
discontinued operations
 (154) (147) (153)
Specific items:
Liquids Pipelines business separation costs 30  6  — 
Milepost 14 incremental costs 9  —  — 
Keystone XL asset impairment charge and other 5  14  (123)
Keystone regulatory decisions 2  15  7 
Keystone XL preservation and other —  4  6 
Risk management activities (16) 8  (4)
Income tax (expense) recovery from discontinued operations
 (124) (100) (267)
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
Income tax expense included in comparable earnings from discontinued operations increased by $7 million in 2024 compared to 2023 primarily due to lower foreign income tax rate differentials largely offset by lower earnings; and decreased by $6 million in 2023 compared to 2022 primarily due to higher foreign income tax rate differentials largely offset by higher earnings.
TC Energy Management's discussion and analysis 2024 | 101

Other information
RISK OVERSIGHT AND ENTERPRISE RISK MANAGEMENT
Risk management is embedded in all activities at TC Energy and is integral to the successful operation of our business. Our strategy ensures that risks and related exposures are aligned with our business objectives and risk tolerances. We achieve this through a centralized Enterprise Risk Management (ERM) program, which systematically identifies and assesses risks that could materially impact our strategic objectives.
The ERM program addresses risks related to executing our business strategies and supports practices for identifying and monitoring emerging risks. Specifically, the ERM framework offers a comprehensive process for risk identification, analysis, evaluation and mitigation. It also ensures ongoing monitoring and reporting to the Board of Directors, CEO, Executive         Vice-Presidents and the Chief Risk Officer.
Board and Committee Oversight
Our Board of Directors retains general oversight over all enterprise risks. Annually, the Board reviews the enterprise risk register and receives quarterly updates on emerging risks and their management and mitigation in accordance with TC Energy’s risk appetite and tolerances. Additionally, the Board receives detailed presentations on enterprise risks quarterly, with specific themes addressed during regular financial updates and strategic meetings. Special presentations are also delivered as needed or upon request.
The Governance Committee of our Board oversees the ERM program, ensuring comprehensive oversight of our risk management activities. In addition, other Board committees oversee specific risk types within their mandates:
•the Human Resources Committee oversees executive resourcing, organizational capabilities and compensation risk to ensure human and labour policies and remuneration practices align with our overall business strategy
•the HSSE Committee oversees operational, major project execution, health, safety, sustainability and environmental risks, including climate-related risks
•the Audit Committee oversees management's role in mitigating financial risk, including market risk, counterparty credit risk and cybersecurity risk.
Executive Leadership and Risk Management
Our Executive Leadership team is responsible for developing and implementing risk management plans and actions, with effective risk management reflected in their compensation. Each identified enterprise risk has a governance owner from the executive leadership team. Risk execution is overseen by an accountable Business Unit President or Senior Vice-President. These risk owners provide in-depth risk reviews to the Board annually.
Segment-Specific Risks
Key segment-specific financial, health, safety, and environment-related risks are covered in their respective sections of this MD&A. Further, our Report on Sustainability provides information on our approach to sustainability, including the oversight of sustainability-related risks and opportunities.
Enterprise Risk Monitoring and Key Risk Indicators
Risks related to our key enterprise risk themes are continuously monitored through our ERM program. The program includes a network of emerging risk liaisons strategically positioned across the organization, responsible for identifying potential enterprise-level risks and reporting them quarterly to the Board of Directors.
Additionally, as part of our ongoing commitment to enhancing the ERM program, we have identified and are adopting Key Risk and Performance Indicators (KRIs) for risk events that could impact our strategic objectives. These KRIs provide quantifiable metrics, objective rationale and meaningful trends for each enterprise risk, helping to inform the annual in-depth review of enterprise risks conducted by the Board.
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Operational risk
TC Energy operates a vast natural gas transmission network across North America, including numerous facilities, gas storage reservoirs and power-generation plants. Operational risks include the potential for significant ruptures or failures, especially in regions where pipelines traverse populated areas. Key factors contributing to these risks include integrity threats such as corrosion, cracking and manufacturing defects. Additionally, aging infrastructure and the potential for extreme weather conditions and other external forces further increase the likelihood of significant ruptures or operational failures.
The consequences of a significant rupture or operational failure can be severe and multifaceted. Potential impacts include loss of human life or severe injuries, environmental damage and extensive operational disruptions. Financial repercussions are also considerable, encompassing costs related to incident response, repairs, fines and penalties. Furthermore, such incidents can lead to incremental regulatory enforcement and reputational harm, which may strain customer relationships and jeopardize future projects.
To ensure the safe and reliable operation of its assets, TC Energy employs a robust Operational Management System, TOMS, that integrates comprehensive risk management and asset integrity practices. Current measures include a quantitative operational risk assessment process, integrity management programs and advanced inline inspection technologies. We also conduct failure investigations and root cause analyses to drive continuous improvement. Governance and oversight by senior management, along with an Emergency Management Program, ensure preparedness and effective response to potential incidents. TOMS standards, processes and procedures are continually improved based on lessons learned from internal and external incidents, as well as collaborative work with industry peers and regulators.
Regulatory risk
TC Energy operates in a highly regulated industry across North America, requiring various permits and approvals from federal, state, provincial and local government agencies. The regulatory landscape is highly complex, with overlapping and sometimes conflicting requirements from various levels of government. Changes in government can further introduce uncertainty and delays in obtaining necessary permits. Additionally, opposition groups can influence regulatory decisions through organized protests, legal challenges and negative media campaigns.
Failure to obtain or maintain regulatory approvals for energy infrastructure projects can lead to substantial financial and operational consequences. These include delays or cancellations of critical projects, increased operating costs due to additional compliance requirements and disruptions to existing infrastructure. Financial impacts also encompass lost development costs, reduced investor confidence and higher capital costs. Moreover, negative publicity and public opposition can damage our reputation, erode public trust and hinder our ability to operate effectively. These challenges can ultimately affect our competitive position and ability to meet growth objectives.
To address this risk, we have implemented several monitoring and mitigation strategies. These include proactive efforts to monitor the evolving regulatory environment, engage in strategic advocacy across all levels of government, cultivate enduring trust and alignment with stakeholders and respond promptly to emerging issues and concerns. These activities are designed to secure necessary approvals to support our growth objectives and mitigate potential delays and disruptions.
Access to capital at a competitive cost
We require significant capital in the form of debt and equity to finance our growth projects and manage maturing debt obligations. It is essential that we secure this capital at costs lower than the returns on our investments. Deterioration in market conditions, changes in investor and lender sentiment, geopolitical instability, higher interest rates and persistent inflation could adversely affect our access to and cost of capital. Additionally, factors such as investor ESG exclusionary screening, capacity limitations in capital markets and economic uncertainties can further compound these risks, potentially leading to higher borrowing costs and constrained growth.
A higher cost of capital can negatively impact our ability to deliver attractive returns on investments and inhibit both short and long-term growth. This could adversely affect our earnings and undermine the viability of capital projects. Additionally, higher costs can negatively impact investor confidence, the reported value of assets and liabilities and our overall financial performance.
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TC Energy employs a comprehensive strategy to monitor and mitigate these risks. Current mitigations include maintaining a high-quality and diversified banking syndicate, proactive engagement with lenders and credit rating agencies and balancing issuance strategies across multiple capital markets. We also actively manage our foreign exchange risk through hedging strategies and maintain a balanced debt portfolio to manage interest rate exposure. Ongoing mitigations involve developing new lending relationships and enhancing engagement with ESG-focused investors. Additionally, TC Energy continuously monitors government policies and industry developments to proactively address potential influences on capital flows.
Capital allocation
To remain competitive, TC Energy must provide essential energy infrastructure services in both supply and demand areas, offering solutions that appeal to our customers, while maintaining alignment with our strategic objectives. Capital allocation challenges include balancing investments to defend our existing footprint and service our customer base, investing in the highest-return, lowest-risk opportunities within our discretionary annual net capital limit and shaping the capital program to optimally utilize available capital. Additionally, there is a risk of diversifying into lower-carbon opportunities before they have adequately developed commercial and regulatory constructs.
Inefficient capital allocation can lead to the misallocation of financial resources to projects that do not align with our strategic objectives, increase exposure to high-risk projects and reduce financial performance. Additionally, failure to adapt to changing energy supply and demand fundamentals, including those related to lower-carbon forms of energy, may result in reputational damage, regulatory risks and the potential for stranded assets. Overall, these risks can cause strategic misalignment and diminish shareholder value.
We have a rigorous governance process to maintain capital allocation discipline. We limit annual net capital expenditures and high-grade our project development pipeline for purposes of pursuing lower risk and higher value opportunities. We also conduct analyses to confirm the resilience of the supply and demand markets we serve as part of our strategic reviews and regularly monitor industry trends and regulatory developments. Continuous improvements to the capital allocation process include enhanced investment review and due diligence, as well as conducting long-term scenario analyses to understand the portfolio effects of capital allocation choices.
Capital recovery risk
Capital recovery risk pertains to the challenge of both earning an acceptable return on invested capital and recovering the initial investment. This risk arises from potential misalignment between deal structures and our risk preferences, leading to capital exposure. Key contributors include inadequate risk assessments, difficulties in stakeholder collaboration, unforeseen changes in project scope or environment, financial constraints, macroeconomic volatility, counterparty risk and evolving public policy. Collectively, these factors threaten our financial stability and strategic objectives.
The inability to recover a return on capital can lead to unexpected capital expenditures, significant financial losses and reduced returns. It can erode trust and credibility with partners, investors, regulators and other key stakeholders. Additionally, poorly structured deals may divert management’s focus from core business activities to address arising issues, further impacting operational efficiency. The broader consequences include potential damage to our reputation and investor confidence, which are crucial for sustaining long-term growth and stability and preserving shareholder value.
TC Energy employs a robust due diligence process that includes comprehensive risk assessments and detailed contract negotiations. Continuous monitoring of risk exposures and mitigation measures is conducted throughout the lifecycle of each deal, high-grading our project development pipeline to the lowest-risk, highest value opportunities. Proactive engagement with counterparties and strategic partnerships helps manage and share risks effectively. Depreciation is recovered through regulated pipeline rates, allowing us to accelerate or decelerate the return of capital from our assets. Additionally, we leverage our diversified asset base and long-term contracts to stabilize cash flows and reduce exposure to market volatility.
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Project execution
Investing in large infrastructure projects requires significant capital commitments and carries considerable project execution risks. Potential shortages of skilled labour and expertise, supply chain lead times and disruptions and increasing project and regulatory complexity are among these risks. Collectively, these factors can lead to cost overruns, schedule delays, suboptimal project performance and increased safety vulnerabilities, ultimately impacting our financial performance, reputation and strategic growth.
Failure to effectively manage these risks can result in significant financial and operational consequences. Cost overruns and schedule delays can undermine the profitability and feasibility of projects, leading to increased contractual claims and disputes. Additionally, inadequate project execution can damage our reputation, reduce investor confidence and hinder future growth opportunities.
To help mitigate these risks, our Project Delivery System is integrated with our capital allocation process and is aligned with TOMS, optimizing project execution for safe, timely and on-budget performance. We develop projects to a sufficient maturity level to fully understand scope, cost, schedule and execution risk prior to sanctioning. This approach enables us to identify and consult stakeholders and proactively address project-specific constraints and risks. Commercial contracts are structured to recover development costs and minimize the impact of potential cost overruns, explicitly sharing execution risk where warranted. Additionally, we leverage project financing and partner involvement to manage capital at risk.
Talent risk
TC Energy's success hinges on attracting, retaining and developing a talented workforce with a deep understanding of the energy industry, geopolitical environment and various regulatory regimes across North America. Key talent-related risks include the loss of critical personnel, difficulties in securing and retaining talent in a highly competitive market and health and wellness issues that could impact workforce productivity.
Failure to manage talent-related risk can lead to several adverse outcomes, including a decline in employee morale and engagement, resulting in reduced productivity, efficiency and quality of work. High resignation rates, particularly among top talent, can disrupt operations and continuity, leading to increased recruitment and training costs. The organization may also face reputational damage if perceived as failing to address employee concerns, impacting its ability to attract and retain future talent. Furthermore, operational disruptions and a disengaged workforce can pose health and safety risks, ultimately affecting our overall performance and strategic execution.
To mitigate these risks, TC Energy employs a comprehensive talent risk management framework to assess needs and prioritize initiatives. We focus on employee development, engagement and well-being to foster a positive work environment and retain top talent. Our company-wide Pay Equity Plan promotes fairness in compensation practices, while our succession planning process ensures a steady pipeline of talented individuals are prepared to assume critical roles. Regular employee engagement surveys provide valuable insights and inform targeted recommendations. Additionally, we have integrated Diversity, Equity and Inclusion initiatives into our talent management strategies and implemented a hybrid work schedule to offer greater flexibility. Collectively, this approach promotes employee retention, minimizes the impact of potential talent losses and guides targeted development actions.
Enterprise security
Ensuring the security of our stakeholders, staff, and our digital and physical assets is paramount to maintaining the safety and reliability of our operations. Security risks encompass potential cyberattacks on industrial control systems and corporate digital assets, unauthorized data disclosures and physical attacks on our infrastructure. These risks are heightened by the increasing sophistication of cyber tactics, rising geopolitical tensions and the critical nature of our infrastructure.
A security incident can result in the misuse or disruption of critical information and functions, cause damage to our assets and potentially lead to safety and/or environmental incidents and inability to provide services. Resulting service interruptions may have cascading effects on supply chains, customer relationships and strategic goals. Additionally, such incidents can harm our reputation and trigger regulatory enforcement actions or litigation, negatively impacting our operations and/or financial position.
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TC Energy maintains an enterprise security program covering cyber and physical security. Our program is based on standards, assurance, risk management and prevention and mitigation activities. Our cyber and physical security risk preventative efforts include deploying security technology, defining secure processes, enhanced security measures for high-risk staff or facilities, and cyber and physical security awareness programs. Our mitigative activities include proactive monitoring for and responding to potential security incidents. We also maintain and regularly test incident response plans to manage and mitigate the impact of potential security incidents including cyberattacks. To further mitigate potential risks, we maintain appropriate insurance coverage against cyber and physical security incidents. To mitigate risks associated with third-party vendors and suppliers, we conduct vendor risk assessments which includes risk assessments focused on security standards, contractual safeguards, and ongoing monitoring.
We collaborate with government security agencies, law enforcement, and industry to stay informed and be proactive on evolving threats. Our prevention and mitigation strategies for both cyber and physical security are regularly reviewed and updated to align with regulatory and industry standards. The status of our enterprise security program is reported to the     Audit Committee quarterly.
TC Energy remains committed to continually improving our security posture and adapting to the ever-evolving threat landscape. By prioritizing security and investing in technologies and practices, we strive to protect our stakeholders, staff, assets, operations, and ensure the long-term sustainability of our business.
Climate-related risks
Our business, operations, financial condition and performance may be impacted by both the physical risks associated with climate change and the transition risks arising from the global transition to a lower-carbon economy. Climate-related risks, including climate policy and related developments, may intersect with and influence the enterprise risks outlined above. Therefore, these risks are systematically considered and assessed as part of the Enterprise Risk Management Framework.
Physical Risks
Climate change has the potential to create both acute and chronic physical risks that can negatively impact our operations. Acute physical risks could include extreme weather events such as hurricanes, wildfires and floods, whereas chronic physical risks could include longer-term shifts in climate patterns, temperature, precipitation and sea levels. Due to the complex nature of climate systems, it is difficult to predict the timing, frequency or severity of such events.
The physical risks from climate change could have significant financial implications, such as unexpected costs resulting from direct damage to our assets, loss of revenues due to business interruption or indirect effects such as value chain disruption. To mitigate these physical risks, we take climate change into account in the design and evaluation of our facilities and operating assets. Our engineering standards are regularly reviewed to ensure assets continue to be designed and operated to withstand the potential impacts of climate change. Additionally, our emergency response plans focus on quickly and effectively responding to severe weather events to minimize impacts.
As a further risk mitigation measure, we maintain insurance coverage to reduce the financial impact associated with damage to our assets due to extreme weather events. We may experience an increase in insurance premiums and deductibles, or a decrease in available coverage for our assets in areas subject to severe weather.
Transition Risks
Transition risks arise from the global shift to a lower-carbon economy. Transition risks include policy, legal, technological, market and reputational risks. These risks include, but are not limited to, changes in energy supply and demand trajectories, the pace and reliability of technological advancements, changes in decarbonization policies and regulations and stakeholder perceptions of our role in the transition to a lower-carbon economy. Financial implications from transition risks could include asset impairments due to new or amended climate-related regulations, reduced demand for fossil fuels, challenges in permitting projects and limited access to and/or increased cost of capital. Our financial performance could also be impacted by shifting consumer demands, insolvency of our significant customers and the development and deployment of new technologies.
Our exposure to climate-related transition risks and resulting policy changes is mitigated through our long-term, low-risk business strategy whereby much of our earnings are underpinned by regulated cost-of-service arrangements and/or long-term contracts with credit-worthy counterparties. Additional information on how we manage climate-related risks and opportunities can be found in the comprehensive TCFD and IFRS S2 alignment sections of our annual Report on Sustainability.
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Health, safety, sustainability and environmental matters
The Board's HSSE Committee oversees operational risk, major project execution risk, occupational and process safety, sustainability, security of personnel, environmental and climate-related risks, as well as monitoring development and implementation of systems, programs and policies relating to HSSE matters through regular reporting from management. We use an integrated management system that establishes a framework for managing these risks and is used to capture, organize, document, monitor and improve our related policies, standards and procedures.
TC Energy's Operational Management System, TOMS, leverages industry best practices and standards and incorporates applicable regulatory requirements. TOMS governs health, safety, environment and operational integrity matters at TC Energy. It is applicable across Canada, the U.S. and Mexico throughout the lifecycle of our assets and employs a continuous improvement cycle. The TOMS framework leverages continuous improvement through an annual management review process. This ensures the ongoing effectiveness of our overarching management system and supports a tiered assurance structure across all business units. The TC Energy assurance model is designed to provide effective management of health, safety, environmental, and operational integrity risks. Lessons learned are consistently shared and applied across our system where applicable. Additionally, any findings or insights from periodic audits conducted by our external regulators are also shared across the elements of our management system to ensure continuous improvement.
The HSSE Committee reviews performance and operational risk management. It receives updates and reports on:
•overall HSSE corporate governance
•operational performance
•asset integrity
•significant occupational safety and process safety incidents
•occupational and process safety performance metrics
•occupational health, safety and industrial hygiene, which includes physical and mental health, as well as psychological safety
•emergency preparedness, incident response and evaluation
•environment, including biodiversity and land reclamation
•developments in and compliance with applicable legislation and regulations, including those related to the environment
•prevention, mitigation and management of risks related to HSSE matters, including climate change or business interruption risks, such as pandemics, which may adversely impact TC Energy
•sustainability matters, including social, environmental and climate-related risks and opportunities, as well as related non-regulatory public disclosures such as our annual Report on Sustainability and our Reconciliation Action Plan.
There are two separate committees that report to the Board HSSE Committee:
•a Sustainability Management Committee, comprised of senior leaders, that provides strategic leadership and direction on environmental, social and governance issues to integrate sustainability principles across the company’s operations and projects
•an Operating Committee that is comprised of senior leaders, that is responsible for making enterprise decisions in support of safety improvements, management system governance and operational risk management.
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Health, safety and asset integrity
The safety of our employees, contractors and the public, the integrity of our pipelines and our power and energy solutions infrastructure, are a top priority. All assets are designed, constructed, commissioned, operated and maintained with full consideration given to safety and integrity and are placed in service only after all necessary requirements, both regulatory and internal, have been satisfied.
In 2024, we spent $2.0 billion (20231 – $2.0 billion) for pipeline integrity on the natural gas pipelines we operate, which includes expenditures related to our modernization program within our U.S. Natural Gas Pipelines business. Pipeline integrity spending will fluctuate based on the results of on-going risk assessments conducted on our pipeline systems and evaluations of information obtained from recent inspections, incidents and maintenance activities.
Under the approved regulatory models in Canada, non-capital pipeline integrity expenditures on CER-regulated natural gas pipelines are generally treated on a flow-through basis and, as a result, fluctuations in these expenditures generally have no impact on our earnings. Non-capital pipeline integrity expenditures on our U.S. natural gas pipelines are primarily treated as operations and maintenance expenditures and are typically recoverable through tolls approved by FERC.
Spending associated with process safety and integrity is used to minimize risk to employees, contractors, the public, equipment and the surrounding environment and also prevent disruptions to serving the energy needs of our customers.
As described in the Risk oversight and enterprise risk management section above, we have a set of procedures in place to manage our response to natural disasters, which include catastrophic events such as forest fires, tornadoes, earthquakes, floods, volcanic eruptions and hurricanes. The procedures, which are included in our Emergency, Business Continuity and Security element of TOMS, are designed to help protect the health and safety of our employees and contractors, minimize risk to the public and limit the potential for adverse effects on the environment. We are committed to protecting the health and safety of all individuals involved in our activities. Occupational health, safety and industrial hygiene provides comprehensive strategies for health promotion and protection. We are committed to delivering effective programs that:
•reduce the human and financial impact of illness and injury
•ensure fitness for work
•strengthen worker resiliency
•build organizational capacity by focusing on individual wellbeing, health education, leader support and improved working conditions to sustain a productive workforce
•increase mental wellbeing awareness, provide various health and wellness supports and training to employees and leaders, measure the success of programs and improve psychological safety
•foster a positive safety culture by building human and organizational performance to strengthen our cultural defenses and develop error-tolerant systems to better protect our people.
Environmental risk, compliance and liabilities
Through the implementation of TOMS, TC Energy proactively and systematically manages environmental hazards and risks throughout the lifecycle of our assets. We complete environmental assessments for our projects, which include field studies that examine existing natural resources, biodiversity and land use along our proposed project footprint, such as vegetation, soils, wildlife, water resources, wetland and protected areas. We consider the information collected during environmental assessments and where sensitive habitats or areas of high biodiversity value are identified, we apply the biodiversity protection hierarchy and avoid those areas, as practicable. Where those areas cannot be avoided, we minimize our disturbance, restore and reclaim the disturbed area and provide offsets where required. To conserve and protect the environment during construction, information gathered for an environmental impact assessment is used to develop project-specific environmental protection plans. Whenever the potential exists for a proposed facility or pipeline to interact with water resources, we conduct evaluations to understand the full nature and extent of the interactions. When we temporarily use water to test the integrity of our pipelines, we adhere to strict regulatory requirements and ensure water meets applicable water quality standards before it is discharged or disposed of and when our construction activities involve crossing waterbodies, we implement protection measures to avoid or minimize potential adverse effects. Project plans are communicated with stakeholders and Indigenous communities, as applicable and engagement with these groups informs the environmental assessments and protection plans.
1 Prior year results have been recast to reflect continuing operations only.
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Our primary sources of risk related to the environment include:
•changing regulations and requirements coupled with increased costs related to impacts on the environment
•product releases which may cause harm to the environment (land, water and air)
•use, storage and disposal of chemicals and hazardous materials
•natural disasters and other catastrophic events, including those related to climate change, which may impact our operations.
Our assets are subject to federal, state, provincial and local environmental statutes and regulations governing environmental protection, including air and GHG emissions, water quality, species at risk, wastewater discharges and waste management. Operating our assets requires obtaining and complying with a wide variety of environmental registrations, licenses, permits and other approvals and requirements. Failure to comply could result in administrative, civil or criminal penalties, remedial requirements, or orders affecting future operations.
TOMS includes requirements for TC Energy to continually monitor our facilities for compliance with all material legal and regulatory environmental requirements across all jurisdictions where we operate. We also comply with all material legal and regulatory permitting requirements in our project routing and development. We routinely monitor proposed changes to environmental policy, legislation and regulation. Where the risks are uncertain or have the potential to affect our ability to effectively operate our business, we comment on proposals independently or through industry associations.
We are not aware of any material outstanding orders, claims or lawsuits against us related to releasing or discharging any material into the environment.
Compliance obligations can result in significant costs associated with installing and maintaining pollution controls, fines and penalties resulting from any failure to comply and potential limitations on operations. Remediation obligations can result in significant costs associated with the investigation and remediation of contaminated properties and with damage claims arising from the contamination of properties.
The timing and complete extent of future expenditures related to environmental matters is difficult to estimate accurately because:
•environmental laws and regulations and their interpretations and enforcement change
•new claims can be brought against our existing or discontinued assets
•our pollution control and clean-up cost estimates may change, especially when our current estimates are based on preliminary site investigations or agreements
•new contaminated sites may be found or what we know about existing sites could change
•where there is potentially more than one responsible party involved in litigation, we cannot estimate our joint and several liability with certainty.
At December 31, 2024, accruals related to these obligations totaled $8 million (2023 – $19 million) representing the estimated amount we will need to manage our currently known material environmental liabilities. We believe we have considered all necessary contingencies and established appropriate reserves for environmental liabilities; however, a risk exists that unforeseen matters may arise requiring us to set aside additional amounts. We adjust reserves regularly to account for changes in liabilities.
Climate change and related regulation
We own assets and have business interests in a number of regions subject to GHG emissions regulations, including GHG emissions management and carbon pricing policies. In 2024, we incurred $141 million (2023 – $109 million) of expenses under existing carbon pricing programs. Across North America, there are a variety of new and evolving initiatives and policies in development at the federal, regional, state and provincial levels aimed at reducing GHG emissions. We actively monitor, participate in the regulatory review process as appropriate and submit formal comments to regulators as initiatives are undertaken and as policies are implemented. We support transparent climate change policies that promote environmentally and economically responsible natural resource development. Our assets in specific geographies are currently subject to GHG regulations. While near-term government policy objectives may influence the pace of GHG regulations, we expect that the number of our assets subject to GHG regulations will continue to increase over time and across our footprint. Changes in regulations may result in higher operating costs, other expenses or capital expenditures to comply with new or more stringent regulations. The following existing jurisdictional policies and anticipated policies sections describe some of the more relevant existing and anticipated policies applicable to our business.
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Existing jurisdictional policies
Canadian jurisdictions
•Federal: The Regulations Respecting Reduction in the Release of Methane and Certain Volatile Organic Compounds (VOCs) took effect in January 2020 to reduce the oil and gas sector's methane emissions by 40 to 45 per cent below 2012 levels by 2025. Alberta, British Columbia and Saskatchewan have released their own methane regulations that replace the federal regulations for provincially-regulated assets. For federally-regulated facilities in these jurisdictions, the federal methane regulations are applicable. Compliance with the regulations requires leak detection and repair (LDAR) surveys and a reduction of vented emissions from specific equipment. Power facilities are not affected by this regulation at the current time
•Federal: The Federal OBPS regulation imposes carbon pricing for larger industrial facilities and sets federal benchmarks for GHG emissions for various industry sectors. This regulation applies to our assets in Manitoba. As a result of the Federal program, our assets across Canada are all subject to some type of carbon pricing and the costs under these programs are recovered through tolls. In 2024, the carbon price was $80/tonne, currently scheduled to increase by $15/tonne every year to $170/tonne in 2030
•Federal: On December 19, 2024, ECCC published the final Clean Electricity Regulations (CERs), targeting a net-zero electricity system by 2050. The CERs mandate an annual GHG emissions limit based on 65 tonnes CO2/GWh for fossil fuel power generation units with a capacity of 25 MW or more starting in 2035 and 0 tonnes CO2/GWh in 2050. Though there are limited compliance flexibilities, concerns persist on the CERs’ potential effect on energy affordability and reliability in certain jurisdictions. We continue to evaluate the operational and financial impact on our cogeneration fleet
•British Columbia: As of April 2024, British Columbia implemented a provincial OBPS in place of the carbon tax, for taxing GHG emissions from fossil fuel combustion at industrial facilities. The B.C. OBPS applies to our assets in British Columbia and compliance costs are recovered through tolls. With the implementation of the B.C. OBPS, the CleanBC Industrial Incentive Program, which offered carbon tax rebates to low emitting industrial facilities, will be phased out as of 2025
•Alberta: In Alberta, the Technology Innovation and Emissions Reduction (TIER) regulation has been in effect since January 2020. The TIER regulation requires established industrial facilities with GHG emissions above a certain threshold to reduce their emissions below an intensity baseline. The TIER system covers all of our natural gas pipelines and Power and Energy Solutions assets in Alberta. Compliance costs with respect to our regulated Canadian natural gas pipelines are recovered through tolls. A portion of the compliance costs for the Power and Energy Solutions assets are recovered through market pricing and hedging activities
•Québec: Québec has a GHG cap-and-trade program under the Western Climate Initiative (WCI) GHG emissions market. In Québec, our Bécancour cogeneration plant is subject to this program as are the Canadian Mainline and TQM natural gas pipeline facilities. The provincial government allocates free emission units for a portion of Bécancour's compliance requirements. The remaining requirements are met with GHG instruments purchased at auctions or secondary markets. The costs of these emissions units are recovered through commercial contracts. For TQM and the Canadian Mainline assets in Québec, compliance instruments have been or will be purchased to comply with the WCI requirements with these compliance costs being recovered through tolls
•Ontario: The Federal OBPS in Ontario was replaced on January 1, 2022 by the Ontario Emissions Performance Standards (OEPS) program. The OEPS program applies to our Canadian Mainline operations in the province and costs under this program are recovered in tolls
•Saskatchewan: The Federal OBPS in Saskatchewan was replaced on January 1, 2023 by the Saskatchewan Output-Based Performance Standard program for pipeline transmission sector assets. The regulation applies to our Canadian Mainline and Foothills operations in the province and costs under this program are recovered in tolls.
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U.S. jurisdictions
•Federal: On December 2, 2023, the United States Environmental Protection Agency (USEPA) released a final rule that amends and supplements the New Source Performance Standards – Subpart OOOO series of volatile organic compound and methane emissions regulations for the oil and natural gas industry. The rule, collectively referred to as the “Methane Rule,” sets performance standards for new, modified, or reconstructed sources after December 2022 (OOOOb) and establishes emission guidelines (EGs) for existing sources prior to December 2022 (OOOOc). Under OOOOc, the states will submit their plans to meet the EGs for existing sources to the USEPA within 24 months after publication of the final rule and existing compressor stations would be required to comply with a state’s new EGs no later than 36 months after the state plan is submitted to USEPA. The Methane Rule includes fugitive component LDAR requirements, a zero-emission process (pneumatic) controller standard, emission limitations for reciprocating and centrifugal compressors and a third-party reporting program facilitated by USEPA for identifying large gas release events (Super Emitter program). The OOOOb standards will apply to a relatively limited number of facilities and the costs of compliance are anticipated to be incorporated into new and modified facilities moving forward. The OOOOc standards would apply to a larger number of existing facilities, but impacts will be subject to the requirements of yet to be issued state EG proposals and actual compliance deadlines, which will vary based on state and/or location
•Federal: The USEPA “Good Neighbor Plan”, effective August 2023, sets new limits for emissions of nitrogen oxides (NOx) from reciprocating internal combustion engines (RICE) by May 2026. The rule could cost TC Energy over US$500 million in mitigation measures, but Federal Circuit courts have granted stays in 12 states, including eight states in which TC Energy has affected RICE, reducing our compliance obligations pending the outcomes of these proceedings. Additionally, TC Energy, among other peer companies and industry groups, is party to ongoing legal proceedings in the D.C. Circuit and on June 27, 2024, the Supreme Court granted a nationwide emergency stay of the Rule that will last for the duration of the pending litigation in the D.C. Circuit and until the Supreme Court resolves petitions for certiorari (if any are filed). The         D.C. Circuit is expected to issue a final decision in the second half of 2025. If the rule is ultimately upheld, the USEPA is expected, but not required, to provide industry with additional time beyond its May 1, 2026 compliance deadline to come into compliance
•Federal: USEPA finalized changes to the Greenhouse Gas Reporting Program (GHGRP) for how oil and gas sources tally and report their methane emissions (Subpart W) on May 6, 2024. The Final Rule finalizes previously proposed GHGRP amendments and also addresses USEPA’s mandate, as defined in the Inflation Reduction Act (IRA), to amend Subpart W for the purposes of improving methane emission estimates associated with the IRA waste emissions charge for natural gas operations. USEPA did not finalize changes in the GHGRP for how oil and gas sources tally and report their energy consumption (Subpart B) via a final rule at this time. The Final Rule effects various changes that would add new reporting sources, modify calculation and reporting methodologies and drive more granular data collection. The Final Rule is still being assessed, but the methodological changes could result in material changes to TC Energy’s publicly reported emissions
•Federal: The IRA was passed and signed into law in August 2022. The IRA instructed USEPA to implement a waste methane fee program by 2024 based on GHG emissions reported to USEPA as required by 40 CFR 98 Subpart W. In response, on November 8, 2024, USEPA finalized a rule to implement the methane Waste Emissions Charge (“WEC”) program. TC Energy reports to Subpart W for the natural gas transmission compression, underground natural gas storage and onshore natural gas transmission pipeline industry segments. For these industry segments, the WEC imposes and collects a fee on methane emissions that exceeds 0.11 per cent of the natural gas sent for sale from the facility. The proposed fee is US$900/tonne for 2024, US$1,200/tonne for 2025 and US$1,500/tonne for 2026 reporting and forward. In an initial assessment, there would be no fee impact to TC Energy based on 2023 emissions. Over the longer term, potential WEC liability is expected to be low as U.S. natural gas facilities are anticipated to become eligible for a regulatory exemption afforded by compliance with the Methane Rule
•California: On September 27, 2024, California signed into law bill SB-219, which amends portions of Sections 38532 and 38533 of the California Health and Safety Code that were established in previous bills SB-253 and SB-261. SB-253 and SB-261 require public and private U.S. companies that perform certain business activities in California to disclose their GHG emissions and climate-related financial risks, respectively. Entities within the scope of SB-261 must prepare and make available on their public websites a climate-related financial risk report by January 1, 2026. Applicability to TC Energy is under evaluation
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•California: California Air Resource Board has revised Subarticle 13 of the Greenhouse Gas Emission Standards for Crude Oil and Natural Gas Facilities. The regulation applies to three Tuscarora facilities. The revised regulation required a new LDAR monitoring plan by July 1, 2024. The regulation also now requires monitoring and repair of components less than or equal to 0.5 inch and added new requirements for remotely detected plumes
•California: California also has a GHG cap-and-trade program linked with Québec's program through the WCI. All Tuscarora facilities fall below the threshold requiring participation in the GHG cap-and-trade program. However, power trading activities in the state do trigger compliance thresholds. These requirements are met with GHG instruments purchased at auctions or secondary markets
•Pennsylvania: The Pennsylvania Department of Environmental Protection has an LDAR program for new source installations which require leak repair within 15 days of discovery
•Ohio: Effective March 2022, the Ohio Environmental Protection Agency (OEPA) finalized Reasonable Available Control Technologies (RACT) requirements and limitations for emissions of NOx from stationary sources in the Cleveland non-attainment area. Columbia Gas Transmission has four facilities in the Cleveland non-attainment area, with two facilities impacted by the rule. A RACT Study was submitted for one of the stations subject to the rule, outlining the steps and cost necessary to install controls by March 2025 to comply with the rule. The other facility subject to the rule is required to perform annual tune-ups to achieve compliance
•Maryland: Effective November 2020, the Maryland Department of the Environment (MDE) finalized a methane regulation program for new and existing natural gas facilities that includes an LDAR program, emission control and reporting requirements, plus a requirement to notify not only the MDE, but also the public of any events above a specific threshold. We have one electric-powered compressor station and associated pipeline segments impacted by this regulation
•Washington: In late 2022, the Washington Department of Ecology adopted the Cap-and-Invest Program (CIP), which became effective in January 2023 and established a comprehensive, market-based program to reduce carbon pollution and achieve the GHG emissions reduction goals established by the State legislature. The CIP sets a declining limit, or cap, on overall carbon emissions in the state and requires businesses to obtain allowances equal to their covered GHG emissions. Under the CIP, companies are incented to reduce emissions to avoid higher compliance costs, as the cost to obtain allowances will increase as the supply of allowances decreases over time. GTN has three impacted compressor station facilities and cost exposure under the CIP is mainly driven by throughput and fuel forecast data, as well as price volatility in the newly established CIP allowance market. As an active participant in the CIP allowance market, GTN met its first base compliance obligation for 2023 and projected obligation for 2024. Electricity imports are also covered under the CIP, however these remained below compliance thresholds in 2024
•New York: On February 2, 2022, the New York Department of Environmental Conservation (NY DEC) adopted 6 NYCRR         Part 203, “Oil and Natural Gas Sector” with an effective date of March 3, 2022 and an initial compliance period commencing January 1, 2023. Part 203 regulates VOCs and methane emissions from the oil and gas sector. Compliance obligations include leak detection and repair at operated storage wells, compressor stations and city gate meter and regulator sites; blowdown notifications, reporting of pigging activities, as well as a baseline inventory for all assets in New York
•Michigan: In April 2023, the Michigan Department of Environment, Great Lakes and Energy (EGLE) published its final RACT requirements and emission limitations for major stationary sources of VOCs in specific counties of the state (2015 ozone non-attainment area). Specifically, storage vessels at two ANR compressor stations are impacted by this rule. Future storage vessels installed at compressor stations in specific counties in the state may require additional controls depending on their size and throughput.
Mexico jurisdictions
•Federal: The General Climate Change Law (LGCC) establishes various public policy instruments, including the National Emissions Registry and its regulations, which allow for the compilation of information on the emission of compounds and GHG emissions of the different productive sectors of the country. The LGCC defines the National Inventory of Emissions as the document that contains the estimate of anthropogenic emissions by sources and absorption by sinks in Mexico. The LGCC has the objective to reduce national emissions, through policies and programs that promote the transition to a sustainable, competitive and lower-carbon economy, including market instruments, incentives and other alternatives that improve the cost-efficiency of specific mitigation measures, reducing their economic costs and promoting competitiveness, technology transfer and the promotion of technological development. This law requires annual reporting of our GHG emissions
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•Federal: The Government of Mexico published a regulation in 2018 that established guidelines for the prevention and control of methane emissions from the hydrocarbon sector. Companies are required to prepare a Program for the Comprehensive Prevention and Control of Methane Emissions (PPCIEM) which includes identification of sources of methane, quantification of baseline emissions and an estimate of the expected GHG emission reductions from prevention and control activities. This regulation requires the PPCIEM, through which operational and technological practices are adopted, to determine a GHG emissions intensity reduction goal that must be met within a period not exceeding six calendar years from the delivery of the PPCIEM. TC Energy developed and applied the PPCIEM to all of its facilities in Mexico in 2020
•Federal: The Secretariat of Environment and Natural Resources published an agreement to progressively and gradually establish an emissions commerce system in Mexico and comply with the LGCC. It functioned as a three-year pilot from 2020 to 2022 allowing the Secretariat to test the design and rules of the system, as well as evaluate its performance and then propose adjustments for a subsequent operational phase after 2022. The Emission Rights Tracking System is the electronic platform where the emission rights and compensation credits are issued, transacted and cancelled, through which the participants interact to fulfill their obligations. It has already been formally established and it is possible that we will have to participate as a company if we exceed 100 ktCO2e in any of our systems. However, currently all our systems in Mexico are below the emissions threshold, so this instrument has not been used
•Federal: The Mexican accounting and sustainability standard setter, Consejo Mexicano de Normas de Información Financiera y Sostenibilidad (CINIF), published the Mexican sustainability standards (Normas de Información de Sostenibilidad or NIS) applicable to all private entities that report their financial statements under Mexican Financial Reporting Standards. The NIS requires the disclosure of 30 sustainability indicators across environmental, social and governance topics for fiscal years beginning on or after January 1, 2025. These requirements will apply to certain TC Energy Mexican entities.
Anticipated policies
Canadian jurisdictions
•Federal: ECCC committed to expand on the current methane reduction regulations and released draft amendments in December 2023 to reduce the oil and gas sector methane emissions by at least 75 per cent below 2012 levels by 2030. The draft amendments introduce a risk-based approach for the detection and repair of fugitive emissions, prohibit all venting with specific exceptions and offer an alternative performance-based approach using continuous monitoring. TC Energy has identified several areas for improvement and clarification. We participated in the 2024 public consultation process and provided recommendations, in collaboration with industry associations. The updated regulations are expected to come into force January 1, 2027, with phased requirements through 2030. We will continue to refine our internal emissions management strategies and update our compliance plans to align with the anticipated regulatory changes
•Federal: On November 9, 2024, ECCC published draft Oil and Gas Sector Greenhouse Gas Emissions Cap Regulations. The draft regulations introduce a cap-and-trade system to reduce GHG emissions from the oil and gas sector, covering upstream activities and LNG production. The initial 2030-2032 compliance period will limit emissions to 27 per cent below 2026 emissions levels with some limited compliance flexibilities. Canada would be the first major oil and gas producing country to impose such limits. Although transmission pipelines are excluded from the draft regulations, there is a possibility of cascading effects and unintended consequences to our business. The draft regulations are set to be finalized in 2025 and phased-in between 2026-2029. We continue to monitor, assess and provide feedback to ECCC, as appropriate
•British Columbia: The BC Energy Regulator is implementing amended regulations effective January 1, 2025 to further reduce methane emissions from the province's upstream oil and gas sector, in support of the CleanBC Roadmap to 2030 target of a 75 per cent reduction. The amendments update the Drilling and Production Regulation, Oil and Gas Processing Facility Regulation and Pipeline Regulation under the Energy Resource Activities Act. These amendments will be applicable to Coastal GasLink operations.
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U.S. jurisdictions
•Federal: The U.S. Senate passed the PHMSA reauthorization bill, the PIPES Act of 2020, which required PHMSA to promulgate gas pipeline leak detection and repair regulations. On May 4, 2023, PHMSA released a Notice of Proposed Rulemaking (NPRM) to regulate methane emissions from new and existing gas transmission, distribution and gas gathering pipelines and underground storage and LNG facilities. PHMSA’s NPRM provides limited exemption for compressor stations recognizing USEPA’s Methane Rule requirements. The cost of compliance due to the proposed PHMSA regulations is subject to issuance of a final rule, which remains pending, but is expected to increase significantly due to new monitoring and repair requirements applicable to the entire natural gas transmission system. On January 17, 2025, PHMSA transmitted the final rule to the Federal Register; however, it was not published prior to the inauguration of the incoming administration. On January 20, 2025, an Executive Order was issued placing a freeze on all pending regulations not published to the Federal Register for review. At this time, the final release date of the Leak Detection and Repair Rule is uncertain. TC Energy will continue to monitor the potential outcome of the regulations following federal direction and additional industry level discussions
•Federal: On November 22, 2024, the USEPA proposed amendments to the Standards of Performance for new, modified, and reconstructed stationary gas turbines (under 40 CFR Part 60, Subpart KKKKa). These amendments aim to limit emissions of criteria air pollutants, particularly nitrogen oxide (NOx), by establishing size-based subcategories and recognizing distinctions between turbines operating at varying loads or capacity factors. The USEPA also proposes that the best system of emission reduction for NOX emissions includes combustion controls with post-combustion selective catalytic reduction (“SCR”). Potential impacts to TC Energy could include additional costs for installation of SCR and other ancillary costs for operational maintenance for new gas turbines that operate at low temperatures and high utilization. However, the proposed rule is still being assessed, and there is currently no effective date for the proposed rule
•Michigan: The Michigan Department of Environment, Great Lakes and Energy (EGLE) is currently evaluating RACT requirements and emission limitations for major stationary sources of NOx in specific counties of the state (2015 ozone non-attainment area). This will lead to the development of laws and regulations that affect TC Energy through impacted ANR and Great Lakes facilities in the state
•New York: The New York State Department of Environmental Conservation (DEC) and New York State Energy Research and Development Authority (NYSERDA) are developing New York’s Cap-and-Invest Program (NYCI), proposed in 2023, to meet the Climate Act’s GHG reduction and equity requirements. The NYCI is anticipated to set an annual cap on the amount of GHG emissions that are permitted to be emitted in the state. Publication of a draft rule was expected in early 2025, but on January 15, 2025, New York Governor Hochul announced a pause to allow for additional information gathering and enhanced engagement, such that a compliance commencement date is indeterminate at this time. NYCI will potentially impact TC Energy owned/operated assets in New York, but impacts will be further evaluated once a draft rule is published
•Oregon: The state has reintroduced rules for its Climate Protection Plan. The previous version was struck down by a state court on technical grounds. Like the previous rule, the draft language appears to exclude TC Energy emissions in the state, as it would exempt "Emissions from an air contamination source that is owned or operated by an interstate natural gas pipeline and that is operating under authority of a certificate of public convenience and necessity issued by the Federal Energy Regulatory Commission".
Changes to environmental remediation regulations – U.S. Jurisdictions
•Federal: The USEPA proposed a rule entitled, Alternate Polychlorinated Biphenyl (PCB) Extraction Methods and Amendments to PCB Cleanup and Disposal Regulations in 2021. The rule addresses a myriad of issues related to laboratory methodologies, performance-based disposal options for PCB remediation waste and emergency situations, among other proposed changes. USEPA finalized the rule in August 2023 and the rule became effective February 26, 2024. We will continue to assess the impact of the rule on future projects on a case-by-case basis, which will depend on the site- and project-specific considerations and remediation efforts on each project.
In addition to the policies above, there are new mandatory climate-related disclosure requirements being issued in jurisdictions in which we operate. These disclosure requirements may impact how we report our climate-related risks and opportunities, strategy, risk management and GHG emission metrics and targets. We continue to monitor these developments and progress activities in anticipation of these new requirements.
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Other sustainability related regulations
•In 2024, the Government of Canada passed Bill C-59 including a provision to amend the Competition Act targeting unsubstantiated claims about the environmental benefits of products or business activities, commonly known as “greenwashing.” The Bill C-59 greenwashing provision affects a wide range of industries and companies, including TC Energy. Following the passage of Bill C-59, the Competition Bureau of Canada conducted a public consultation on implementation guidance and enforcement of the greenwashing provision. TC Energy participated in the public consultation process and will continue to seek clarity on how the new legislation will be interpreted and applied.
There are other sustainability-related disclosure requirements being issued in jurisdictions in which we operate. While these disclosure requirements do not necessarily apply to us, they may impact how we report on non-climate related sustainability risks, opportunities, strategies, governance and incidents. We continue to monitor these developments and progress activities related to these new and anticipated requirements.
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Financial risks
We are exposed to various financial risks and have strategies, policies and limits in place to manage the impact of these risks on our earnings, cash flows and, ultimately, shareholder value.
Risk management strategies, policies and limits are designed to ensure our risks and related exposures are in line with our business objectives and risk tolerance. Our risks are managed within limits that are established by our Board of Directors, implemented by senior management and monitored by our risk management, internal audit and business segment groups. Our Board of Directors' Audit Committee oversees how management monitors compliance with risk management policies and procedures and oversees management's review of the adequacy of the risk management framework.
Market risk
We construct and invest in energy infrastructure projects, purchase and sell commodities, issue short- and long-term debt, including amounts in foreign currencies and invest in foreign operations. Certain of these activities expose us to market risk from changes in commodity prices, foreign exchange rates and interest rates, which may affect our earnings, cash flows and the value of our financial assets and liabilities. We assess contracts used to manage market risk to determine whether all, or a portion, meet the definition of a derivative.
Derivative contracts used to assist in managing exposure to market risk may include the following:
•forwards and futures contracts – agreements to purchase or sell a specific financial instrument or commodity at a specified price and date in the future
•swaps – agreements between two parties to exchange streams of payments over time according to specified terms
•options – agreements that convey the right, but not the obligation of the purchaser, to buy or sell a specific amount of a financial instrument or commodity at a fixed price, either at a fixed date or at any time within a specified period.
Commodity price risk
The following strategies may be used to manage our exposure to market risk resulting from commodity price risk management activities in our non-regulated businesses:
•in our natural gas marketing business, we enter into natural gas transportation and storage contracts, as well as natural gas purchase and sale agreements. We manage our exposure on these contracts using financial instruments and hedging activities to offset market price volatility
•in our power business, we manage the exposure to fluctuating commodity prices through long-term contracts and hedging activities including selling and purchasing electricity and natural gas in forward markets
•in our non-regulated natural gas storage business, our exposure to seasonal natural gas price spreads is managed with a portfolio of third-party storage capacity contracts and through offsetting purchases and sales of natural gas in forward markets to lock in future positive margins.
Lower natural gas or electricity prices could lead to reduced investment in the development, expansion and production of these commodities. A reduction in the demand for these commodities could negatively impact opportunities to expand our asset base and/or re-contract with our shippers and customers as contractual agreements expire.
Interest rate risk
We utilize both short- and long-term debt to finance our operations which exposes us to interest rate risk. We typically pay fixed rates of interest on our long-term debt and floating rates on short-term debt including our commercial paper programs and amounts drawn on our credit facilities. A small portion of our long-term debt bears interest at floating rates. In addition, we are exposed to interest rate risk on financial instruments and contractual obligations containing variable interest rate components. We actively manage our interest rate risk using interest rate derivatives.
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Foreign exchange risk
Certain of our businesses generate all or most of their earnings in U.S. dollars and, since we report our financial results in Canadian dollars, changes in the value of the U.S. dollar against the Canadian dollar directly affect our comparable EBITDA and may also impact comparable earnings.
A portion of our Mexico Natural Gas Pipelines monetary assets and liabilities are peso-denominated, while our Mexico operations' financial results are denominated in U.S. dollars. Therefore, changes in the value of the Mexican peso against the U.S. dollar can affect our comparable earnings. In addition, foreign exchange gains or losses calculated for Mexico income tax purposes on the revaluation of U.S. dollar-denominated monetary assets and liabilities result in a peso-denominated income tax exposure for these entities, leading to fluctuations in Income (loss) from equity investments and Income tax expense (recovery) in the Consolidated statement of income.
We actively manage a portion of our foreign exchange risk using foreign exchange derivatives. Refer to the Foreign exchange section for additional information.
We hedge a portion of our net investment in foreign operations (on an after-tax basis) with U.S. dollar-denominated debt, cross-currency interest rate swaps and foreign exchange options, as appropriate.
Counterparty credit risk
We have exposure to counterparty credit risk in a number of areas including:
•cash and cash equivalents
•accounts receivable
•available-for-sale assets
•fair value of derivative assets
•net investment in leases and certain contract assets in Mexico.
At times, our counterparties may endure financial challenges resulting from commodity price and market volatility, economic instability and political or regulatory changes. In addition to actively monitoring these situations, there are a number of factors that reduce our counterparty credit risk exposure in the event of default, including:
•contractual rights and remedies together with the utilization of contractually-based financial assurances
•current regulatory frameworks governing certain of our operations
•the competitive position of our assets and the demand for our services
•potential recovery of unpaid amounts through bankruptcy and similar proceedings.
We review financial assets carried at amortized cost for impairment using the lifetime expected loss of the financial asset at initial recognition and throughout the life of the financial asset. We use historical credit loss and recovery data, adjusted for our judgment regarding current economic and credit conditions, along with reasonable and supportable forecasts to determine any impairment, which is recognized in Plant operating costs and other. At December 31, 2024 and 2023, we had no significant credit risk concentrations, with the exception of the CFE, which represents approximately 33 per cent of the gross exposure. Gross exposure is measured as the unmitigated full-term contract revenue exposure discounted in accordance with each contract’s discount rate, as applicable. At this time, there were no significant amounts past due or impaired. We recorded a pre-tax recovery of $22 million for the year ended December 31, 2024 on the expected credit loss provision before tax recognized on TGNH net investment in leases and certain contract assets in Mexico (2023 – $80 million recovery). Other than the expected credit loss provision noted above, we had no significant credit losses at December 31, 2024 and 2023. Refer to Note 28, Risk management and financial instruments, of our 2024 Consolidated financial statements for additional information.
We have significant credit and performance exposure to financial institutions that hold cash deposits and provide committed credit lines and letters of credit that help manage our exposure to counterparties and provide liquidity in commodity, foreign exchange and interest rate derivative markets. Our portfolio of financial sector exposure consists primarily of highly-rated investment grade, systemically important financial institutions.
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Liquidity risk
Liquidity risk is the risk that we will not be able to meet our financial obligations as they come due. We manage our liquidity risk by continuously forecasting our cash flows and ensuring we have adequate cash balances, cash flows from operations, committed and demand credit facilities and access to capital markets to meet our operating, financing and capital expenditure obligations under both normal and stressed economic conditions. Refer to the Financial Condition section for additional information.
Legal proceedings
TC Energy and its subsidiaries are subject to various legal proceedings, arbitrations and actions arising in the normal course of business. We assess all legal matters on an ongoing basis, including those of our equity investments to determine if they meet the requirements for disclosure or accrual of a contingent loss. With the potential exception of the matters discussed in Note 31, Commitments, contingencies and guarantees, of our 2024 Consolidated financial statements, it is the opinion of management that the ultimate resolution of such proceedings and actions will not have a material impact on our consolidated financial position or results of operations. The claims discussed in Note 31, Commitments, contingencies and guarantees, are material and there is a reasonable possibility of loss; however, they have not been assessed as probable and a reasonable estimate of loss cannot be made.
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CONTROLS AND PROCEDURES
We meet Canadian and U.S. regulatory requirements for disclosure controls and procedures, internal control over financial reporting and related CEO and CFO certifications.
Disclosure controls and procedures
Under the supervision and with the participation of management, including our President and CEO and our CFO, we carried out quarterly evaluations of the effectiveness of our disclosure controls and procedures, including for the year ended December 31, 2024, as required by the Canadian securities regulatory authorities and by the SEC. Based on this evaluation, our President and CEO and our CFO have concluded that the disclosure controls and procedures are effective in that they are designed to ensure that the information we are required to disclose in reports we file with or send to securities regulatory authorities is recorded, processed, summarized and reported accurately within the time periods specified under Canadian and U.S. securities laws.
Management’s annual report on internal control over financial reporting
We are responsible for establishing and maintaining adequate internal control over financial reporting, which is a process designed by, or under the supervision of, our President and CEO and our CFO and effected by our Board of Directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP.
Under the supervision and with the participation of management, including our President and CEO and our CFO, an evaluation of the effectiveness of the internal control over financial reporting was conducted as of December 31, 2024, based on the criteria described in “Internal Control – Integrated Framework” issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment, management determined that, as of December 31, 2024, the internal control over financial reporting was effective.
Our internal control over financial reporting as of December 31, 2024 has been audited by KPMG LLP, an independent registered public accounting firm, as stated in their attestation report which is included in our 2024 Consolidated financial statements.
CEO and CFO certifications
Our President and CEO and our CFO have attested to the quality of the public disclosure in our fiscal 2024 reports filed with Canadian securities regulators and the SEC and have filed certifications with them.
Changes in internal control over financial reporting
There were no changes during the year covered by this annual report that had or are reasonably likely to have a material impact on our internal control over financial reporting.
On October 1, 2024, we completed the Spinoff Transaction. In connection with the Spinoff Transaction, the internal controls associated with the Liquids Pipelines business were transferred to South Bow. We are contractually obligated to maintain adequate controls post-spinoff for the provision of services under the Transition Services Agreement.
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CRITICAL ACCOUNTING ESTIMATES
In preparing our Consolidated financial statements, we are required to make estimates and assumptions that affect both the amount and timing of recording assets, liabilities, revenues and expenses since the determination of these items may be dependent on future events. We use the most current information available and exercise careful judgment in making these estimates and assumptions.
Certain estimates and judgments have a material impact where the assumptions underlying these accounting estimates relate to matters that are highly uncertain at the time the estimate or judgment is made or are subjective. Refer to Note 2, Accounting policies, of our 2024 Consolidated financial statements for additional information.
Impairment of goodwill
We test goodwill for impairment annually or more frequently if events or changes in circumstances lead us to believe it might be impaired. We can initially assess qualitative factors which include, but are not limited to, macroeconomic conditions, industry and market considerations, current valuation multiples and discount rates, cost factors, historical and forecasted financial results, or events specific to that reporting unit. If we conclude that it is not more likely than not that the fair value of the reporting unit is greater than its carrying value, we will then perform a quantitative goodwill impairment test. We can elect to proceed directly to the quantitative goodwill impairment test for any reporting unit. If the quantitative goodwill impairment test is performed, we compare the fair value of the reporting unit to its carrying value, including its goodwill. If the carrying value of a reporting unit exceeds its fair value, goodwill impairment is measured at the amount by which the reporting unit’s carrying value exceeds its fair value.
When a portion of a reporting unit that constitutes a business is disposed, goodwill associated with that business is included in the carrying amount of the business in determining the gain or loss on disposal. The amount of goodwill disposed is determined based on the relative fair values of the business to be disposed and the portion of the reporting unit that will be retained.
We determine the fair value of a reporting unit based on our projections of future cash flows, which involves making estimates and assumptions about transportation rates, market supply and demand, growth opportunities, output levels, competition from other companies, operating costs, regulatory changes, discount rates and earnings and other multiples.
In the determination of the fair value utilized in the quantitative goodwill impairment test performed in 2023 for the Columbia reporting unit, we performed a discounted cash flow analysis using projections of future cash flows and applied a risk-adjusted discount rate and terminal value multiple which involved significant estimates and judgments. It was determined that the fair value of the Columbia reporting unit exceeded its carrying value, including goodwill. Although goodwill was not impaired, the estimated fair value in excess of the carrying value was less than 10 per cent. There is a risk that reductions in future cash flow forecasts and adverse changes in other key assumptions could result in a future impairment of a portion of the goodwill balance relating to Columbia.
In March 2022, an impairment loss was recognized for the excess carrying value over the estimated fair value of our Great Lakes reporting unit. There is a risk that reductions in future cash flow forecasts and adverse changes in other key assumptions could result in future impairment of the remaining goodwill balance.
Qualitative goodwill impairment indicators
As part of the annual goodwill impairment assessment at December 31, 2024, we evaluated qualitative factors impacting the fair value of the underlying reporting units. It was determined that it was more likely than not that the fair value of these reporting units exceeded their carrying amounts, including goodwill.

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FINANCIAL INSTRUMENTS
With the exception of Long-term debt and Junior subordinated notes, our derivative and non-derivative financial instruments are recorded on the balance sheet at fair value unless they were entered into and continue to be held for the purpose of receipt or delivery in accordance with our normal purchase and sales exemptions and are documented as such. In addition, fair value accounting is not required for other financial instruments that qualify for certain accounting exemptions.
Derivative instruments
We use derivative instruments to reduce volatility associated with fluctuations in commodity prices, interest rates and foreign exchange rates. Derivative instruments, including those that qualify and are designated for hedge accounting treatment, are recorded at fair value. 
The majority of derivative instruments that are not designated or do not qualify for hedge accounting treatment have been entered into as economic hedges to manage our exposure to market risk and are classified as held-for-trading. Changes in the fair value of held-for-trading derivative instruments are recorded in net income in the period of change. This may expose us to increased variability in reported operating results since the fair value of the held-for-trading derivative instruments can fluctuate significantly from period to period.
The recognition of gains and losses on derivatives for Canadian natural gas regulated pipeline exposures is determined through the regulatory process. Gains and losses arising from changes in the fair value of derivatives accounted for as part of RRA, including those that qualify for hedge accounting treatment, are expected to be refunded or recovered through the tolls charged by us. As a result, these gains and losses are deferred as regulatory liabilities or regulatory assets and are refunded to or collected from the ratepayers in subsequent years when the derivative settles.
Balance sheet presentation of derivative instruments
The balance sheet presentation of the fair value of derivative instruments is as follows:
at December 31
(millions of $) 2024 2023
Other current assets 347  589 
Other long-term assets 122  155 
Accounts payable and other (507) (415)
Other long-term liabilities (209) (106)
(247) 223 
Anticipated timing of settlement of derivative instruments
The anticipated timing of settlement of derivative instruments assumes constant commodity prices, interest rates and foreign exchange rates. Settlements will vary based on the actual value of these factors at the date of settlement.
at December 31, 2024 Total fair value < 1 year 1 - 3 years 4 - 5 years > 5 years
(millions of $)
Derivative instruments held for trading
 (122) (147) 3  25  (3)
Derivative instruments in hedging relationships (125) (15) (35) (42) (33)
  (247) (162) (32) (17) (36)
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Unrealized and realized gains (losses) on derivative instruments
The following summary does not include hedges of our net investment in foreign operations.
year ended December 31
(millions of $) 2024 2023 2022
Derivative Instruments Held for Trading1
Unrealized gains (losses) in the year
  Commodities (71) 132  (11)
  Foreign exchange (266) 246  (149)
Interest rate
 (71) —  — 
Realized gains (losses) in the year
  Commodities 199  192  46 
  Foreign exchange (152) 155  (2)
Interest rate
 29  —  — 
Derivative Instruments in Hedging Relationships2
Realized gains (losses) in the year
  Commodities 33  (2) (73)
  Interest rate (52) (43) (3)
1Realized and unrealized gains (losses) on held-for-trading derivative instruments used to purchase and sell commodities are included on a net basis in Revenues. Realized and unrealized gains (losses) on foreign exchange held-for-trading derivative instruments are included on a net basis in Foreign exchange (gains) losses, net in the Consolidated statement of income. Realized and unrealized gains (losses) on interest rate derivatives are included on a net basis in Interest expense in the Consolidated statement of income.
2In 2024, unrealized gains of $6 million were reclassified to Net Income (loss) from AOCI related to discontinued cash flow hedges (2023 and 2022 – nil).
For further details on our non-derivative and derivative financial instruments, including classification assumptions made in the calculation of fair value and additional discussion of exposure to risks and mitigation activities, refer to Note 28, Risk management and financial instruments, of our 2024 Consolidated financial statements.
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RELATED PARTY TRANSACTIONS
Related party transactions are conducted in the normal course of business and are measured at the exchange amount, which is
the amount of consideration established and agreed to by the related parties.
Coastal GasLink LP
We hold a 35 per cent equity interest in Coastal GasLink LP, and have been contracted to develop, construct and operate the Coastal GasLink pipeline.
We have a subordinated loan agreement with Coastal GasLink LP under which we advance non-revolving interest-bearing loans subject to floating market-based rates. In December 2024, following the commercial in-service of the pipeline, Coastal GasLink LP repaid the $3,147 million balance outstanding to TC Energy under the subordinated loan agreement. This repayment reduced our funding commitment under the subordinated loan agreement to $228 million at December 31, 2024.
We also have a subordinated demand revolving credit facility agreement with Coastal GasLink LP to provide additional short-term liquidity and funding flexibility to projects under construction.
Refer to Note 7, Coastal GasLink, of our 2024 Consolidated financial statements for additional information about Coastal GasLink LP related party transactions.
Sur de Texas
We hold a 60 per cent equity interest in a joint venture with IEnova to own the Sur de Texas pipeline, for which we are the operator. In 2017, we entered into a MXN$21.3 billion unsecured revolving credit facility with the joint venture, which bore interest at a floating rate and was fully repaid upon maturity on March 15, 2022 in the amount of $1.2 billion.
Our Consolidated statement of income reflects the related interest income and foreign exchange impact on this loan receivable until its repayment on March 15, 2022, which were fully offset upon consolidation with corresponding amounts included in our proportionate share of Sur de Texas equity earnings as follows:
year ended December 31 Affected line item in the Consolidated statement of income
(millions of $) 2024 2023 2022
Interest income1
 —  —  19  Interest income and other
Interest expense2
 —  —  (19)
Income (loss) from equity investments
Foreign exchange losses1
 —  —  (28)
Foreign exchange (gains) losses, net
Foreign exchange gains1
 —  —  28 
Income (loss) from equity investments
1Included in our Corporate segment.
2Included in our Mexico Natural Gas Pipelines segment.
On March 15, 2022, as part of refinancing activities with the Sur de Texas joint venture, the peso-denominated inter-affiliate loan discussed above was replaced with a new U.S. dollar-denominated inter-affiliate loan from us of an equivalent $1.2 billion (US$938 million) with a floating interest rate. On July 29, 2022, the Sur de Texas joint venture entered into an unsecured term loan agreement with third parties, the proceeds of which were used to fully repay the U.S. dollar-denominated inter-affiliate loan with TC Energy.
ACCOUNTING CHANGES
For a description of our significant accounting policies and a summary of changes in accounting policies and standards impacting our business, refer to Note 2, Accounting policies, and Note 3, Accounting changes, of our 2024 Consolidated financial statements.
TC Energy Management's discussion and analysis 2024 | 123

QUARTERLY RESULTS
Selected quarterly consolidated financial data
2024
(millions of $, except per share amounts) Fourth
Third1
Second1
First1
Revenues from continuing operations 3,577  3,358  3,327  3,509 
Net income (loss) attributable to common shares 971  1,457  963  1,203 
from continuing operations
 1,069  1,349  793  988 
from discontinued operations2
 (98) 108  170  215 
Comparable earnings3
 1,094  1,074  978  1,284 
from continuing operations
 1,094  905  811  1,055 
from discontinued operations2
 —  169  167  229 
Share statistics:        
Net income (loss) per common share – basic $0.94  $1.40  $0.93  $1.16 
 from continuing operations
 $1.03  $1.30  $0.77  $0.95 
 from discontinued operations2
 ($0.09) $0.10  $0.16  $0.21 
Comparable earnings per common share3
 $1.05  $1.03  $0.94  $1.24 
from continuing operations $1.05  $0.87  $0.78  $1.02 
from discontinued operations2
 —  $0.16  $0.16  $0.22 
Dividends declared per common share4
 $0.8225  $0.96  $0.96  $0.96 
1Prior quarter results have been recast to reflect the split between continuing and discontinued operations.
2Represents nine months of Liquids Pipelines earnings in 2024.
3Additional information on the most directly comparable GAAP measure can be found on page 24.
4Dividends declared in fourth quarter 2024 reflect TC Energy’s proportionate allocation following the Spinoff Transaction. Refer to the Discontinued operations section for additional information.
20231
(millions of $, except per share amounts) Fourth Third Second First
Revenues from continuing operations 3,504  3,225  3,148  3,390 
Net income (loss) attributable to common shares 1,463  (197) 250  1,313 
  from continuing operations
 1,249  (325) 76  1,217 
  from discontinued operations2
 214  128  174  96 
Comparable earnings3
 1,403  1,035  981  1,233 
  from continuing operations
 1,192  848  767  1,089 
  from discontinued operations2
 211  187  214  144 
Share statistics:
Net income (loss) per common share – basic $1.41  ($0.19) $0.24  $1.29 
from continuing operations
 $1.20  ($0.31) $0.07  $1.19 
from discontinued operations2
 $0.21  $0.12  $0.17  $0.10 
Comparable earnings per common share3
 $1.35  $1.00  $0.96  $1.21 
  from continuing operations $1.15  $0.82  $0.75  $1.07 
  from discontinued operations2
 $0.20  $0.18  $0.21  $0.14 
Dividends declared per common share $0.93  $0.93  $0.93  $0.93 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2Represents a full year of Liquids Pipelines earnings in 2023.
3Additional information on the most directly comparable GAAP measure can be found on page 24.
124 | TC Energy Management's discussion and analysis 2024

Factors affecting quarterly financial information by business segment
Quarter-over-quarter revenues and net income fluctuate for reasons that vary across our business segments. In addition to the factors below, our revenues and segmented earnings (losses) are impacted by fluctuations in foreign exchange rates, mainly related to our U.S. dollar-denominated operations and our peso-denominated exposure.
As discussed on page 10 of the About this document section, results of the Liquids Pipelines business were accounted for as a discontinued operation starting October 1, 2024. To allow for a meaningful comparison, discussions throughout the Quarterly results section are based on continuing operations unless otherwise noted. Prior year results have been recast to reflect the split between continuing and discontinued operations. Discontinued operations reflect nine months of Liquids Pipelines earnings for the year ended December 31, 2024 compared to a full year of Liquids earnings in 2023. Refer to the Discontinued operations section for additional information.
In our Natural Gas Pipelines business, except for seasonal fluctuations in short-term throughput volumes on U.S. pipelines, quarter-over-quarter revenues and segmented earnings (losses) generally remain relatively stable during any fiscal year. Over the long term, however, they fluctuate because of:
•regulatory decisions
•negotiated settlements with customers
•newly constructed assets being placed in service
•acquisitions and divestitures
•natural gas marketing activities and commodity prices
•developments outside of the normal course of operations
•certain fair value adjustments
•provisions for expected credit losses on net investment in leases and certain contract assets in Mexico.
In Power and Energy Solutions, quarter-over-quarter revenues and segmented earnings are affected by:
•weather
•customer demand
•newly constructed assets being placed in service
•acquisitions and divestitures
•market prices for natural gas and power
•capacity prices and payments
•power marketing and trading activities
•planned and unplanned plant outages
•developments outside of the normal course of operations
•certain fair value adjustments.
Factors affecting financial information by quarter
We calculate comparable measures by adjusting certain GAAP measures for specific items we believe are significant but not reflective of our underlying operations in the period. Except as otherwise described herein, these comparable measures are calculated on a consistent basis from period to period and are adjusted for specific items in each period, as applicable. Refer to page 24 for more information on non-GAAP measures we use.
In fourth quarter 2024, comparable earnings from continuing operations also excluded:
•a pre-tax net gain on debt extinguishment of $228 million (after-tax $178 million) related to the purchase and cancellation of certain senior unsecured notes and medium term notes and the retirement of outstanding callable notes in October 2024
•pre-tax unrealized foreign exchange gains, net of $143 million (after-tax $153 million) on the peso-denominated intercompany loan between TCPL and TGNH, net of non-controlling interest
•a pre-tax recovery of $3 million (after-tax $2 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico, net of non-controlling interest
•a deferred income tax expense of $96 million resulting from the revaluation of remaining deferred tax balances following the Spinoff Transaction
•a pre-tax impairment charge of $36 million (after-tax $27 million) related to development costs incurred on Project Tundra, a next-generation technology carbon capture and storage project, following our decision to end our collaboration on the project
•a pre-tax expense of $9 million (after-tax $7 million) related to Focus Project costs.
TC Energy Management's discussion and analysis 2024 | 125

In third quarter 2024, comparable earnings from continuing operations also excluded:
•a pre-tax gain of $572 million (after-tax $456 million) related to the sale of PNGTS which was completed on August 15, 2024
•pre-tax unrealized foreign exchange losses, net, of $52 million (after-tax $52 million) on the peso-denominated intercompany loan between TCPL and TGNH, net of non-controlling interest
•a pre-tax expense of $5 million (after-tax $4 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico, net of non-controlling interest
•a pre-tax expense of $5 million (after-tax $3 million) related to Focus Project costs.
In second quarter 2024, comparable earnings from continuing operations also excluded:
•a pre-tax gain of $48 million (after-tax $63 million) related to the sale of non-core assets in U.S. Natural Gas Pipelines and Canadian Natural Gas Pipelines
•pre-tax unrealized foreign exchange losses, net of $3 million (after-tax $3 million) on the peso-denominated intercompany loan between TCPL and TGNH, net of non-controlling interest
•a pre-tax recovery of $3 million (after-tax $2 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico, net of non-controlling interest
•pre-tax costs of $10 million (after-tax $42 million) related to the NGTL System Ownership Transfer.
In first quarter 2024, comparable earnings from continuing operations also excluded:
•pre-tax unrealized foreign exchange gains, net of $55 million (after-tax $55 million) on the peso-denominated intercompany loan between TCPL and TGNH
•a pre-tax recovery of $21 million (after-tax $15 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico
•a pre-tax expense of $34 million (after-tax $26 million) related to a non-recurring third-party settlement
•a pre-tax expense of $10 million (after-tax $8 million) related to Focus Project costs.
In fourth quarter 2023, comparable earnings from continuing operations also excluded:
•a $74 million income tax recovery related to a revised assessment of the valuation allowance and non-taxable capital losses on our equity investment in Coastal GasLink LP
•pre-tax unrealized foreign exchange losses, net of $55 million (after-tax $55 million) on the peso-denominated intercompany loan between TCPL and TGNH
•a pre-tax expense of $36 million (after-tax $25 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico
•a pre-tax expense of $15 million (after-tax $9 million) related to Focus Project costs.
In third quarter 2023, comparable earnings from continuing operations also excluded:
•a pre-tax impairment charge of $1,244 million (after-tax $1,179 million) related to our equity investment in Coastal GasLink LP
•a pre-tax expense of $18 million (after-tax $14 million) related to Focus Project costs
•pre-tax net unrealized foreign exchange gains, net of $20 million (after-tax $20 million) on the peso-denominated intercompany loan between TCPL and TGNH
•a pre-tax recovery of $1 million (nil after tax) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico.
In second quarter 2023, comparable earnings from continuing operations also excluded:
•a pre-tax impairment charge of $843 million (after-tax $809 million) related to our equity investment in Coastal GasLink LP
•a pre-tax expense of $32 million (after-tax $25 million) related to Focus Project costs
•pre-tax unrealized foreign exchange losses, net of $9 million (after-tax $9 million) on the peso-denominated intercompany loan between TCPL and TGNH
•a pre-tax recovery of $11 million (after-tax $8 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico.
In first quarter 2023, comparable earnings from continuing operations also excluded:
•a pre-tax recovery of $104 million (after-tax $72 million) on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico
•a pre-tax impairment charge of $13 million (after-tax $29 million) related to our equity investment in Coastal GasLink LP.
126 | TC Energy Management's discussion and analysis 2024

FOURTH QUARTER 2024 HIGHLIGHTS
Consolidated results
three months ended December 31 2024
20231
(millions of $, except per share amounts)
Canadian Natural Gas Pipelines 506  692 
U.S. Natural Gas Pipelines 918  955 
Mexico Natural Gas Pipelines 214  150 
Power and Energy Solutions 276  263 
Corporate (16) (34)
Total segmented earnings (losses) 1,898  2,026 
Interest expense (679) (777)
Allowance for funds used during construction 233  132 
Foreign exchange gains (losses), net
 (69) 89 
Interest income and other 120  119 
Income (loss) from continuing operations before income taxes
 1,503  1,589 
Income tax (expense) recovery from continuing operations
 (223) (188)
Net income (loss) from continuing operations
 1,280  1,401 
Net income (loss) from discontinued operations, net of tax2
 (98) 214 
Net income (loss)
 1,182  1,615 
Net (income) loss attributable to non-controlling interests
 (183) (128)
Net income (loss) attributable to controlling interests
 999  1,487 
Preferred share dividends (28) (24)
Net income (loss) attributable to common shares
 971  1,463 
Net income (loss) per common share – basic
 0.94 1.41
from continuing operations
 $1.03  $1.20 
from discontinued operations2
 ($0.09) $0.21 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2The Liquids Pipelines business was accounted for as a discontinued operation starting October 1, 2024. Refer to the Discontinued operations section for additional information.
three months ended December 31 2024
20231
(millions of $)
Amounts attributable to common shares
Net income (loss) from continuing operations
 1,280  1,401 
Net income (loss) attributable to non-controlling interest
 (183) (128)
Net income (loss) attributable to controlling interests from continuing operations
 1,097  1,273 
Preferred share dividends (28) (24)
Net income (loss) attributable to common shares from continuing operations
 1,069  1,249 
Net income (loss) from discontinued operations, net of tax2
 (98) 214 
Net income (loss) attributable to common shares
 971  1,463 
1Prior year results have been recast to reflect the split between continuing and discontinued operations.
2The Liquids Pipelines business was accounted for as a discontinued operation starting October 1, 2024. Refer to the Discontinued operations section for additional information.
Net income (loss) attributable to common shares from continuing operations decreased by $180 million or $0.17 per common share for the three months ended December 31, 2024 compared to the same period in 2023. The decrease is primarily due to the net effect of the specific items mentioned above.

TC Energy Management's discussion and analysis 2024 | 127

Reconciliation of net income (loss) attributable to common shares to comparable earnings - from continuing operations
three months ended December 31 2024
20231
(millions of $, except per share amounts)
Net income (loss) attributable to common shares from continuing operations
 1,069  1,249 
Specific items (pre tax):
Net gain on debt extinguishment2
 (228) — 
Foreign exchange (gains) losses, net – intercompany loan3
 (143) 55 
Expected credit loss provision on net investment in leases
  and certain contract assets in Mexico4
 (3) 36 
Project Tundra impairment charge
 36  — 
Focus Project costs5
 9  15 
Bruce Power unrealized fair value adjustments (2) (7)
Risk management activities6
 301  (91)
Taxes on specific items7
 55  (65)
Comparable earnings from continuing operations
 1,094  1,192 
Net income (loss) per common share from continuing operations
 $1.03  $1.20 
Specific items (net of tax)
 0.02  (0.05)
Comparable earnings per common share from continuing operations
 $1.05  $1.15 
1Prior year results have been recast to reflect continuing operations only.
2In October 2024, TCPL commenced and completed our cash tender offers to purchase and cancel certain senior unsecured notes and medium term notes at a 7.73 per cent weighted average discount. In addition, we retired outstanding callable notes at par. These extinguishments of debt resulted in a pre-tax net gain of $228 million, primarily due to fair value discounts and unamortized debt issue costs. The net gain on debt extinguishment was recorded in Interest expense in the Consolidated statement of income. Refer to the Financial condition section for additional information.
3In 2023, TCPL and TGNH became party to an unsecured revolving credit facility. The loan receivable and loan payable are eliminated upon consolidation; however, due to differences in the currency that each entity reports its financial results, there is an impact to net income reflecting the revaluation and translation of the loan receivable and loan payable to TC Energy's reporting currency. As the amounts do not accurately reflect what will be realized at settlement, we exclude from comparable measures the unrealized foreign exchange gains and losses on the loan receivable, as well as the corresponding unrealized foreign exchange gains and losses on the loan payable, net of non-controlling interest.
4In 2022, TGNH and the CFE executed agreements which consolidate several natural gas pipelines under one TSA. As this TSA contains a lease, we have recognized amounts in net investment in leases on our Consolidated balance sheet. As required by U.S. GAAP, we have recognized an expected credit loss provision related to net investment in leases and certain contract assets in Mexico, which will fluctuate from period to period based on changing economic assumptions and forward-looking information. This provision is an estimate of losses that may occur over the duration of the TSA through 2055. This provision does not reflect losses or cash outflows that were incurred under this lease arrangement in the current period or from our underlying operations, and therefore, we have excluded any unrealized changes, net of non-controlling interest, from comparable measures. Refer to Note 28, Risk management and financial instruments, for additional information.
5    In 2022, we launched the Focus Project with benefits in the form of enhanced safety, productivity and cost-effectiveness expected to be realized in the future. Beginning in 2023, we recognized expenses in Plant operating costs and other, for external consulting and severance, some of which are not recoverable through regulatory and commercial tolling structures. Refer to the Corporate – Significant events section for additional information.
128 | TC Energy Management's discussion and analysis 2024

6
 three months ended December 31 2024 2023
(millions of $)
U.S. Natural Gas Pipelines (37) (29)
  Canadian Power 17  (6)
U.S. Power (2) 4 
  Natural Gas Storage (20) 18 
Interest rate
 (71) — 
  Foreign exchange (188) 104 
(301) 91 
  Income tax attributable to risk management activities 72  (24)
 
Total unrealized gains (losses) from risk management activities
 (229) 67 
7
 Refer to the Corporate - Financial results section for additional information.
Comparable EBITDA to comparable earnings - from continuing operations
Comparable EBITDA from continuing operations represents segmented earnings (losses) adjusted for the specific items described above and excludes charges for depreciation and amortization.
three months ended December 31
(millions of $, except per share amounts) 2024
20231
Comparable EBITDA from continuing operations
Canadian Natural Gas Pipelines 851  1,034 
U.S. Natural Gas Pipelines 1,200  1,225 
Mexico Natural Gas Pipelines 234  208 
Power and Energy Solutions 341  266 
Corporate (7) (18)
Comparable EBITDA from continuing operations
 2,619  2,715 
Depreciation and amortization (639) (632)
Interest expense included in comparable earnings (836) (777)
Allowance for funds used during construction 233  132 
Foreign exchange gains (losses), net included in comparable earnings (44) 40 
Interest income and other
 120  119 
Income tax (expense) recovery included in comparable earnings (168) (253)
Net (income) loss attributable to non-controlling interests included in comparable earnings
 (163) (128)
Preferred share dividends (28) (24)
Comparable earnings from continuing operations
 1,094  1,192 
Comparable earnings per common share from continuing operations
 $1.05  $1.15 
1Prior year results have been recast to reflect continuing operations only.

TC Energy Management's discussion and analysis 2024 | 129

Comparable EBITDA from continuing operations
Fourth quarter 2024 versus fourth quarter 2023
Comparable EBITDA from continuing operations decreased by $96 million for the three months ended December 31, 2024 compared to the same period in 2023 primarily due to the net effect of the following:
•decreased EBITDA in Canadian Natural Gas Pipelines mainly due to lower earnings from Coastal GasLink related to the recognition of a $200 million incentive payment in 2023, partially offset by higher flow-through costs on the NGTL System
•decreased U.S. dollar-denominated EBITDA from U.S. Natural Gas Pipelines mainly as a result of the sale of PNGTS, which was completed on August 15, 2024, lower realized earnings related to our U.S. natural gas marketing business primarily due to lower margins and lower equity earnings from Iroquois, partially offset by incremental earnings from growth projects placed in service and additional contract sales
•increased Power and Energy Solutions EBITDA primarily attributable to higher contributions from Bruce Power due to higher generation, a higher contract price and lower outage costs, partially offset by decreased Canadian Power earnings primarily due to lower realized power prices, net of lower natural gas fuel costs
•increased U.S. dollar-denominated EBITDA from Mexico Natural Gas Pipelines primarily due to higher equity earnings from Sur de Texas as a result of the impact of peso-denominated financial exposure and lower income tax expense, partially offset by lower earnings in TGNH primarily related to higher operating costs
•the positive foreign exchange impact of a stronger U.S. dollar on the Canadian dollar equivalent comparable EBITDA in our U.S. dollar-denominated operations. U.S. dollar-denominated comparable EBITDA decreased by US$27 million compared to 2023 and was translated at a rate of 1.40 in 2024 versus 1.36 in 2023. Refer to the Foreign exchange section for additional information.
Due to the flow-through treatment of certain costs including income taxes, financial charges and depreciation in our Canadian rate-regulated pipelines, changes in these costs impact our comparable EBITDA despite having no significant effect on net income.
Comparable earnings from continuing operations
Fourth quarter 2024 versus fourth quarter 2023
Comparable earnings from continuing operations decreased by $98 million or $0.10 per common share for the three months ended December 31, 2024 compared to the same period in 2023 and was primarily the net effect of:
•changes in comparable EBITDA described above
•higher interest expense primarily due to lower capitalized interest, interest expense allocated to discontinued operations in 2023 and lower interest rates on increased levels of short-term borrowing, partially offset by long-term debt repayments, net of issuances and realized gains from risk management activities used to manage our interest rate risk
•higher AFUDC primarily due to spending on the Southeast Gateway pipeline project, partially offset by projects placed in service
•risk management activities used to manage our foreign exchange exposure to net liabilities in Mexico and to U.S. dollar‑denominated income and the revaluation of our peso-denominated net monetary liabilities to U.S. dollars
•lower income tax expense due to lower earnings subject to income tax and Mexico foreign exchange exposure, partially offset by lower foreign income tax rate differentials and higher flow-through income taxes
•higher net income attributable to non-controlling interests primarily due to the sale of a 13.01 per cent non-controlling equity interest in TGNH to the CFE completed in second quarter 2024, lower taxable earnings from the Texas Wind Farms and a stronger U.S. dollar on translation of U.S. dollar-denominated net income attributable to non-controlling interests.




130 | TC Energy Management's discussion and analysis 2024

Foreign exchange
Certain of our businesses generate all or most of their earnings in U.S. dollars and, since we report our financial results in Canadian dollars, changes in the value of the U.S. dollar against the Canadian dollar directly affect our comparable EBITDA and may also impact comparable earnings. As our U.S. dollar-denominated operations continue to grow, this exposure increases. A portion of the U.S. dollar-denominated comparable EBITDA exposure is naturally offset by U.S. dollar-denominated amounts below comparable EBITDA within Depreciation and amortization, Interest expense and other income statement line items. A portion of the remaining exposure is actively managed on a rolling forward basis up to three years using foreign exchange derivatives; however, the natural exposure beyond that period remains. The net impact of the U.S. dollar movements on comparable earnings during the three months ended December 31, 2024 after considering natural offsets and economic hedges was not significant.
The components of our financial results denominated in U.S. dollars are set out in the table below, including our U.S. Natural Gas Pipelines and Mexico Natural Gas Pipelines operations. Comparable EBITDA is a non-GAAP measure.
Pre-tax U.S. dollar-denominated income and expense items - from continuing operations
three months ended December 31
(millions of US$) 2024
20231
Comparable EBITDA
U.S. Natural Gas Pipelines 859  900 
Mexico Natural Gas Pipelines
 167  153 
1,026  1,053 
Depreciation and amortization (191) (192)
Interest expense on long-term debt and junior subordinated notes
 (440) (473)
Interest expense allocated to discontinued operations
 —  47 
Allowance for funds used during construction 159  81 
Net (income) loss attributable to non-controlling interests included in comparable earnings and other
 (125) (92)
  429  424 
Average exchange rate - U.S. to Canadian dollars 1.40  1.36 
1    Prior year results have been recast to reflect continuing operations only.
Foreign exchange related to Mexico Natural Gas Pipelines
Changes in the value of the Mexican peso against the U.S. dollar can affect our comparable earnings as a portion of our Mexico Natural Gas Pipelines monetary assets and liabilities are peso-denominated, while our financial results are denominated in U.S. dollars for our Mexico operations. These peso-denominated balances are revalued to U.S. dollars, creating foreign exchange gains and losses that are included in Income (loss) from equity investments, Foreign exchange (gains) losses, net and Net income (loss) attributable to non-controlling interests in the Consolidated statement of income.
In addition, foreign exchange gains or losses calculated for Mexico income tax purposes on the revaluation of U.S. dollar‑denominated monetary assets and liabilities result in a peso-denominated income tax exposure for these entities, leading to fluctuations in Income from equity investments and Income tax expense. This exposure increases as our U.S. dollar‑denominated net monetary liabilities grow.
The above exposures are managed using foreign exchange derivatives, although some unhedged exposure remains. The impacts of the foreign exchange derivatives are recorded in Foreign exchange (gains) losses, net in the Consolidated statement of income. Refer to the Financial risks and financial instruments section for additional information.





TC Energy Management's discussion and analysis 2024 | 131

The period end exchange rates for one U.S. dollar to Mexican pesos were as follows:
December 31, 2024 20.87 
December 31, 2023 16.91 
December 31, 2022 19.50 
A summary of the impacts of transactional foreign exchange gains and losses from changes in the value of the Mexican peso against the U.S. dollar and associated derivatives is set out in the table below:
three months ended December 31
(millions of $) 2024 2023
Comparable EBITDA - Mexico Natural Gas Pipelines1
 30  (16)
Foreign exchange gains (losses), net included in comparable earnings (21) 64 
Income tax (expense) recovery included in comparable earnings 27  (38)
Net (income) loss attributable to non-controlling interests included in comparable earnings2
 (3) — 
33  10 
1Includes the foreign exchange impacts from the Sur de Texas joint venture recorded in Income (loss) from equity investments in the Consolidated statement of income.
2Represents the non-controlling interest portion related to TGNH. Refer to the Corporate section for additional information.

132 | TC Energy Management's discussion and analysis 2024

Highlights by business segment
Canadian Natural Gas Pipelines
Canadian Natural Gas Pipelines segmented earnings decreased by $186 million for the three months ended December 31, 2024 compared to the same period in 2023.
Net income for the NGTL System decreased by $8 million for the three months ended December 31, 2024 compared to the same period in 2023 mainly due to incentive losses. The NGTL System was operating under the 2020-2024 Revenue Requirement Settlement which included an approved ROE of 10.1 per cent on 40 per cent deemed common equity. This settlement provided the NGTL System the opportunity to increase depreciation rates if tolls fall below specified levels and an incentive mechanism for certain operating costs where variances from projected amounts are shared with our customers.
Net income for the Canadian Mainline increased by $7 million for the three months ended December 31, 2024 compared to the same period in 2023 mainly due to higher incentive earnings. The Canadian Mainline is operating under the 2021-2026 Mainline Settlement which includes an approved ROE of 10.1 per cent on 40 per cent deemed common equity and an incentive to decrease costs and increase revenues on the pipeline under a beneficial sharing mechanism with our customers.
Comparable EBITDA for Canadian Natural Gas Pipelines decreased by $183 million for the three months ended December 31, 2024 compared to the same period in 2023 due to the net effect of:
•earnings from Coastal GasLink in 2023 related to the recognition of a $200 million incentive payment upon meeting certain milestones
•higher flow-through income taxes and depreciation on the NGTL System, partially offset by incentive losses.
Depreciation and amortization for the three months ended December 31, 2024 was largely consistent with the same period in 2023.
U.S. Natural Gas Pipelines
U.S. Natural Gas Pipelines segmented earnings decreased by $37 million for the three months ended December 31, 2024 compared to the same period in 2023 and included unrealized gains and losses from changes in the fair value of derivatives related to our U.S. natural gas marketing business, which have been excluded from our calculation of comparable EBITDA and comparable EBIT.
A stronger U.S. dollar for the three months ended December 31, 2024 had a positive impact on the Canadian dollar equivalent segmented earnings from our U.S. dollar-denominated operations. Refer to the Foreign exchange section for additional information.
Comparable EBITDA for U.S. Natural Gas Pipelines decreased by US$41 million for the three months ended December 31, 2024 compared to the same period in 2023 and was primarily due to the net effect of:
•decreased earnings as a result of the sale of our 61.7 per cent equity interest in PNGTS, which was completed on     August 15, 2024
•lower realized earnings related to our U.S. natural gas marketing business, primarily due to lower margins
•lower equity earnings from Iroquois
•decreased earnings due to higher operational costs, reflective of increased system utilization across our footprint
•incremental earnings from growth and modernization projects placed in service, as well as increased earnings from additional contract sales on ANR.
Depreciation and amortization for the three months ended December 31, 2024 was largely consistent with the same period in 2023.
TC Energy Management's discussion and analysis 2024 | 133

Mexico Natural Gas Pipelines
Mexico Natural Gas Pipelines segmented earnings increased by $64 million for the three months ended December 31, 2024 compared to the same period in 2023 and included an unrealized recovery of $3 million (2023 – unrealized loss of $36 million), on the expected credit loss provision related to TGNH net investment in leases and certain contract assets in Mexico, which has been excluded from our calculation of comparable EBITDA and comparable EBIT. Refer to Note 28, Risk management and financial instruments, of our 2024 Consolidated financial statements for additional information.
A stronger U.S. dollar for the three months ended December 31, 2024 had a positive impact on the Canadian dollar equivalent segmented earnings from our U.S. dollar-denominated operations in Mexico. Refer to the Foreign exchange section for additional information.
Comparable EBITDA for Mexico Natural Gas Pipelines increased by US$14 million for the three months ended December 31, 2024 compared to the same period in 2023 due to the net effect of:
•higher equity earnings in Sur de Texas primarily due to the foreign exchange impacts upon the revaluation of peso-denominated liabilities as a result of a weaker Mexican peso and lower income tax expense mainly due to foreign exchange impacts. We use foreign exchange derivatives to manage this exposure, the impact of which is recognized in Foreign exchange (gains) losses, net in the Consolidated statement of income. Refer to the Foreign exchange section for additional information
•lower earnings in TGNH primarily related to higher operating costs from integrity activities performed in fourth quarter 2024.
Depreciation and amortization was consistent for the three months ended December 31, 2024 compared to the same period in 2023.
Power and Energy Solutions
Power and Energy Solutions segmented earnings increased by $13 million for the three months ended December 31, 2024 compared to the same period in 2023 and included the following specific items which have been excluded from our calculation of comparable EBITDA and comparable EBIT:
•a pre-tax impairment charge of $36 million related to development costs incurred on Project Tundra, a next-generation technology carbon capture and storage project, following our decision to end our collaboration on the project
•our proportionate share of Bruce Power's unrealized gains and losses on funds invested for post-retirement benefits and risk management activities
•unrealized gains and losses from changes in the fair value of derivatives used to reduce commodity exposures.
Comparable EBITDA for Power and Energy Solutions increased by $75 million for the three months ended December 31, 2024 compared to the same period in 2023 primarily due to the net effect of:
•improved contributions from Bruce Power primarily due to increased generation, a higher contract price and lower outage costs, partially offset by increased operating and depreciation costs. Refer to the Bruce Power section for additional information
•decreased Canadian Power financial results primarily from lower realized power prices, net of lower natural gas fuel costs.
Depreciation and amortization was consistent for the three months ended December 31, 2024 compared to the same period in 2023.
Corporate
Corporate segmented losses decreased by $18 million for the three months ended December 31, 2024 compared to the same period in 2023. Corporate segmented losses included a pre-tax charge of $9 million for the three months ended December 31, 2024 (2023 – $15 million) related to Focus Project costs, which has been excluded from our calculation of comparable EBITDA and comparable EBIT.
Comparable EBITDA for Corporate was a loss of $7 million for the three months ended December 31, 2024 compared to a loss of $18 million for the same period in 2023 and includes shared costs in 2023 related to TC Energy's corporate services and governance functions that were not allocated to discontinued operations in accordance with U.S. GAAP. Refer to the Discontinued operations section for additional information.
Depreciation and amortization for the three months ended December 31, 2024 was largely consistent with the same period in 2023.
134 | TC Energy Management's discussion and analysis 2024

QUARTERLY RESULTS - FROM DISCONTINUED OPERATIONS
Factors affecting financial information by quarter
The quarterly results section references non-GAAP measures, which are described on page 24. These measures do not have any standardized meaning as prescribed by GAAP and therefore may not be comparable to similar measures presented by other entities.
In fourth quarter 2024, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $85 million (after-tax $72 million) from Liquids Pipelines business separation costs related to the Spinoff Transaction, of which $75 million was recognized in segmented earnings and $10 million in interest income
•a pre-tax expense of $37 million (after-tax $28 million) related to our current estimate of potential incremental costs resulting from the Milepost 14 incident. This amount represents our 86 per cent share pursuant to the indemnity provisions in the Separation Agreement
•a pre-tax recovery of $3 million (after-tax $2 million) as a result of the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods.
In third quarter 2024, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $67 million (after-tax $56 million) due to Liquids Pipelines business separation costs related to the Spinoff Transaction
•a pre-tax expense of $21 million (after-tax $16 million) related to Keystone XL asset disposition and termination activities
•a pre-tax charge of $15 million (after-tax $12 million) related to the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods.
In second quarter 2024, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $29 million (after-tax $26 million) due to Liquids Pipelines business separation costs related to the Spinoff Transaction.
In first quarter 2024, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $16 million (after-tax $13 million) due to Liquids Pipelines business separation costs related to the Spinoff Transaction.
In fourth quarter 2023, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $25 million (after-tax $23 million) from Liquids Pipelines business separation costs related to the Spinoff Transaction
•pre-tax preservation and other costs of $5 million (after-tax $4 million) related to the preservation and storage of the Keystone XL pipeline project assets
•pre-tax carrying charges of $5 million (after-tax $4 million) as a result of a charge related to the FERC Administrative Law Judge initial decision on Keystone issued in February 2023 in respect of a tolling-related complaint pertaining to amounts recognized in prior periods
•a pre-tax recovery of $4 million (after-tax $18 million) related to the net impact of a U.S. minimum tax recovery on the 2021 Keystone XL asset impairment charge and other and a gain on the sale of Keystone XL project assets, offset partially by adjustments to the estimate for contractual and legal obligations related to termination activities.
In third quarter 2023, comparable earnings from discontinued operations also excluded:
•a pre-tax charge of $15 million (after-tax $11 million) due to Liquids Pipelines business separation costs related to the Spinoff Transaction
•pre-tax preservation and other costs for Keystone XL pipeline project assets of $3 million (after-tax $2 million).
In second quarter 2023, comparable earnings from discontinued operations also excluded:
•a $36 million pre-tax (after-tax $36 million) accrued insurance expense related to the Milepost 14 incident
•pre-tax preservation and other costs for Keystone XL pipeline project assets of $5 million (after-tax $4 million).
TC Energy Management's discussion and analysis 2024 | 135

In first quarter 2023, comparable earnings from discontinued operations also excluded:
•a $62 million pre-tax (after-tax $48 million) charge as a result of the FERC Administrative Law Judge initial decision on Keystone issued in February 2023 in respect of a tolling-related complaint pertaining to amounts recognized from 2018 to 2022 which consists of a one-time pre-tax charge of $57 million (after-tax $44 million) and accrued pre-tax carrying charges of $5 million (after-tax $4 million)
•pre-tax preservation and other costs for Keystone XL pipeline project assets of $5 million (after-tax $4 million).
Results from discontinued operations
three months ended December 31
(millions of $, except per share amounts)
20241
20232
Segmented earnings (losses) from discontinued operations
 (109) 301 
Interest expense
 —  (68)
Interest income and other
(10) 2 
Income (loss) from discontinued operations before income taxes
 (119) 235 
Income tax (expense) recovery
 21  (21)
Net income (loss) from discontinued operations, net of tax
 (98) 214 
Net income (loss) per common share from discontinued operations - basic
 ($0.09) $0.21 
1The Liquids Pipelines business was accounted for as a discontinued operation starting October 1, 2024. Refer to the Discontinued operations section for additional information.
2Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
Net income (loss) from discontinued operations, net of tax was a net loss of $98 million or loss of $0.09 per share for the three months ended December 31, 2024 compared to net income of $214 million or $0.21 per share for the same period in 2023. The decrease reflects the completion of the Spinoff Transaction on October 1, 2024 and the net effect of the specific items mentioned above.
Reconciliation of net income (loss) from discontinued operations, net of tax to comparable earnings from discontinued operations
three months ended December 31
20241
20232
(millions of $, except per share amounts)
Net income (loss) from discontinued operations, net of tax
 (98) 214 
Specific items (pre tax):
Liquids Pipelines business separation costs 85  25 
Milepost 14 incremental costs
 37  — 
Keystone regulatory decisions (3) 5 
Keystone XL preservation and other —  5 
Keystone XL asset impairment charge and other —  (4)
Risk management activities
 —  (20)
Taxes on specific items3
 (21) (14)
Comparable earnings from discontinued operations
 —  211 
Net income (loss) per common share from discontinued operations
 ($0.09) $0.21 
Specific items (net of tax)
 0.09  (0.01)
Comparable earnings per common share from discontinued operations
 —  $0.20 
1The Liquids Pipelines business was accounted for as a discontinued operation starting October 1, 2024. Refer to the Discontinued operations section for additional information.
2Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3Refer to page 101 for additional information.
136 | TC Energy Management's discussion and analysis 2024

Comparable EBITDA to comparable earnings - from discontinued operations
Comparable EBITDA from discontinued operations represents segmented earnings (losses) from discontinued operations adjusted for the specific items described above and excludes charges for depreciation and amortization.
three months ended December 31
(millions of $, except per share amounts)
20241
20232
Comparable EBITDA from discontinued operations
 —  392 
Depreciation and amortization —  (85)
Interest expense included in comparable earnings3
 —  (63)
Interest income and other included in comparable earnings4
 —  2 
Income tax (expense) recovery included in comparable earnings5
 —  (35)
Comparable earnings from discontinued operations
 —  211 
Comparable earnings per common share from discontinued operations
 —  $0.20 
1    The Liquids Pipelines business was accounted for as a discontinued operation starting October 1, 2024. Refer to the Discontinued operations section for additional information.
2    Prior year results have been recast to reflect the Liquids Pipelines business as a discontinued operation as a result of the Spinoff Transaction.
3Excludes pre-tax carrying charges of $5 million for the three months ended December 31, 2023 as a result of a charge related to the FERC Administrative Law Judge decision on Keystone in respect of a tolling-related complaint pertaining to amounts recognized in prior periods.
4Excludes pre-tax Liquids Pipelines business separation costs of $10 million related to insurance provisions for the three months ended December 31, 2024.
5Excludes the impact of income taxes related to the specific items mentioned above as well as a $14 million U.S. minimum tax recovery in fourth quarter 2023 on the Keystone XL asset impairment charge and other related to the termination of the Keystone XL pipeline project.
Comparable EBITDA and comparable earnings from discontinued operations
Comparable EBITDA and comparable earnings from discontinued operations were nil for three months ended December 31, 2024 compared to comparable EBITDA of $392 million and comparable earnings of $211 million or $0.20 per common share for the same period in 2023. The decrease reflects the completion of the Spinoff Transaction on October 1, 2024.
TC Energy Management's discussion and analysis 2024 | 137

Glossary
Units of measure
Bcf Billion cubic feet
Bcf/d Billion cubic feet per day
GWh Gigawatt hours
km Kilometres
MMcf/d Million cubic feet per day
MW Megawatt(s)
MWh Megawatt hours
TJ/d Terajoule per day
General terms and terms related to our operations
CEO Chief Executive Officer
CFO Chief Financial Officer
cogeneration facilities Facilities that produce both electricity and useful heat at the same time
DRP Dividend Reinvestment and Share Purchase Plan
Empress A major delivery/receipt point for natural gas near the Alberta/Saskatchewan border
ESG
Environmental, social and governance
FID Final investment decision
force majeure Unforeseeable circumstances that prevent a party to a contract from fulfilling it
GHG Greenhouse gas
HCAs High-consequence areas
HSSE Health, safety, sustainability and environment
investment base
Includes rate base, as well as assets under construction
LDC Local distribution company
LNG Liquefied natural gas
OM&A Operating, maintenance and administration
PPA Power purchase arrangement
rate base Average assets in service, working capital and deferred amounts used in setting of regulated rates
RNG Renewable natural gas
TSA Transportation Service Agreement
TOMS TC Energy's Operational Management System
WCSB Western Canadian Sedimentary basin

Accounting terms
AFUDC Allowance for funds used during construction
U.S.GAAP / GAAP U.S. generally accepted accounting principles
RRA
Rate-regulated accounting
ROE Return on common equity
Government and regulatory bodies terms
AER
Alberta Energy Regulator
CER Canada Energy Regulator
CFE Comisión Federal de Electricidad (Mexico)
CRE
Comisión Reguladora de Energía, or Energy Regulatory Commission (Mexico)
ECCC Environment and Climate Change Canada
FERC Federal Energy Regulatory Commission (U.S.)
IESO
Independent Electricity System Operator (Ontario)
IFRS S2
International Financial Reporting Standards S2 Climate-related Disclosures
NYSE New York Stock Exchange
OBPS Output Based Pricing System
OPG Ontario Power Generation
PHMSA Pipeline and Hazardous Materials Safety Administration
SEC U.S. Securities and Exchange Commission
SENER
Secretaría de Energía or Mexican Ministry of Energy
TCFD Task Force on Climate-Related Financial Disclosures
TNFD
Task Force on Nature-related Financial Disclosures
TSX Toronto Stock Exchange
138 | TC Energy Management's discussion and analysis 2024
EXHIBIT 13.3
Management's Report on Internal Control over Financial Reporting
The consolidated financial statements and Management's Discussion and Analysis (MD&A) included in this Annual Report are the responsibility of the management of TC Energy Corporation (TC Energy or the Company) and have been approved by the Board of Directors of the Company. The consolidated financial statements have been prepared by management in accordance with United States generally accepted accounting principles (GAAP) and include amounts that are based on estimates and judgments. The MD&A is based on the Company's financial results. It compares the Company's financial and operating performance in 2024 to that in 2023, and highlights significant changes between 2023 and 2022. The MD&A should be read in conjunction with the consolidated financial statements and accompanying notes. Financial information contained elsewhere in this Annual Report is consistent with the consolidated financial statements.
Management is responsible for establishing and maintaining adequate internal control over financial reporting for the Company. Management has designed and maintains a system of internal control over financial reporting, including a program of internal audits to carry out its responsibility. Management believes these controls provide reasonable assurance that financial records are reliable and form a proper basis for the preparation of financial statements. The internal control over financial reporting includes management's communication to employees of policies that govern ethical business conduct.
Under the supervision and with the participation of the President and Chief Executive Officer and the Chief Financial Officer, management conducted an evaluation of the effectiveness of its internal control over financial reporting based on the framework in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Management concluded, based on its evaluation, that internal control over financial reporting was effective as of December 31, 2024, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external reporting purposes.
The Board of Directors is responsible for reviewing and approving the consolidated financial statements and MD&A and ensuring that management fulfills its responsibilities for financial reporting and internal control. The Board of Directors carries out these responsibilities primarily through the Audit Committee, which consists of independent, non-management directors. The Audit Committee meets with management at least four times a year and meets independently with internal and external auditors and as a group to review any significant accounting, internal control and auditing matters in accordance with the terms of the Charter of the Audit Committee, which is set out in the Annual Information Form. The Audit Committee's responsibilities include overseeing management's performance in carrying out its financial reporting responsibilities and reviewing the Annual Report, including the consolidated financial statements and MD&A, before these documents are submitted to the Board of Directors for approval. The internal and independent external auditors have access to the Audit Committee without the requirement to obtain prior management approval.
The Audit Committee approves the terms of engagement of the independent external auditors and reviews the annual audit plan, the Auditors' Report and the results of the audit. It also recommends to the Board of Directors the firm of external auditors to be appointed by the shareholders.
The shareholders have appointed KPMG LLP as independent external auditors to express an opinion as to whether the consolidated financial statements present fairly, in all material respects, the Company's consolidated financial position, results of operations and cash flows in accordance with GAAP. The reports of KPMG LLP outline the scope of its examinations and its opinions on the consolidated financial statements and the effectiveness of the Company's internal control over financial reporting.
Francois.jpg
Sean-ODonnell-blue.jpg
François L. Poirier
President and
Chief Executive Officer
  
Sean O'Donnell
Executive Vice-President and
Chief Financial Officer
February 13, 2025    
TC Energy Consolidated Financial Statements 2024 | 139

Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors
TC Energy Corporation:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheets of TC Energy Corporation (the Company) as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, cash flows, and equity for each of the years in the three-year period ended December 31, 2024, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the years in the three‑year period ended December 31, 2024, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 13, 2025 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the Audit Committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements; and (2) involved our especially challenging, subjective or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Qualitative goodwill impairment assessment for the Columbia and ANR reporting units
As discussed in Notes 2 and 14 to the consolidated financial statements, the goodwill balance as of December 31, 2024 for the Columbia Pipeline Group, Inc. (Columbia) and the American Natural Resources (ANR) reporting units was $10,588 million and $2,803 million, respectively. The Company assesses goodwill for impairment testing annually or more frequently if events or changes in circumstances indicate that the carrying value of a reporting unit, including goodwill, might be impaired. The Company performed qualitative assessments to determine whether events or changes in circumstances indicate that the Columbia and ANR reporting units’ goodwill might be impaired. These qualitative assessments were performed as of December 31, 2024.
140 | TC Energy Consolidated Financial Statements 2024

We identified the evaluation of qualitative goodwill impairment indicators, or qualitative factors, for the Columbia and ANR reporting units as a critical audit matter. The assessment of the potential impact that these qualitative factors have on a reporting unit’s fair value required the application of subjective auditor judgment. Qualitative factors include macroeconomic conditions, industry and market considerations, valuation multiples and discount rates, cost factors, historical and forecasted financial results and events specific to the reporting units, which required a higher degree of auditor judgment to evaluate. These qualitative factors could have had a significant effect on the Company’s qualitative assessment and the potential for the need to perform a quantitative goodwill impairment test. In addition, the audit effort associated with this evaluation required specialized skills and knowledge.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls related to the Company’s goodwill impairment assessment process, including controls related to the assessment of potential qualitative factors. We evaluated the Company’s assessment of identified event-specific changes against our knowledge of event-specific changes obtained through other audit procedures. We evaluated information from analyst reports in the energy and utility industries, including global energy consumption forecasts and natural gas production forecasts, which were compared to geopolitical and market considerations used by the Company. We compared the current valuation multiples and discount rates, cost factors, historical and forecasted financial results of the reporting units, including the impact of newly approved growth projects, to assumptions used in the quantitative goodwill impairment tests performed in a previous period. In addition, we involved a valuation professional with specialized skills and knowledge, who assisted in:
•evaluating the Company’s determination of the valuation multiples by comparing them to independently observed, recent market transactions of comparable assets and using publicly available market data for comparable entities
•evaluating the discount rates used by management in the assessment, by comparing them against a discount rate range that was independently developed using publicly available market data for comparable entities.

/s/ KPMG LLP

Chartered Professional Accountants
We have served as the Company's auditor since 1956.
Calgary, Canada
February 13, 2025
TC Energy Consolidated Financial Statements 2024 | 141

Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors
TC Energy Corporation:
Opinion on Internal Control Over Financial Reporting
We have audited TC Energy Corporation’s (the Company) internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, cash flows, and equity for each of the years in the three-year period ended December 31, 2024, and the related notes (collectively, the consolidated financial statements), and our report dated February 13, 2025 expressed an unqualified opinion on those consolidated financial statements.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Annual Report on Internal Control over Financial Reporting included in the Company's Management’s Discussion and Analysis. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control Over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ KPMG LLP
Chartered Professional Accountants
Calgary, Canada
February 13, 2025
142 | TC Energy Consolidated Financial Statements 2024

Consolidated statement of income
year ended December 31 2024 2023 2022
(millions of Canadian $, except per share amounts)
Revenues (Note 6)
Canadian Natural Gas Pipelines 5,600  5,173  4,764 
U.S. Natural Gas Pipelines 6,339  6,229  5,933 
Mexico Natural Gas Pipelines 870  846  688 
Power and Energy Solutions 954  1,019  924 
Corporate
 8  —  — 
13,771  13,267  12,309 
Income (Loss) from Equity Investments (Note 11)
 1,558  1,310  999 
Impairment of Equity Investment (Note 7)
 —  (2,100) (3,048)
Operating and Other Expenses
Plant operating costs and other 4,413  4,073  4,228 
Commodity purchases resold 217  80  22 
Property taxes 820  781  727 
Depreciation and amortization 2,535  2,446  2,262 
Goodwill impairment charge (Note 14)
 —  —  571 
7,985  7,380  7,810 
Net Gain (Loss) on Sale of Assets (Note 30)
 620  —  — 
Financial Charges
Interest expense (Note 20)
 3,019  2,966  2,300 
Allowance for funds used during construction (784) (575) (369)
Foreign exchange (gains) losses, net (Note 22)
 147  (320) 185 
Interest income and other (324) (272) (140)
2,058  1,799  1,976 
Income (Loss) from Continuing Operations before Income Taxes
 5,906  3,298  474 
Income Tax Expense (Recovery) from Continuing Operations (Note 19)
Current 495  864  363 
Deferred 427  (22) (41)
922  842  322 
Net Income (Loss) from Continuing Operations
 4,984  2,456  152 
Net Income (Loss) from Discontinued Operations, Net of Tax (Note 4)
 395  612  633 
Net Income (Loss)
5,379  3,068  785 
Net income (loss) attributable to non-controlling interests (Note 23)
 681  146  37 
Net Income (Loss) Attributable to Controlling Interests
 4,698  2,922  748 
Preferred share dividends
 104  93  107 
Net Income (Loss) Attributable to Common Shares
 4,594  2,829  641 
Amounts Attributable to Common Shares
Net income (loss) from continuing operations
4,984  2,456  152 
Net income (loss) attributable to non-controlling interests (Note 23)
 681  146  37 
Net income (loss) attributable to controlling interests from continuing operations
 4,303  2,310  115 
Preferred share dividends 104  93  107 
Net income (loss) attributable to common shares from continuing operations
 4,199  2,217  8 
Net income (loss) from discontinued operations, net of tax
 395  612  633 
Net Income (Loss) Attributable to Common Shares
4,594  2,829  641 
Net Income (Loss) per Common Share - Basic and Diluted (Note 24)
Continuing operations
 $4.05  $2.15  $0.01 
Discontinued operations
 $0.38  $0.60  $0.63 
$4.43  $2.75  $0.64 
Dividends Declared per Common Share $3.7025  $3.72  $3.60 
Weighted Average Number of Common Shares (millions) (Note 24)
Basic 1,038  1,030  995 
Diluted 1,038  1,030  996 
The accompanying Notes to the consolidated financial statements are an integral part of these statements.
TC Energy Consolidated Financial Statements 2024 | 143

Consolidated statement of comprehensive income
year ended December 31 2024 2023 2022
(millions of Canadian $)
Net Income (Loss)
 5,379  3,068  785 
Other Comprehensive Income (Loss), Net of Income Taxes
Foreign currency translation gains and losses on net investment in foreign operations
 1,602  (1,141) 1,494 
Reclassification of foreign currency translation (gains) on net investment on disposal of foreign operations
 (25) —  — 
Change in fair value of net investment hedges (18) 17  (36)
Change in fair value of cash flow hedges 35  —  (39)
Reclassification to net income of (gains) losses on cash flow hedges
 (16) 74  42 
Unrealized actuarial gains (losses) on pension and other post-retirement benefit plans
 83  (11) 63 
Reclassification to net income of actuarial (gains) losses on pension and other post-retirement benefit plans
 (6) —  6 
Other comprehensive income (loss) on equity investments
 173  (211) 867 
Other comprehensive income (loss) (Note 26)
 1,828  (1,272) 2,397 
Comprehensive Income (Loss)
 7,207  1,796  3,182 
Comprehensive income (loss) attributable to non-controlling interests
 1,584  (220) 45 
Comprehensive Income (Loss) Attributable to Controlling Interests
 5,623  2,016  3,137 
Preferred share dividends 104  93  107 
Comprehensive Income (Loss) Attributable to Common Shares
 5,519  1,923  3,030 
The accompanying Notes to the consolidated financial statements are an integral part of these statements.
144 | TC Energy Consolidated Financial Statements 2024

Consolidated statement of cash flows
year ended December 31 2024 2023 2022
(millions of Canadian $)
Cash Generated from Operations
Net income (loss)
 5,379  3,068  785 
Depreciation and amortization 2,788  2,778  2,584 
Goodwill and asset impairment charges and other (Notes 4 and 14)
21  (4) 453 
Deferred income taxes (Note 19)
 493  11  174 
(Income) loss from equity investments (Note 11)
 (1,608) (1,377) (1,054)
Impairment of equity investment (Note 7)
 —  2,100  3,048 
Distributions received from operating activities of equity investments (Note 11)
 1,675  1,254  1,025 
Employee post-retirement benefits funding, net of expense (Note 27)
 11  (17) (29)
Net (gain) loss on sale of assets (Note 30)
 (620) —  — 
Equity allowance for funds used during construction (512) (367) (248)
Unrealized (gains) losses on financial instruments (Note 28)
 340  (342) 135 
Expected credit loss provision (Note 28)
 (22) (83) 163 
Foreign exchange (gains) losses on loans receivable
 (216) 44  28 
Other (232) (4) (50)
(Increase) decrease in operating working capital (Note 29)
 199  207  (639)
Net cash provided by operations 7,696  7,268  6,375 
Investing Activities
Capital expenditures (Note 5)
 (6,308) (8,007) (6,678)
Capital projects in development (Note 5)
 (50) (142) (49)
Contributions to equity investments (Notes 5, 7 and 11)
 (4,683) (4,149) (3,433)
Acquisitions, net of cash acquired (Note 30)
 —  (307) — 
Loans to affiliate (issued) repaid, net (Notes 7 and 12)
 —  250  (11)
Keystone XL contractual recoveries
7  10  571 
Proceeds from sales of assets, net of transaction costs (Note 30)
 791  33  — 
Other distributions from equity investments (Note 11)
 3,686  23  2,632 
Deferred amounts and other (352) 2  (41)
Net cash (used in) provided by investing activities
 (6,909) (12,287) (7,009)
Financing Activities
Notes payable issued (repaid), net 341  (6,299) 766 
Long-term debt issued, net of issue costs 8,089  15,884  2,508 
Long-term debt repaid (9,273) (3,772) (1,338)
Disposition of equity interest, net of transaction costs (Note 30)
 419  5,328  — 
Junior subordinated notes issued, net of issue costs 1,465  —  1,008 
Cash transferred to South Bow, net of debt settlements
 (244) —  — 
Dividends on common shares (3,953) (2,787) (3,192)
Dividends on preferred shares (99) (92) (106)
Contributions from non-controlling interests 21  —  — 
Distributions to non-controlling interests and other
 (755) (173) (87)
Common shares issued, net of issue costs 88  4  1,905 
Preferred shares redeemed (Note 25)
 —  —  (1,000)
Gains (losses) on settlement of financial instruments 27  —  23 
Net cash (used in) provided by financing activities (3,874) 8,093  487 
Effect of Foreign Exchange Rate Changes on Cash and Cash Equivalents 210  (16) 94 
Increase (Decrease) in Cash and Cash Equivalents
 (2,877) 3,058  (53)
Cash and Cash Equivalents
Beginning of year 3,678  620  673 
Cash and Cash Equivalents
End of year 801  3,678  620 
Includes continuing and discontinued operations. Refer to Note 4, Discontinued operations, for additional information related to cash flows from discontinued operations.
The accompanying Notes to the consolidated financial statements are an integral part of these statements.
TC Energy Consolidated Financial Statements 2024 | 145

Consolidated balance sheet
at December 31 2024 2023
(millions of Canadian $)
ASSETS
Current Assets
Cash and cash equivalents 801  3,678 
Accounts receivable 2,611  2,427 
Inventories 747  771 
Other current assets (Note 8)
1,339  1,419 
Current assets of discontinued operations (Note 4)
 235  3,077 
5,733  11,372 
Plant, Property and Equipment (Note 9)
 77,501  69,451 
Net Investment in Leases (Note 10)
 2,477  2,263 
Equity Investments (Note 11)
 10,636  9,240 
Restricted Investments 2,998  2,532 
Regulatory Assets (Note 13)
 2,682  2,330 
Goodwill (Note 14)
 13,670  12,532 
Other Long-Term Assets (Note 15)
 2,410  2,881 
Long-Term Assets of Discontinued Operations (Note 4)
 136  12,433 
118,243  125,034 
LIABILITIES
Current Liabilities
Notes payable (Note 16)
 387  — 
Accounts payable and other (Note 17)
 5,297  4,305 
Dividends payable 874  979 
Accrued interest 828  913 
Current portion of long-term debt (Note 20)
 2,955  2,938 
Current liabilities of discontinued operations (Note 4)
 170  2,682 
10,511  11,817 
Regulatory Liabilities (Note 13)
 5,303  4,703 
Other Long-Term Liabilities (Note 18)
1,051  991 
Deferred Income Tax Liabilities (Note 19)
 6,884  6,972 
Long-Term Debt (Note 20)
 44,976  49,976 
Junior Subordinated Notes (Note 21)
 11,048  10,287 
Long-Term Liabilities of Discontinued Operations (Note 4)
 110  1,280 
79,883  86,026 
EQUITY
Common shares, no par value (Note 24)
 30,101  30,002 
Issued and outstanding:
December 31, 2024 – 1,039 million shares
December 31, 2023 – 1,037 million shares
Preferred shares (Note 25)
 2,499  2,499 
Retained earnings (Accumulated deficit)
 (5,241) (2,997)
Accumulated other comprehensive income (loss) (Note 26)
 233  49 
Controlling Interests 27,592  29,553 
Non-Controlling Interests (Note 23)
 10,768  9,455 
38,360  39,008 
118,243  125,034 
Commitments, Contingencies and Guarantees (Note 31)
Variable Interest Entities (Note 32)
The accompanying Notes to the consolidated financial statements are an integral part of these statements.

On behalf of the Board:
Francois.jpg
Una Power.jpg
François L. Poirier, Director
Una M. Power, Director
146 | TC Energy Consolidated Financial Statements 2024

Consolidated statement of equity
year ended December 31 2024 2023 2022
(millions of Canadian $)
Common Shares (Note 24)
Balance at beginning of year 30,002  28,995  26,716 
Shares issued:
Exercise of stock options 99  4  183 
Dividend reinvestment and share purchase plan —  1,003  342 
Under public offering, net of issue costs —  —  1,754 
Balance at end of year 30,101  30,002  28,995 
Preferred Shares (Note 25)
Balance at beginning of year 2,499  2,499  3,487 
Redemption of shares —  —  (988)
Balance at end of year 2,499  2,499  2,499 
Additional Paid-In Capital
Balance at beginning of year —  722  729 
Issuance of stock options, net of exercises (5) 9  (7)
Disposition of equity interest, net of transaction costs (Note 30)
 (41) (3,537) — 
Reclassification of additional paid-in capital deficit to accumulated deficit
 46  2,806  — 
Balance at end of year —  —  722 
Retained Earnings (Accumulated Deficit)
Balance at beginning of year (2,997) 819  3,773 
Net income (loss) attributable to controlling interests 4,698  2,922  748 
Common share dividends (3,842) (3,839) (3,595)
Preferred share dividends (104) (93) (95)
Spinoff of Liquids Pipelines business (Note 4)
 (2,950) —  — 
Reclassification of additional paid-in capital deficit to accumulated deficit (46) (2,806) — 
Redemption of preferred shares —  —  (12)
Balance at end of year (5,241) (2,997) 819 
Accumulated Other Comprehensive Income (Loss) (Note 26)
Balance at beginning of year 49  955  (1,434)
Other comprehensive income (loss) attributable to controlling interests 946  (379) 2,389 
Impact of non-controlling interest (Note 30)
 (21) (527) — 
Spinoff of Liquids Pipelines business (Note 4)
 (741) —  — 
Balance at end of year 233  49  955 
Equity Attributable to Controlling Interests 27,592  29,553  33,990 
Equity Attributable to Non-Controlling Interests
Balance at beginning of year 9,455  126  125 
Disposition of equity and non-controlling interests (Note 30)
 461  9,451  — 
Non-controlling interests on acquisition of Texas Wind Farms (Note 30)
 —  222  — 
Net income (loss) attributable to non-controlling interests (Note 23)
 681  146  37 
Other comprehensive income (loss) attributable to non-controlling interests 903  (366) 8 
Contributions from non-controlling interests
 21  —  — 
Distributions declared to non-controlling interests (753) (124) (44)
Balance at end of year 10,768  9,455  126 
Total Equity 38,360  39,008  34,116 
The accompanying Notes to the consolidated financial statements are an integral part of these statements.
TC Energy Consolidated Financial Statements 2024 | 147

Notes to consolidated financial statements
1. DESCRIPTION OF TC ENERGY'S BUSINESS
TC Energy Corporation (TC Energy or the Company) is a leading North American energy infrastructure company which operates in four business segments: Canadian Natural Gas Pipelines, U.S. Natural Gas Pipelines, Mexico Natural Gas Pipelines and Power and Energy Solutions. These segments offer different products and services, including certain natural gas and electricity marketing and storage services. The Company also has a Corporate segment, consisting of corporate and administrative functions that provide governance, financing and other support to the Company's business segments.
Canadian Natural Gas Pipelines
The Canadian Natural Gas Pipelines segment primarily consists of the Company's investments in 41,121 km (25,552 miles) of regulated natural gas pipelines currently in operation.
U.S. Natural Gas Pipelines
The U.S. Natural Gas Pipelines segment primarily consists of the Company's investments in 49,681 km (30,870 miles) of regulated natural gas pipelines, 532 Bcf of regulated natural gas storage facilities and other assets currently in operation.
Mexico Natural Gas Pipelines
The Mexico Natural Gas Pipelines segment primarily consists of the Company's investments in 2,885 km (1,791 miles) of regulated natural gas pipelines currently in operation.
Power and Energy Solutions
The Power and Energy Solutions segment primarily consists of the Company's investments in approximately 4,650 MW of power generation facilities and 118 Bcf of non-regulated natural gas storage facilities. These assets are located in Alberta, Ontario, Québec, New Brunswick and Texas. In addition, TC Energy has physical and virtual power purchase agreements (PPAs) in Canada and the U.S. to buy and/or sell power from wind and solar facilities. These PPAs have the potential to be leases, derivatives or revenue arrangements depending on the contractual terms of the agreement.
Spinoff of Liquids Pipelines Business
On July 27, 2023, TC Energy announced plans to separate into two independent, investment-grade, publicly listed companies through the spinoff of its Liquids Pipelines business. TC Energy shareholders voted to approve the plan in June 2024 and, on October 1, 2024, TC Energy completed the spinoff of its Liquids Pipelines business into the new public company, South Bow Corporation (South Bow) (the Spinoff Transaction). TC Energy shareholders as of September 25, 2024 received one new TC Energy common share and 0.2 of a South Bow common share in exchange for each TC Energy common share held. TC Energy common shares resumed regular way trading on the TSX and NYSE on October 2, 2024. South Bow's common shares commenced regular way trading on the TSX on October 2, 2024 and on the NYSE on October 8, 2024, under the ticker symbol SOBO. Refer to Note 4, Discontinued operations, for additional information.
148 | TC Energy Consolidated Financial Statements 2024

2. ACCOUNTING POLICIES
The Company's consolidated financial statements have been prepared by management in accordance with U.S. generally accepted accounting principles. Amounts are stated in Canadian dollars unless otherwise indicated.
Basis of Presentation
These consolidated financial statements include the accounts of TC Energy and its subsidiaries. The Company consolidates variable interest entities (VIEs) for which it is considered to be the primary beneficiary as well as voting interest entities in which it has a controlling financial interest. To the extent there are interests owned by other parties, these interests are included in non-controlling interests. TC Energy uses the equity method of accounting for joint ventures in which the Company is able to exercise joint control and for investments in which the Company is able to exercise significant influence.
The Spinoff Transaction represented a strategic shift that had a major effect on the Company's operations and consolidated financial results. Accordingly, the historical results of the Liquids Pipelines business are presented as discontinued operations and have been excluded from continuing operations and segment disclosures for all periods presented. The Notes to the consolidated financial statements reflect continuing operations only, unless otherwise indicated. Prior to the spinoff, the operations of the Liquids Pipelines business were materially reported as the Company's Liquids Pipelines segment. Refer to Note 4, Discontinued operations, and Note 5, Segmented information, for additional information.
Certain prior year amounts have been reclassified to conform to current year presentation.
Use of Estimates and Judgments
In preparing these consolidated financial statements, TC Energy is required to make estimates and assumptions that affect both the amount and timing of recording assets, liabilities, revenues and expenses since the determination of these items may be dependent on future events. The Company uses the most current information available and exercises careful judgment in making these estimates and assumptions.
Certain estimates and judgments have a material impact where the assumptions underlying these accounting estimates relate to matters that are highly uncertain at the time they are made or are subjective. These estimates and judgments include, but are not limited to, the assessment of goodwill impairment indicators and fair value of reporting units that contain goodwill (Note 14).
Some of the estimates and judgments the Company has to make have a material impact on the consolidated financial statements, but do not involve significant subjectivity or uncertainty. These estimates and judgments include, but are not limited to:
•provisions for indemnities related to the South Bow Separation Agreement (Note 4)
•recoverability and depreciation rates of plant, property and equipment (Note 9)
•allocation of consideration to lease and non-lease components in a contract that contains a lease (Note 10)
•assumptions used to measure the carrying amount of and expected credit losses on net investment in leases and certain contract assets (Notes 10 and 28)
•fair value of equity investments (Note 11)
•carrying value of regulatory assets and liabilities (Note 13)
•recognition of asset retirement obligations (Note 18)
•provisions for income taxes, including valuation allowances and releases as well as tax positions that may be reviewed as part of an audit by tax authorities (Note 19)
•assumptions used to measure retirement and other post-retirement benefit obligations (Note 27)
•fair value of financial instruments (Note 28)
•fair value of Fluvanna Wind Farm and Blue Cloud Wind Farm (Texas Wind Farms) assets (Note 30)
•commitments and provisions for contingencies and guarantees (Note 31).
TC Energy continues to assess climate-related impacts on the consolidated financial statements. There are ongoing developments in the ESG frameworks and regulatory initiatives that could further impact accounting estimates and judgments including, but not limited to, assessment of asset useful lives, goodwill valuation, impairment of plant, property and equipment, accrued environmental costs and asset retirement obligations. The impact of these changes is continuously assessed to ensure any changes in assumptions that would impact estimates listed above are adjusted on a timely basis.
Actual results could differ from these estimates.
TC Energy Consolidated Financial Statements 2024 | 149

Regulation
Certain Canadian, U.S. and Mexico natural gas pipeline and storage assets are regulated with respect to construction, operations and the determination of tolls. In Canada, regulated natural gas pipelines are subject to the authority of the Canada Energy Regulator (CER), the Alberta Energy Regulator or the B.C. Oil and Gas Commission. In the U.S., regulated interstate natural gas pipelines and regulated natural gas storage assets are subject to the authority of the Federal Energy Regulatory Commission (FERC). In Mexico, regulated natural gas pipelines are subject to the authority of the Energy Regulatory Commission (CRE). Rate-regulated accounting (RRA) standards may impact the timing of the recognition of certain revenues and expenses in TC Energy's rate-regulated businesses which may differ from that otherwise recognized in non-rate-regulated businesses to reflect the economic impact of the regulators' decisions regarding revenues and tolls. Regulatory assets represent costs that are expected to be recovered in customer rates in future periods and regulatory liabilities represent amounts that are expected to be returned to customers through future rate-setting processes. An operation qualifies for the use of RRA when it meets three criteria:
•a regulator must establish or approve the rates for the regulated services or activities
•the regulated rates must be designed to recover the cost of providing the services or products
•it is reasonable to assume that rates set at levels to recover the cost can be charged to and collected from customers because of the demand for services or products and the level of direct or indirect competition.
TC Energy's businesses that apply RRA currently include natural gas pipelines in Canada, U.S. and Mexico and regulated U.S. natural gas storage.
Revenue Recognition
The total consideration for services and products to which the Company expects to be entitled can include fixed and variable amounts. The Company has variable revenue that is subject to factors outside the Company's influence, such as market prices, actions of third parties and weather conditions. The Company considers this variable revenue to be "constrained" as it cannot be reliably estimated and, therefore, recognizes variable revenue when the service is provided.
Revenues from contracts with customers are recognized net of any commodity taxes collected from customers which are subsequently remitted to governmental authorities. The Company's contracts with customers include natural gas pipelines capacity arrangements and transportation contracts, power generation contracts, natural gas storage and other contracts.
Revenues from non-lease components associated with a lease arrangement are recognized systematically over the term of the contract.
The majority of income earned from marketing activities, as it relates to the purchase and sale of natural gas and electricity, is recorded on a net basis in the month of delivery.
Canadian Natural Gas Pipelines
Capacity Arrangements and Transportation
Revenues from the Company's Canadian natural gas pipelines are generated from contractual arrangements for committed capacity and from the transportation of natural gas. Revenues earned from firm contracted capacity arrangements are recognized ratably over the term of the contract regardless of the amount of natural gas that is transported. Transportation revenues for interruptible or volumetric-based services are recognized when the service is performed.
Revenues from the Company's Canadian natural gas pipelines under federal jurisdiction are subject to regulatory decisions by the CER. The tolls charged on these pipelines are based on revenue requirements designed to recover the costs of providing natural gas capacity for transportation services, which includes a return of and on capital, as approved by the CER. The Company's Canadian natural gas pipelines are generally not subject to earnings volatility related to variances in revenues and costs. These variances, except as related to incentive arrangements, are generally subject to deferral treatment and are recovered or refunded in future tolls. Revenues recognized prior to a CER decision on rates for that period reflect the CER's last approved return on equity (ROE) assumptions. Adjustments to revenues are recorded when the CER decision is received. Canadian natural gas pipelines' revenues are invoiced and received on a monthly basis. The Company does not take ownership of the natural gas that it transports for customers.
150 | TC Energy Consolidated Financial Statements 2024

Other
Through the year, the Company was contracted to provide pipeline construction services to a partially-owned entity for a development fee. The development fee was considered variable consideration due to refund provisions in the contract. The Company recognized its estimate of the most likely amount of the variable consideration to which it was entitled. The development fee was recognized over time as the services were provided based on the input method using an estimate of activity level.
U.S. Natural Gas Pipelines
Capacity Arrangements and Transportation
Revenues from the Company's U.S. natural gas pipelines are generated from contractual arrangements for committed capacity and from the transportation of natural gas. Revenues earned from firm contracted capacity arrangements are generally recognized ratably over the term of the contract regardless of the amount of natural gas that is transported. Transportation revenues for interruptible or volumetric-based services are recognized when the service is performed.
The Company's U.S. interstate natural gas pipelines are subject to FERC regulations and, as a result, a portion of revenues collected may be subject to refund if invoiced during an interim period when a rate proceeding is ongoing. Allowances for these potential refunds are recognized using management's best estimate based on the facts and circumstances of the proceeding. Any allowances that are recognized during the proceeding process are refunded or retained at the time a regulatory decision becomes final. U.S. natural gas pipelines' revenues are invoiced and received on a monthly basis. The Company does not take ownership of the natural gas that it transports for customers.
Natural Gas Storage and Other
Revenues from the Company's regulated U.S. natural gas storage services are generated mainly from firm committed capacity storage contracts. The performance obligation in these contracts is the reservation of a specified amount of capacity for storage including specifications with regard to the amount of natural gas that can be injected or withdrawn on a daily basis. Revenues are recognized ratably over the contract period for firm committed capacity regardless of the amount of natural gas that is stored, and when gas is injected or withdrawn for interruptible or volumetric-based services. Natural gas storage services revenues are invoiced and received on a monthly basis. The Company does not take ownership of the natural gas that it stores for customers.
The Company owns mineral rights associated with certain natural gas storage facilities. These mineral rights can be leased or contributed to producers of natural gas in return for a royalty interest which is recognized when natural gas and associated liquids are produced.
Mexico Natural Gas Pipelines
Capacity Arrangements and Transportation
Revenues from certain of the Company's Mexico natural gas pipelines are primarily collected based on CRE-approved negotiated firm capacity contracts and are generally recognized ratably over the term of the contract. Transportation revenues related to interruptible or volumetric-based services are recognized when the service is performed. Mexico natural gas pipelines' revenues are invoiced and received on a monthly basis. The Company does not take ownership of the natural gas that it transports for customers.
Other
The Company generates revenues from operating and maintenance services provided on leased pipelines. Revenues earned from these services are recognized ratably over the term of the contract.
TC Energy Consolidated Financial Statements 2024 | 151

Power and Energy Solutions
Power
Revenues from the Company's Power and Energy Solutions business are primarily derived from long-term contractual commitments to provide power capacity to meet the demands of the market and from the sale of electricity to both centralized markets and to customers. Power generation revenues also include revenues from the sale of steam to customers. Revenues and capacity payments are recognized as the services are provided and as electricity and steam is delivered. Power generation revenues are invoiced and received on a monthly basis.
Natural Gas Storage and Other
Non-regulated natural gas storage contracts include park, loan and term storage arrangements. Revenues are recognized as the services are provided. Term storage revenues are invoiced and received on a monthly basis. Revenues from ancillary services are recognized as the service is provided. The Company does not take ownership of the natural gas that it stores for customers.
Cash and Cash Equivalents
The Company's Cash and cash equivalents consist of cash and highly liquid short-term investments with original maturities of three months or less and are recorded at cost, which approximates fair value.
Inventories
Inventories primarily consist of materials and supplies including spare parts and fuel, proprietary natural gas inventory in storage and emissions allowances and credits not held for compliance. The Company purchases certain emissions allowances and credits as part of bundled arrangements that also include the purchase of electricity for a fixed price. The cost allocated to emissions allowances and credits under such arrangements is based on observable market prices. Inventories are carried at the lower of cost and net realizable value.
Assets Held for Sale
The Company classifies assets as held for sale when management approves and commits to a formal plan to actively market a disposal group and expects the sale to close within the next 12 months. Upon classifying an asset as held for sale, the asset is recorded at the lower of its carrying amount or its estimated fair value, net of selling costs and any losses are recognized in net income. Gains related to the expected sale of these assets are not recognized until the transaction closes. Once an asset is classified as held for sale, depreciation expense is no longer recorded.
Plant, Property and Equipment
Natural Gas Pipelines
Plant, property and equipment for natural gas pipelines is carried at cost. Depreciation is calculated on a straight-line basis once the assets are ready for their intended use. Pipeline and compression equipment are depreciated at annual rates ranging from 0.75 per cent to 6.67 per cent and metering and other plant equipment are depreciated at various rates reflecting their estimated useful lives. The cost of major overhauls of equipment is capitalized and depreciated over the estimated service lives of the overhauls. The cost of regulated natural gas pipelines includes an allowance for funds used during construction (AFUDC) consisting of a debt component and an equity component based on the rate of return on rate base approved by regulators. AFUDC is reflected as an increase in the cost of the assets in Plant, property and equipment with a corresponding credit recognized in Allowance for funds used during construction in the Consolidated statement of income. The equity component of AFUDC is a non-cash expenditure. Interest is capitalized during construction of non-regulated natural gas pipelines.
Natural gas pipelines' linepack and natural gas storage base gas are valued at cost and are maintained to ensure adequate pressure exists to transport natural gas through pipelines and deliver natural gas held in storage. Linepack and base gas are not depreciated.
When rate-regulated natural gas pipelines retire plant, property and equipment from service, the original book cost is removed from the gross plant amount and recorded as a reduction to accumulated depreciation with no amount recorded to net income. Costs incurred to remove plant, property and equipment from service, net of any salvage proceeds, are also recorded in accumulated depreciation.
152 | TC Energy Consolidated Financial Statements 2024

Other
The Company participates as a working interest partner in the development of certain Marcellus and Utica acreage. The working interest allows the Company to invest in drilling activities in addition to receiving a royalty interest in well production. The Company uses the successful efforts method of accounting for natural gas and crude oil resulting from its portion of drilling activities. Capitalized well costs are depleted based on the units of production method.
Power and Energy Solutions
Plant, property and equipment for Power and Energy Solutions assets are recorded at cost and, once the assets are ready for their intended use, depreciated by major component on a straight-line basis over their estimated service lives at average annual rates ranging from two per cent to 20 per cent. Other equipment is depreciated at various rates reflecting their estimated useful lives. The cost of major overhauls of equipment is capitalized and depreciated over the estimated service lives of the overhauls. Interest is capitalized on facilities under construction. When these assets are retired from plant, property and equipment, the original book cost and related accumulated depreciation are derecognized and any gain or loss is recorded in net income.
Natural gas storage base gas, which is valued at original cost, represents gas volumes that are maintained to ensure adequate reservoir pressure exists to deliver gas held in storage. Base gas is not depreciated.
Corporate
Corporate plant, property and equipment is recorded at cost and depreciated on a straight-line basis over its estimated useful life at average annual rates ranging from four per cent to 20 per cent.
Capital Projects in Development
The Company capitalizes project costs once advancement of the project to construction stage is probable or costs are otherwise likely to be recoverable. The Company capitalizes interest costs for non-regulated projects in development and AFUDC for regulated projects in development. Capital projects in development are included in Other long-term assets on the Consolidated balance sheet. These represent larger projects that generally require regulatory or other approvals before physical construction can begin. Once approvals are received, projects are moved to plant, property and equipment under construction.
Leases
The Company determines if     a contract contains a lease at inception of a contract by using judgment in assessing the following aspects: 1) the contract specifies an identified asset which is physically distinct or, if not physically distinct, represents substantially all of the capacity of the asset; 2) the contract provides the customer    with the    right to obtain substantially all of the economic benefits from the use of the asset and 3) the customer has the right to direct how and for what purpose the identified asset is used throughout the period of the contract.
If the contract is determined to contain a lease, further judgment is required to identify separate lease components of the arrangement by assessing whether the lessee can benefit from the right of use either on its own or together with other resources that are readily available to the lessee, as well as if the right of use is neither highly dependent on, nor highly interrelated, with the other rights to use the underlying assets in the contract.
The Company considers non-lease components as distinct elements of a contract that are not related to the use of the leased asset. A good or service that is provided to a customer is distinct if: 1) the    customer can benefit from the good or service either on its own or together with other resources that are readily available to the customer and 2) the entity’s promise to transfer the good or service to the customer is separately identifiable from other promises in the contract. The Company applies the practical expedient to not separate lease and non-lease components for all lessee contracts and facilities for which the Company is the lessor in an operating lease.
TC Energy Consolidated Financial Statements 2024 | 153

Lessee Accounting Policy
Operating leases are recognized as right-of-use (ROU) assets and included in Plant, property and equipment while corresponding liabilities are included in Accounts payable and other and Other long-term liabilities on the Consolidated balance sheet.
Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at the commencement date of the lease agreement. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that option. As the Company's lease contracts do not provide an implicit interest rate, the Company uses its incremental borrowing rate based on the information available at commencement date in determining the present value of future payments. Operating lease expense is recognized on a straight-line basis over the lease term and included in Plant operating costs and other in the Consolidated statement of income.
The Company applies the practical expedient to not recognize ROU assets or lease liabilities for leases that qualify for the short-term lease recognition exemption.
Lessor Accounting Policy
The Company provides transportation and other services on certain assets to customers according to long-term service agreements through sales-type and operating leases.
In a sales-type lease, the Company measures the total consideration within the contract at lease commencement. When a lease arrangement contains more than one lease and/or non-lease component, a portion of the contract consideration is allocated to each component based on the stand-alone selling price for each distinct service. The Company applies judgment to determine reasonable estimates of the expected future cost of satisfying the performance obligations of each service. The payments associated with lease components are apportioned between a reduction in the lease receivable and sales-type lease income.
At lease commencement, the Company recognizes a net investment in lease represented by the present value of both the future lease payments and the estimated residual value of the leased asset. The plant, property and equipment of the leased asset is derecognized, with related gains/losses, if any, recognized in the Consolidated statement of income. Sales-type lease income is determined using the rate implicit in the lease and is recorded in Revenues.
The Company is the lessor within certain other contracts, including PPAs, that are accounted for as operating leases. In an operating lease, the leased asset remains capitalized in Plant, property and equipment on the Consolidated balance sheet and is depreciated over its useful life, while lease payments are recognized as revenue over the term of the lease on a straight-line basis. Variable lease payments are recognized as income in the period in which they occur.
Impairment of Long-Lived Assets
The Company reviews long-lived assets such as plant, property and equipment and capital projects in development for impairment whenever events or changes in circumstances indicate the carrying value may not be recoverable. If the total of the estimated undiscounted future cash flows for an asset within plant, property and equipment, or the estimated selling price of any long-lived asset is less than the carrying value of an asset, an impairment loss is recognized for the excess of the carrying value over the estimated fair value of the asset.
Impairment of Equity Method Investments
The Company reviews equity method investments for impairment when an event or change in circumstances has a significant adverse effect on the investment's fair value. Where the Company concludes an investment's fair value is below its carrying value, the Company then determines whether the impairment is other-than-temporary, and if so, an impairment loss is recognized for the excess of the carrying value over the estimated fair value of the investment, not exceeding the carrying value of the investment.
Acquisitions and Goodwill
The Company accounts for business combinations using the acquisition method of accounting and, accordingly, the assets and liabilities of the acquired entities are primarily measured at their estimated fair values at the date of acquisition. The excess of the fair value of the consideration transferred over the estimated fair value of the net assets acquired is classified as goodwill. Goodwill is not amortized and is tested for impairment on an annual basis, or more frequently if events or changes in circumstances indicate that it might be impaired.
154 | TC Energy Consolidated Financial Statements 2024

The annual review for goodwill impairment is performed at the reporting unit level which is one level below the Company's operating segments. The Company can initially assess qualitative factors to determine whether events or changes in circumstances indicate that goodwill might be impaired. The factors the Company considers include, but are not limited to, macroeconomic conditions, industry and market considerations, current valuation multiples and discount rates, cost factors, historical and forecasted financial results and events specific to that reporting unit.
If the Company concludes that it is not more likely than not that the fair value of the reporting unit is greater than its carrying value, the Company will then perform a quantitative goodwill impairment test. The Company can elect to proceed directly to the quantitative goodwill impairment test for any of its reporting units. If the quantitative goodwill impairment test is performed, the Company compares the fair value of the reporting unit to its carrying value, including its goodwill. If the carrying value of a reporting unit exceeds its fair value, goodwill impairment is measured at the amount by which the reporting unit’s carrying value exceeds its fair value. The fair value of a reporting unit is determined by using a discounted cash flow analysis which requires the use of assumptions that may include, but are not limited to, revenue and capital expenditure projections, valuation multiples and discount rates. The Company has elected to allocate goodwill impairment charges first to goodwill that is non-deductible for income tax purposes, with any remaining charge allocated to tax-deductible goodwill.
When a portion of a reporting unit that constitutes a business is disposed, goodwill associated with that business is included in the carrying amount of the business in determining the gain or loss on disposal. The amount of goodwill disposed is determined based on the relative fair values of the business to be disposed and the portion of the reporting unit that will be retained. A goodwill impairment test will be completed for both the goodwill disposed and the portion of the goodwill that will be retained.
Non-Controlling Interests
Non-controlling interests (NCI) represent third-party ownership interests in certain consolidated subsidiaries of the Company. Partial dispositions which result in a change in the Company's ownership interest, but do not result in a change in control, of a subsidiary that constitutes a business are accounted for as equity transactions. No gain or loss is recognized in earnings. At the time of partial disposition, NCI is recorded as the third party's ownership interest in the Company's carrying value of the net assets of the subsidiary. Any difference between the amount by which the NCI is adjusted and the fair value of the consideration paid or received is recognized in Additional paid-in capital and/or Retained earnings (Accumulated deficit).
Loans and Receivables
Loans receivable from affiliates and accounts receivable are measured at amortized cost.
Impairment of Financial Assets
The Company reviews financial assets, inclusive of net investment in leases and certain contract assets, carried at amortized cost for impairment using the lifetime expected loss of the financial asset at initial recognition and throughout the life of the financial asset. An expected credit loss (ECL) is calculated using a model and methodology based on assumptions and judgment considering historical data, current counterparty information as well as reasonable and supportable forecasts of future economic conditions.
The ECL is recognized in Plant operating costs and other in the Consolidated statement of income, and is presented on the Consolidated balance sheet as a reduction to the carrying value of the related financial asset.
Restricted Investments
The Company has certain investments that are restricted as to their withdrawal and use. These restricted investments are classified as available for sale and are recorded at fair value on the Consolidated balance sheet.
As a result of the CER’s Land Matters Consultation Initiative (LMCI), TC Energy is required to collect funds to cover estimated future pipeline abandonment costs for larger CER-regulated Canadian pipelines. Funds collected are placed in trusts that hold and invest the funds and are accounted for as restricted investments (LMCI restricted investments). LMCI restricted investments may only be used to fund the abandonment of the CER-regulated pipeline facilities, therefore, a corresponding regulatory liability is recorded on the Consolidated balance sheet. The Company also has other restricted investments that have been set aside to fund insurance claim losses to be paid by the Company's wholly-owned captive insurance subsidiary.
TC Energy Consolidated Financial Statements 2024 | 155

Income Taxes
The Company uses the asset and liability method of accounting for income taxes. This method requires the recognition of deferred income tax assets and liabilities for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred income tax assets and liabilities are measured using enacted tax rates at the balance sheet date that are anticipated to apply to taxable income in the years in which temporary differences are expected to be reversed or settled. Changes to these balances are recognized in net income in the period in which they occur, except for changes in balances related to regulated natural gas pipelines which are deferred until they are refunded or recovered in tolls, as permitted by the regulator. Deferred income tax assets and liabilities are classified as non-current on the Consolidated balance sheet. The Company’s exposure to uncertain tax positions is evaluated and a provision is made where it is more likely than not that this exposure will materialize.
Canadian income taxes are not provided for on the unremitted earnings of foreign investments that the Company does not intend to repatriate in the foreseeable future.
Any interest and/or penalty incurred related to income tax is reflected in Income tax expense.
Asset Retirement Obligations
The Company recognizes the fair value of a liability for asset retirement obligations (ARO) in the period in which it is incurred, when a legal obligation exists and a reasonable estimate of fair value can be made. The fair value is added to the carrying amount of the associated asset and the liability is accreted through charges to Plant operating costs and other in the Consolidated statement of income.
In determining the fair value of ARO, the following assumptions are used:
•the expected retirement date
•the scope and cost of abandonment and reclamation activities that are required
•appropriate inflation and discount rates.
The Company's AROs are substantially related to its power generation facilities. The scope and timing of asset retirements related to the Company's natural gas pipelines and storage facilities are indeterminable because the Company intends to operate them as long as there is supply and demand. As a result, the Company has not recorded an amount for ARO related to these assets.
Environmental Liabilities and Emission Allowances and Credits
The Company records liabilities on an undiscounted basis for environmental remediation efforts that are likely to occur and where the cost can be reasonably estimated. These estimates, including associated legal costs, are based on available information using existing technology and enacted laws and regulations and are subject to revision in future periods based on actual costs incurred or new circumstances. TC Energy evaluates recoveries from insurers and other third parties separately from the liability and, when recovery is probable, an asset is recorded separately from the associated liability. These recoveries are presented, along with environmental remediation costs, on a net basis in Plant operating costs and other in the Consolidated statement of income. Variations in one or more of the categories described above could result in additional costs such as fines, penalties and/or expenditures associated with litigation and settlement of claims with respect to environmental liabilities.
Emission allowances or credits purchased for compliance are recorded on the Consolidated balance sheet at historical cost and derecognized when they are utilized or cancelled/retired by government agencies. Compliance costs are expensed when incurred. Allowances granted to or internally generated by TC Energy are not attributed a value for accounting purposes. When required, TC Energy accrues emission liabilities on the Consolidated balance sheet using the best estimate of the amount required to settle the compliance obligation. Allowances and credits not used for compliance are sold and any gain or loss is recorded in Revenues within the Power and Energy Solutions segment in the Consolidated statement of income. The Company records allowances and credits held for compliance in Other current assets and Other long-term assets on the Consolidated balance sheet. Allowances and credits not held for compliance are classified as Inventories on the Consolidated balance sheet.
156 | TC Energy Consolidated Financial Statements 2024

Stock Options and Other Compensation Programs
TC Energy's Stock Option Plan permits options for the purchase of common shares to be awarded to certain employees, including officers. Stock options granted are recorded using the fair value method. Under this method, compensation expense is measured at the grant date based on the fair value as calculated using a binomial model and is recognized on a straight-line basis over the vesting period with an offset to Additional paid-in capital. Forfeitures are accounted for when they occur. Upon exercise of stock options, amounts originally recorded against Additional paid-in capital are reclassified to Common shares on the Consolidated balance sheet.
The Company has medium-term incentive plans under which payments are made to eligible employees. The expense related to these incentive plans is accounted for on an accrual basis. Under these plans, benefits vest when certain conditions are met, including the employees' continued employment during a specified period and achievement of specified corporate performance targets.
Employee Post-Retirement Benefits
The Company sponsors defined benefit pension plans (DB Plans), defined contribution plans (DC Plans), savings plans and other post-retirement benefit plans (OPEB Plans). Contributions made by the Company to the DC Plans and savings plans are expensed in the period in which contributions are made. The cost of the DB Plans and OPEB Plans received by employees is actuarially determined using the projected benefit method pro-rated based on service and management's best estimate of expected plan investment performance, salary escalation, retirement age of employees and expected health care costs.
The DB Plans' assets are measured at fair value at December 31 of each year. The expected return on the DB Plans' assets is determined using market-related values based on a five-year moving average value for all of the DB Plans' assets. Past service costs are amortized over the expected average remaining service life (EARSL) of the employees. Adjustments arising from plan amendments are amortized on a straight-line basis over the EARSL of employees active at the date of amendment. The Company recognizes the overfunded or underfunded status of its DB Plans as an asset or liability, respectively, on its Consolidated balance sheet and recognizes changes in that funded status through Other comprehensive income (loss)(OCI) in the year in which the change occurs. The excess of net actuarial gains or losses over 10 per cent of the greater of the benefit obligation and the market-related value of the DB Plans' assets, if any, is amortized out of Accumulated other comprehensive income (loss)(AOCI) and into net income over the EARSL of the active employees. When the restructuring of a benefit plan gives rise to both a curtailment and a settlement, the curtailment is accounted for prior to the settlement.
For certain regulated operations, post-retirement benefit amounts are recoverable through tolls as benefits are funded. The Company records any unrecognized gains or losses or changes in actuarial assumptions related to these post-retirement benefit plans as either regulatory assets or liabilities. The regulatory assets or liabilities are amortized on a straight-line basis over the EARSL of active employees.
Foreign Currency Transactions and Translation
Foreign currency transactions are those transactions whose terms are denominated in a currency other than the currency of the primary economic environment in which the Company or reporting subsidiary operates. This is referred to as the functional currency. Transactions denominated in foreign currencies are translated into the functional currency using the exchange rate prevailing at the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to the functional currency using the rate of exchange in effect at the balance sheet date whereas non-monetary assets and liabilities are translated at the historical rate of exchange in effect on the date of the transaction. Exchange gains and losses resulting from translation of monetary assets and liabilities are recorded in net income except for exchange gains and losses on any foreign currency debt related to Canadian regulated natural gas pipelines, which are deferred until they are refunded or recovered in tolls, as permitted by the CER.
Gains and losses arising from translation of foreign operations' functional currencies to the Company's Canadian dollar reporting currency are reflected in OCI until the operations are sold, at which time the gains and losses are reclassified to net income. Asset and liability accounts are translated at the rate of exchange in effect at the balance sheet date while revenues, expenses, gains and losses are translated at the exchange rate prevailing at the date of the transaction. The Company's U.S. dollar-denominated debt and certain derivative hedging instruments have been designated as a hedge of the net investment in foreign subsidiaries and, as a result, the unrealized foreign exchange gains and losses on the U.S. dollar-denominated debt and derivatives are also reflected in OCI.
TC Energy Consolidated Financial Statements 2024 | 157

Derivative Instruments and Hedging Activities
All derivative instruments are recorded on the Consolidated balance sheet at fair value, unless they qualify for and are designated under a normal purchase and normal sales exemption, or are considered to meet other permitted exemptions.
The Company applies hedge accounting to arrangements that qualify for and are designated for hedge accounting treatment. This includes fair value and cash flow hedges as well as hedges of foreign currency exposures of net investments in foreign operations. Hedge accounting is discontinued prospectively if the hedging relationship ceases to be effective or the hedging or hedged items cease to exist as a result of maturity, expiry, sale, termination, cancellation or exercise.
In a fair value hedging relationship, the carrying value of the hedged item is adjusted for changes in fair value attributable to the hedged risk and these changes are recognized in net income. Changes in the fair value of the hedged item, to the extent that the hedging relationship is effective, are offset by changes in the fair value of the hedging item, which are also recorded in net income. Changes in the fair value of foreign exchange and interest rate fair value hedges are recorded in Interest income and other and Interest expense, respectively. If hedge accounting is discontinued, the carrying value of the hedged item is no longer adjusted and the cumulative fair value adjustments to the carrying value of the hedged item are amortized to net income over the remaining term of the original hedging relationship.
In a cash flow hedging relationship, the change in the fair value of the hedging derivative is recognized in OCI. When hedge accounting is discontinued, the amounts recognized previously in AOCI are reclassified to Revenues, Interest expense and Interest income and other, as appropriate, during the periods when the variability in cash flows of the hedged item affects net income or as the original hedged item settles. Gains and losses on derivatives are reclassified immediately to net income from AOCI when the hedged item is sold or terminated early, or when it becomes probable that the anticipated transaction will not occur. Termination payments on interest rate derivatives are classified as a financing activity in the Consolidated statement of cash flows.
In hedging the foreign currency exposure of a net investment in a foreign operation, the foreign exchange gains and losses on the hedging instruments are recognized in OCI. The amounts recognized previously in AOCI are reclassified to net income in the event the Company reduces its net investment in a foreign operation.
In some cases, derivatives do not meet the specific criteria for hedge accounting treatment. In these instances, the changes in fair value are recorded in net income in the period of change.
Gains and losses arising from changes in the fair value of derivatives accounted for as part of RRA, including those that qualify for hedge accounting treatment, are refunded or recovered through the tolls charged by the Company. As a result, these gains and losses are deferred as regulatory liabilities or regulatory assets and are refunded to or collected from rate payers in subsequent periods when the derivative settles.
Derivatives embedded in other financial instruments or contracts (host instrument) are recorded as separate derivatives. Embedded derivatives are measured at fair value if their economic characteristics are not clearly and closely related to those of the host instrument, their terms are the same as those of a stand-alone derivative and the total contract is not held for trading or accounted for at fair value. When changes in the fair value of embedded derivatives are measured separately, they are included in net income.
Long-Term Debt Transaction Costs and Issuance Costs
The Company records long-term debt transaction costs and issuance costs as a deduction from the carrying amount of the related debt liability and amortizes these costs using the effective interest method except those related to the Canadian natural gas regulated pipelines, which continue to be amortized on a straight-line basis in accordance with the provisions of regulatory tolling mechanisms.
Guarantees
Upon issuance, the Company records the fair value of certain guarantees entered into by the Company on behalf of a partially-owned entity or by partially-owned entities for which contingent payments may be made. The fair value of these guarantees is estimated by discounting the cash flows that would be incurred by the Company if letters of credit were used in place of the guarantees as appropriate in the circumstances. Guarantees are recorded as an increase to Equity investments or Plant, property and equipment and a corresponding liability is recorded in Other long-term liabilities. The release from the obligation is recognized either over the term of the guarantee or upon expiration or settlement of the guarantee.
158 | TC Energy Consolidated Financial Statements 2024

Variable Interest Entities
A VIE is a legal entity that does not have sufficient equity at risk to finance its activities without additional subordinated financial support or is structured such that equity investors lack the ability to make significant decisions relating to the entity’s operations through voting rights or do not substantively participate in the gains and losses of the entity. The assessment of whether an entity is a VIE and, if so, whether the Company is the primary beneficiary, is completed at the inception of the entity or at a reconsideration event.
Consolidated VIEs
The Company's consolidated VIEs consist of legal entities where the Company has a variable interest and for which it is considered the primary beneficiary. As the primary beneficiary, the Company has the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact economic performance including: purchasing or selling significant assets; maintenance and operations of assets; incurring additional indebtedness; or determining the strategic operating direction of the entity. In addition, the Company has the obligation to absorb losses or the right to receive benefits from the consolidated VIE that could potentially be significant to the VIE.
Non-Consolidated VIEs
The Company’s non-consolidated VIEs consist of legal entities where the Company has a variable interest but is not the primary beneficiary as it does not have the power (either explicit or implicit), through voting or similar rights, to direct the activities that most significantly impact the economic performance of these VIEs or where this power is shared with third parties. The Company contributes capital to these VIEs and receives ownership interests that provide it with residual claims on assets after liabilities are paid. Non-consolidated VIEs are accounted for as equity investments.
The Company’s maximum exposure to loss is the maximum loss that could potentially be recorded through net income in future periods as a result of the Company’s variable interest in a VIE.
TC Energy Consolidated Financial Statements 2024 | 159

3.  ACCOUNTING CHANGES
Changes in Accounting Policies for 2024
Segment Reporting
In November 2023, the Financial Accounting Standards Board (FASB) issued new guidance to improve disclosures about a public entity's reportable segments and address requests from investors for additional, more detailed information about a reportable segment's expenses. The guidance was effective for annual periods beginning January 1, 2024 and interim periods beginning January 1, 2025. The Company adopted the guidance effective January 1, 2024. Refer to Note 5, Segmented information.
Leases
In March 2023, the FASB issued new guidance that clarified the accounting for leasehold improvements associated with common control leases. This new guidance was effective January 1, 2024 and adoption did not have a material impact on the Company's consolidated financial statements.
Future Accounting Changes
Income Taxes
In December 2023, the FASB issued new guidance to enhance the transparency and decision usefulness of income tax disclosures through improvements to the rate reconciliation and income taxes paid information. The guidance also includes certain other amendments to improve the effectiveness of income tax disclosures. This new guidance is effective for annual periods beginning January 1, 2025. The guidance is applied prospectively with retrospective application permitted. Early adoption is permitted for annual financial statements not yet issued. The Company intends to adopt the guidance prospectively and does not intend to early adopt the guidance. The Company is currently assessing the impact of the standard on the Company's consolidated financial statements, but does not expect the guidance to have a material impact on the Company's financial position or results of operations.
Disaggregation of Income Statement Expenses
In November 2024, the FASB issued new guidance requiring additional disclosure on the nature of expenses included in the income statement. The new standard requires disclosures about specific types of expenses included in the expense captions presented on the face of the income statement as well as disclosures about selling expenses. The new guidance is effective for annual periods beginning January 1, 2027 and interim periods beginning January 1, 2028. Early adoption is permitted. The guidance is applied prospectively with retrospective application permitted. The Company intends to adopt the guidance prospectively and does not intend to early adopt the guidance. The Company is currently assessing the impact of the standard on the Company's consolidated financial statements.
160 | TC Energy Consolidated Financial Statements 2024

4.  DISCONTINUED OPERATIONS
Spinoff of Liquids Pipelines Business
Agreements
Pursuant to the October 1, 2024 Spinoff Transaction described in Note 1, Description of TC Energy's business, TC Energy and South Bow have executed a series of agreements to outline the parameters and guidelines that govern their ongoing relationship. A Transition Services Agreement has been established to specify certain services that TC Energy will provide to South Bow for a period of up to two years. These services primarily include access to, and support of, systems that South Bow will continue to use until it has fully implemented new systems to support its business processes and warehouse management services.
A Tax Matters Agreement was executed to govern TC Energy and South Bow's tax rights and obligations after the Spinoff Transaction. The agreement imposes certain restrictions on both TC Energy and South Bow in order to preserve the tax-free status of the spinoff. In the event the Spinoff Transaction is not tax-free, the agreement allocates tax liabilities by generally assigning responsibility to either TC Energy or South Bow to the extent that the failure to qualify is attributable to actions, events or transactions, or a breach of the representations or covenants made by that entity.
A Separation Agreement was established to specify the separation of assets and liabilities between TC Energy and South Bow. The agreement states, among other things, that TC Energy will indemnify South Bow for 86 per cent of total net liabilities and costs arising from the Milepost 14 incident that occurred on the Keystone Pipeline System in December 2022 and the existing variable toll disputes on the Keystone Pipeline System (excluding any future impacts with respect to the variable toll after October 1, 2024), subject to a maximum liability to South Bow of $30 million, in aggregate, for those two matters.
At December 31, 2023, the Company accrued a life-to-date environmental liability for the Milepost 14 incident of $794 million, before expected insurance recoveries and not including potential fines and penalties which were indeterminable. Prior to the Spinoff Transaction, for the nine months ended September 30, 2024, amounts paid for the environmental remediation liability were $92 million (twelve months ended December 31, 2023 – $676 million). For the year ended December 31, 2024, the Company received $99 million (2023 – $575 million) from its insurance policies related to the costs for environmental remediation. In addition, the Company also received insurance proceeds of $36 million that were collected from the Company’s wholly-owned captive insurance subsidiary. As part of the Separation Agreement, all future insurance recoveries will remain with TC Energy.
For the year ended December 31, 2024, the Company recorded a pre-tax expense of $37 million for its current estimate of potential incremental costs related to the Milepost 14 incident. This amount represents TC Energy’s 86 per cent share pursuant to the indemnity provisions in the Separation Agreement.
Amounts accrued for these matters are recorded as current assets and liabilities from discontinued operations. Due to the inherent uncertainties of the final amounts to be settled under these indemnities, any amounts that may ultimately be payable in respect of these net liabilities to South Bow could differ materially from those reported at December 31, 2024.
Separation Costs
Liquids Pipelines business separation costs primarily include internal costs related to separation activities, legal, income tax, audit and other consulting fees, insurance provisions and net financial charges related to debt issued and held in escrow. For the years ended December 31, 2024 and 2023, Liquids Pipelines business separation costs of $197 million ($167 million after tax) and $40 million ($34 million after tax), respectively, were included in Net income (loss) from discontinued operations, net of tax in the Consolidated statement of income.
TC Energy Consolidated Financial Statements 2024 | 161

Pensions
As part of the Spinoff Transaction, certain TC Energy employees became employees of South Bow. Prior to the Spinoff Transaction, these employees in Canada and the U.S. participated in DB Plans, DC Plans and savings plans, as applicable. Effective October 1, 2024, the benefit obligations under the DB Plans in respect of the employees moving from TC Energy to South Bow were transferred to South Bow. An asset transfer application related to the Canadian DB Plan will be prepared in early 2025 outlining the proposed transfer of assets from TC Energy to South Bow. The Canadian DB Plan's assets to be transferred to South Bow are subject to regulatory approval and will be transferred when approval is received. As at December 31, 2024, these assets remain in the TC Energy DB Plan trust and have been reflected as Long-term assets of discontinued operations and a corresponding obligation to South Bow has been reflected as Long-term liabilities of discontinued operations on the Consolidated balance sheet. The assets related to the U.S. DB Plan were fully transferred to South Bow as at December 31, 2024.
South Bow Debt
On August 28, 2024, South Bow Canadian Infrastructure Holdings Ltd. and 6297782 LLC, two wholly-owned subsidiaries of the Company at the time, completed an offering of approximately $7.9 billion Canadian-dollar equivalent of senior unsecured notes and junior subordinated notes. Approximately $6.2 billion Canadian-dollar equivalent of the net proceeds was placed in escrow pending the completion of the Spinoff Transaction on October 1, 2024 and US$1.3 billion of senior unsecured notes were used to repay a TransCanada PipeLines Limited (TCPL) term loan. Upon completion of the Spinoff Transaction, the escrowed funds were released to South Bow and used to repay indebtedness owed by South Bow and its subsidiaries to TC Energy and its subsidiaries.
Presentation of Discontinued Operations
Upon completion of the Spinoff Transaction, the Liquids Pipelines business was accounted for as discontinued operations. The Company's presentation of discontinued operations includes revenues and expenses directly attributable to the Liquids Pipelines business. As such, the results of discontinued operations excludes shared costs related to TC Energy’s corporate services and governance functions that had provided support, and whose costs had been historically allocated, to the Liquids Pipelines segment. Depreciation expense related to Corporate shared assets has also been excluded from the results of discontinued operations. The Company has elected to allocate a portion of interest expense incurred at the corporate level to discontinued operations.
Prior year amounts have been reclassified to present the Liquids Pipelines business as discontinued operations.
Income from Discontinued Operations
year ended December 31
(millions of Canadian $)
2024¹
 2023 2022
Revenues 2,217  2,667  2,668 
Income (Loss) from Equity Investments 50  67  55 
Operating and Other Expenses
Plant operating costs and other 806  814  704 
Commodity purchases resold 387  437  512 
Property taxes 84  116  121 
Depreciation and amortization 253  332  322 
Asset impairment charge and other 21  (4) (118)
1,551  1,695  1,541 
Segmented Earnings (Losses) from Discontinued Operations 716  1,039  1,182 
Financial Charges
Interest expense
 218  297  288 
Interest income and other
 (21) 30  (6)
197  327  282 
Income (Loss) from Discontinued Operations before Income Taxes
 519  712  900 
Income tax expense (recovery)
 124  100  267 
Net Income (Loss) from Discontinued Operations, Net of Tax
 395  612  633 
1    Represents nine months of Liquids Pipelines earnings in 2024 compared to a full year of Liquids Pipelines earnings in 2023 and 2022.
162 | TC Energy Consolidated Financial Statements 2024

Assets and Liabilities of Discontinued Operations
at December 31
(millions of Canadian $) 2024 2023
ASSETS
Current Assets
Accounts receivable —  1,782 
Inventories —  211 
Other current assets
 235  1,084 
235  3,077 
Plant, Property and Equipment
 —  11,118 
Equity Investments
 —  1,074 
Other Long-Term Assets
 136  241 
371  15,510 
LIABILITIES
Current Liabilities
Accounts payable and other
 170  2,682 
170  2,682 
Other Long-Term Liabilities
 110  127 
Deferred Income Tax Liabilities
 —  1,153 
280  3,962 
The Spinoff Transaction resulted in derecognition of the net assets of the Liquids Pipelines segment in the amount of
$3,691 million. The reduction in net assets was reflected as a $2,950 million decrease in Retained earnings (Accumulated deficit) and a $741 million decrease in Accumulated other comprehensive income (loss) on the Consolidated statement of equity.
Cash Flows from Discontinued Operations
year ended December 31
(millions of Canadian $) 2024 2023 2022
Net cash provided by operations
 670  1,026  709 
Net cash (used in) provided by investing activities (89) 87  502 
TC Energy Consolidated Financial Statements 2024 | 163

5.  SEGMENTED INFORMATION
The Company’s chief operating decision maker is the President and Chief Executive Officer. The chief operating decision maker uses segmented earnings (losses) to assess the performance of the business segments, assist with capital investment decisions and benchmark to TC Energy’s competitors.
Information regarding the Company's business segments is as follows:
year ended December 31, 2024 Canadian Natural Gas Pipelines U.S.
Natural Gas Pipelines		 Mexico Natural Gas Pipelines Power and Energy Solutions Corporate Total
(millions of Canadian $) 1
Revenues 5,600  6,339  870  954  8  13,771 
Intersegment revenues2
 —  99  —  49  (148) — 
5,600  6,438  870  1,003  (140) 13,771 
Income (loss) from equity investments 34  341  283  900  —  1,558 
Operating costs2
 (2,246) (2,381) (132) (700) 9  3 (5,450)
Depreciation and amortization (1,382) (955) (92) (101) (5) 3 (2,535)
Other segment items4
 10  610  —  —  —  620 
Segmented Earnings (Losses)
2,016  4,053  929  1,102  (136) 7,964 
Interest expense       (3,019)
Allowance for funds used during construction 784 
Foreign exchange gains (losses), net
 (147)
Interest income and other       324 
Income (Loss) from Continuing Operations before Income Taxes
     5,906 
Income tax (expense) recovery from continuing operations
     (922)
Net Income (Loss) from Continuing Operations
     4,984 
Net Income (Loss) from Discontinued Operations, Net of Tax
 395 
Net Income (Loss)
 5,379 
Net (income) loss attributable to non-controlling interests     (681)
Net Income (Loss) Attributable to Controlling Interests
  4,698 
Preferred share dividends     (104)
Net Income (Loss) Attributable to Common Shares
 4,594 
Capital Spending5
Capital expenditures 1,273  2,568  2,228  62  50  6,181 
Capital projects in development —  5  —  45  —  50 
Contributions to equity investments6
 827  2  —  717  —  1,546 
2,100  2,575  2,228  824  50  7,777 
Discontinued operations
 127 
7,904 
1Includes intersegment eliminations.
2The Company records intersegment sales at contracted rates. For segmented reporting, these transactions are included as Intersegment revenues in the segment providing the service and Operating costs in the segment receiving the service. These transactions are eliminated on consolidation. Intersegment profit is recognized when the product or service has been provided to third parties or otherwise realized.
3Includes shared costs and depreciation previously allocated to the Liquids Pipelines segment. Refer to Note 4, Discontinued operations, for additional information.
4Other segment items include a Net gain (loss) on sale of assets.
5Included in Investing activities in the Consolidated statement of cash flows.
6Contributions to equity investments in the Canadian Natural Gas Pipelines segment of $3.1 billion are offset by the equivalent amount in Other distributions from equity investments, although they are reported on a gross basis in the Company’s Consolidated statement of cash flows. Refer to Note 7, Coastal GasLink, for additional information.
164 | TC Energy Consolidated Financial Statements 2024


year ended December 31, 2023 Canadian Natural Gas Pipelines U.S.
Natural Gas Pipelines		 Mexico Natural Gas Pipelines Power and Energy Solutions
Corporate
 Total
(millions of Canadian $) 1
Revenues
 5,173  6,229  846  1,019  —  13,267 
Intersegment revenues2
 —  101  —  22  (123) — 
5,173  6,330  846  1,041  (123) 13,267 
Income (loss) from equity investments 220  324  78  688  — 

1,310 
Impairment of equity investment
 (2,100) —  —  —  —  (2,100)
Operating costs2
 (2,058) (2,189) (39) (633) (15) 3 (4,934)
Depreciation and amortization (1,325) (934) (89) (92) (6) 3 (2,446)
Segmented Earnings (Losses) (90) 3,531  796  1,004  (144) 5,097 
Interest expense       (2,966)
Allowance for funds used during construction 575 
Foreign exchange gains (losses), net
 320 
Interest income and other       272 
Income (Loss) from Continuing Operations before Income Taxes
    3,298 
Income tax (expense) recovery from continuing operations
       (842)
Net Income (Loss) from Continuing Operations
     2,456 
Net income (loss) from Discontinued Operations, Net of Tax
 612 
Net Income (Loss)
 3,068 
Net Income (loss) attributable to non-controlling interests
 (146)
Net Income (Loss) Attributable to Controlling Interests
    2,922 
Preferred share dividends       (93)
Net Income (Loss) Attributable to Common Shares     2,829 
Capital Spending4
Capital expenditures 2,953  2,536  2,292  144  33  7,958 
Capital projects in development —  —  —  142  —  142 
Contributions to equity investments 3,231  124  —  794  —  4,149 
6,184  2,660  2,292  1,080  33  12,249 
Discontinued operations
 49 
12,298 
1Includes intersegment eliminations.
2The Company records intersegment sales at contracted rates. For segmented reporting, these transactions are included as Intersegment revenues in the segment providing the service and Operating costs in the segment receiving the service. These transactions are eliminated on consolidation. Intersegment profit is recognized when the product or service has been provided to third parties or otherwise realized.
3Includes shared costs and depreciation previously allocated to the Liquids Pipelines segment. Refer to Note 4, Discontinued operations, for additional information.
4Included in Investing activities in the Consolidated statement of cash flows.

TC Energy Consolidated Financial Statements 2024 | 165

year ended December 31, 2022 Canadian Natural Gas Pipelines U.S.
Natural Gas Pipelines		 Mexico Natural Gas Pipelines Power and Energy Solutions
Corporate
 Total
(millions of Canadian $) 1
Revenues 4,764  5,933  688  924  —  12,309 
Intersegment revenues2
 —  132  —  12  (144) — 
4,764  6,065  688  936  (144) 12,309 
Income (loss) from equity investments 18  292  122  539  28  3 999 
Impairment of equity investment
 (3,048) —  —  —  —  (3,048)
Operating costs2
 (1,976) (2,282) (221) (570) 72  4 (4,977)
Depreciation and amortization (1,198) (887) (98) (72) (7) 4 (2,262)
Other segment items5
 —  (571) —  —  —  (571)
Segmented Earnings (Losses) (1,440) 2,617  491  833  (51) 2,450 
Interest expense       (2,300)
Allowance for funds used during construction 369 
Foreign exchange gains (losses), net3
 (185)
Interest income and other       140 
Income (Loss) from Continuing Operations before Income Taxes
     474 
Income tax (expense) recovery from continuing operations
       (322)
Net Income (Loss) from Continuing Operations
     152 
Net Income (Loss) from Discontinued Operations, Net of Tax
 633 
Net Income (Loss)
 785 
Net (income) loss attributable to non-controlling interests
     (37)
Net Income (Loss) Attributable to Controlling Interests
     748 
Preferred share dividends     (107)
Net Income (Loss) Attributable to Common Shares     641
Capital Spending6
Capital expenditures
 3,274  2,137  1,027  93  41  6,572 
Capital projects in development
 —  —  —  49  —  49 
Contributions to equity investments7
 1,445  —  —  752  —  2,197 
4,719  2,137  1,027  894  41  8,818 
Discontinued operations
 143 
8,961 
1Includes intersegment eliminations.
2The Company records intersegment sales at contracted rates. For segmented reporting, these transactions are included as Intersegment revenues in the segment providing the service and Operating costs in the segment receiving the service. These transactions are eliminated on consolidation. Intersegment profit is recognized when the product or service has been provided to third parties or otherwise realized.
3Income (loss) from equity investments includes the Company's proportionate share of Sur de Texas foreign exchange gains and losses on the peso-denominated loans from affiliates which are fully offset in Foreign exchange gains (losses), net by the corresponding foreign exchange losses and gains on the affiliate receivable balance until March 15, 2022, when it was fully repaid upon maturity. Refer to Note 12, Loans receivable from affiliates, for additional information.
4Includes shared costs and depreciation previously allocated to the Liquids Pipelines segment. Refer to Note 4, Discontinued operations, for additional information.
5Other segment items includes a goodwill impairment charge. Refer to Note 14, Goodwill, for additional information.
6Included in Investing activities in the Consolidated statement of cash flows.
7Contributions to equity investments in the Corporate segment of $1.2 billion are offset by the equivalent amount in Other distributions from equity investments, although they are reported on a gross basis in the Company’s Consolidated statement of cash flows. Refer to Note 12, Loans receivable from affiliates, for additional information.
166 | TC Energy Consolidated Financial Statements 2024

at December 31 2024 2023
(millions of Canadian $)
Total Assets by Segment
Canadian Natural Gas Pipelines 31,167  29,782 
U.S. Natural Gas Pipelines 56,304  50,499 
Mexico Natural Gas Pipelines 15,995  12,003 
Power and Energy Solutions 10,217  9,525 
Corporate 4,189  7,715 
117,872  109,524 
Discontinued Operations
 371  15,510 
118,243  125,034 
Geographic Information
year ended December 31 2024 2023 2022
(millions of Canadian $)
Revenues      
Canada – domestic 5,579  5,337  4,920 
Canada – export 953  821  765 
United States 6,369  6,263  5,936 
Mexico 870  846  688 
  13,771  13,267  12,309 
at December 31 2024 2023
(millions of Canadian $)
Plant, Property and Equipment    
Canada 26,354  26,434 
United States 40,580  35,640 
Mexico 10,567  7,377 
  77,501  69,451 
TC Energy Consolidated Financial Statements 2024 | 167

6. REVENUES
Disaggregation of Revenues
year ended December 31, 2024 Canadian
Natural
Gas
Pipelines		 U.S.
Natural
Gas
Pipelines		 Mexico
Natural
Gas
Pipelines		 Power
and
Energy
 Solutions
Total
(millions of Canadian $)
Revenues from contracts with customers
Capacity arrangements and transportation 5,586  5,382  438  —  11,406 
Power generation —  —  —  266  266 
Natural gas storage and other1,2
 14  869  124  383  1,390 
5,600  6,251  562  649  13,062 
Other revenues3
 —  88  —  305  393 
Sales-type lease income4
 —  —  308  —  308 
Corporate revenues5
 —  —  —  —  8 
5,600  6,339  870  954  13,771 
1Includes $14 million of fee revenues from an affiliate related to the development and construction of the Coastal GasLink pipeline project which is 35 per cent owned by TC Energy.
2Includes $98 million of revenues generated from non-lease components for the provision of operating and maintenance services with respect to sales-type leases on the in-service Transportadora de Gas Natural de La Huasteca (TGNH) pipelines. Refer to Note 10, Leases, for additional information.
3Other revenues include income from the Company's operating lease arrangements, marketing activities and financial instruments. Refer to Note 10, Leases, and Note 28, Risk management and financial instruments, for additional information.
4Represents the sales-type lease income on the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
5Includes $7 million of revenues generated from the Transition Services Agreement with South Bow. Refer to Note 4, Discontinued operations, for additional information.
year ended December 31, 2023 Canadian
Natural
Gas
Pipelines		 U.S.
Natural
Gas
Pipelines		 Mexico
Natural
Gas
Pipelines		 Power
and
Energy Solutions
Total
(millions of Canadian $)
Revenues from contracts with customers
Capacity arrangements and transportation 5,141  5,107  442  —  10,690 
Power generation —  —  —  427  427 
Natural gas storage and other1,2
 32  874  125  363  1,394 
5,173  5,981  567  790  12,511 
Other revenues3
 —  248  —  229  477 
Sales-type lease income4
 —  —  279  —  279 
5,173  6,229  846  1,019  13,267 
1Includes $31 million of fee revenues from an affiliate related to the development and construction of the Coastal GasLink pipeline project which is 35 per cent owned by TC Energy.
2Includes $97 million of revenues generated from non-lease components for the provision of operating and maintenance services with respect to sales-type leases on the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
3Other revenues include income from the Company's operating lease arrangements, marketing activities and financial instruments. Refer to Note 10, Leases, and Note 28, Risk management and financial instruments, for additional information.
4Represents the sales-type lease income on the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
168 | TC Energy Consolidated Financial Statements 2024

year ended December 31, 2022 Canadian
Natural
Gas
Pipelines		 U.S.
Natural
Gas
Pipelines		 Mexico
Natural
Gas
Pipelines		 Power
and
Energy Solutions
Total
(millions of Canadian $)
Revenues from contracts with customers
Capacity arrangements and transportation 4,696  4,621  507  —  9,824 
Power generation —  —  —  490  490 
Natural gas storage and other1,2
 68  1,298  54  391  1,811 
4,764  5,919  561  881  12,125 
Other revenues3,4
 —  14  —  43  57 
Sales-type lease income5
 —  —  127  —  127 
4,764  5,933  688  924  12,309 
1Includes $68 million of fee revenues from an affiliate related to the development and construction of the Coastal GasLink pipeline project which is 35 per cent owned by TC Energy.
2Includes $37 million of revenues generated from non-lease components for the provision of operating and maintenance services with respect to sales-type leases on the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
3Other revenues include income from the Company's operating lease arrangements, marketing activities and financial instruments. Refer to Note 10, Leases, and Note 28, Risk management and financial instruments, for additional information.
4Other revenues from U.S. Natural Gas Pipelines include the amortization of the net regulatory liabilities resulting from H.R. 1, the Tax Cuts and Jobs Act (U.S. Tax Reform). Refer to Note 13, Rate-regulated businesses.
5 Represents the sales-type lease income on the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
Contract Balances
at December 31 2024 2023 Affected line item on the
Consolidated balance sheet
(millions of Canadian $)
Receivables from contracts with customers 1,452  1,388  Accounts receivable
Contract assets (Note 8)
 165  151  Other current assets
Long-term contract assets (Note 15)
 608  457  Other long-term assets
Contract liabilities1 (Note 17)
 30  47  Accounts payable and other
Long-term contract liabilities1
—  2  Other long-term liabilities
1During the year ended December 31, 2024, $41 million (2023 – $47 million) of revenues were recognized that were included in contract liabilities and long-term contract liabilities at the beginning of the year.
Contract assets and long-term contract assets primarily relate to the Company’s right to revenues for services completed but not invoiced at the reporting date on long-term committed capacity natural gas pipelines contracts. The change in contract assets is primarily related to the transfer to Accounts receivable when these rights become unconditional and the customer is invoiced, as well as the recognition of additional revenues that remain to be invoiced. Contract liabilities and long-term contract liabilities primarily represent unearned revenue for contracted services. Under the terms of the consolidated Transportation Service Agreement (TSA), the contract liability relating to current and future in-service pipelines of the Company's Mexico-based subsidiary, Transportadora de Gas Natural de la Huasteca (TGNH), is netted against certain contract asset balances. The resulting net contract liability is settled against Net investment in leases on the Consolidated balance sheet when the pipeline enters into service.
TC Energy Consolidated Financial Statements 2024 | 169

Future Revenues from Remaining Performance Obligations
As at December 31, 2024, future revenues from long-term pipeline capacity arrangements and transportation as well as natural gas storage and other contracts extending through 2055 are approximately $29.1 billion, of which approximately $6.4 billion is expected to be recognized in 2025.
A significant portion of the Company's revenues are not included in the future revenue disclosure above, as the Company has elected the following disclosure exemptions:
•revenues related to flow-through operating costs, or other similar variable consideration, that are recognized at the amount for which the Company has the right to invoice the customer
•variable consideration relating to interruptible transportation service revenues and power generation revenues where there is uncertainty in estimating the amount of future revenue
•revenues for periods extending beyond the current rate settlement term for the Company’s U.S. natural gas pipelines' regulated transportation and storage contracts where the maximum tariff rate is to be collected from shippers
•revenues for periods extending beyond the current rate settlement term for the Company's Canadian natural gas pipelines' regulated firm capacity contracts.
7.  COASTAL GASLINK
On November 18, 2024, Coastal GasLink Pipeline Limited Partnership (Coastal GasLink LP) executed a commercial agreement with LNG Canada (LNGC) and each of the five LNGC participants (LNGC Participants) that declared commercial in-service for the pipeline, allowing for the collection of tolls from customers retroactive to October 1, 2024. The agreement also includes a one-time payment of $199 million from LNGC Participants to TC Energy in recognition of the completion of certain work and the final settlement of costs. The payment is to be made by LNGC Participants upon the earlier of three months after the declared in-service of the LNGC facility, or December 15, 2025. The payment, which accrues in full to TC Energy in accordance with the contractual terms between the Coastal GasLink LP partners, has been accounted for as an in-substance equity distribution from Coastal GasLink LP and reflected in Accounts receivable and Equity investments on the Company's Consolidated balance sheet at December 31, 2024.
Subordinated Loan Agreement
TC Energy has a subordinated loan agreement with Coastal GasLink LP under which the Company advances non-revolving interest-bearing loans subject to floating market-based rates to Coastal GasLink LP to fund capital costs to complete the Coastal GasLink pipeline. At December 31, 2023, this loan had a committed capacity of $3,375 million.
Coastal GasLink LP partners, including TC Energy, were contractually obligated to contribute equity to Coastal GasLink LP to ultimately fund the settlement of amounts outstanding under the subordinated loan agreement. Because of the expectation that the Company would predominantly fund the settlement of the amounts outstanding, amounts drawn under the subordinated loan agreement have been accounted for as in-substance equity contributions and are presented as Contributions to equity investments in the Company’s Consolidated statement of cash flows. Repayments of amounts owed by Coastal GasLink LP to the Company are accounted for as in-substance equity distributions and are presented in Other distributions from equity investments in the Company's Consolidated statement of cash flows.
During the year ended December 31, 2024, draws of $627 million (2023 - $2,520 million) were made by Coastal GasLink LP under the subordinated loan agreement.
On December 17, 2024, following the declared commercial in-service of the pipeline, Coastal GasLink LP repaid the $3,147 million balance owing to TC Energy under the subordinated loan agreement. The Company's share of equity contributions required to fund Coastal GasLink LP's repayment of the outstanding loan balance amounted to $3,137 million. This repayment reduced the Company's funding commitment under the subordinated loan agreement to $228 million at December 31, 2024. At December 31, 2024, $228 million (December 31, 2023 - $855 million) in unused committed capacity remains available for use by Coastal GasLink LP. At December 31, 2024, the balance of loans outstanding under the subordinated loan agreement was nil (December 31, 2023 - $2,520 million).
170 | TC Energy Consolidated Financial Statements 2024

Subordinated Demand Revolving Credit Facility Agreement
The Company has a subordinated demand revolving credit facility agreement with Coastal GasLink LP to provide additional     short-term liquidity and funding flexibility to projects under construction. Facilities available through this agreement bear interest at floating market-based rates and have a combined capacity of $120 million (December 31, 2023 - $100 million) with no outstanding balances at December 31, 2024 and 2023.
Impairment of Equity Investment in Coastal GasLink LP
In February 2023, Coastal GasLink LP announced an increase in the revised capital cost of the Coastal GasLink pipeline. As noted above, the expectation was that equity contributions to fund the increased capital cost would be predominantly funded by TC Energy. For the year ended December 31, 2022 until the quarter ended September 30, 2023, the expectation that additional equity contributions under the subordinated loan agreement would be predominantly funded by TC Energy was an indication of significant adverse impact on the estimated fair value of the Company’s investment in Coastal GasLink LP. The Company completed valuation assessments in each of these periods and concluded that the fair value of its investment in         Coastal GasLink LP was below its carrying value in each period assessed, reflecting other-than-temporary impairments. As a result, the Company recorded cumulative pre-tax impairment charges of $5,148 million, or $4,586 million after tax, between December 31, 2022 and September 30, 2023. No further indication of other-than-temporary impairments of the Company's investment in Coastal GasLink LP have since been identified and no further impairment charges have been recorded.
At December 31, 2024, the carrying value of the Company's investment in Coastal GasLink LP was $1,006 million (2023 – $294 million).
8.  OTHER CURRENT ASSETS
at December 31 2024 2023
(millions of Canadian $)
Fair value of derivative contracts (Note 28)
 347  589 
Current portion of net investment in leases (Note 10)
 333  306 
Contract assets (Note 6)
 165  151 
Cash provided as collateral 128  28 
Regulatory assets (Note 13)
 123  76 
Prepaid expenses 86  87 
Emissions credits
 75  94 
Other 82  88 
  1,339  1,419 
TC Energy Consolidated Financial Statements 2024 | 171

9.  PLANT, PROPERTY AND EQUIPMENT
at December 31 2024 2023
Cost Accumulated
Depreciation
Net
Book Value
 Cost Accumulated
Depreciation
Net
Book Value
(millions of Canadian $)
Canadian Natural Gas Pipelines
NGTL System            
Pipeline 20,497  7,413  13,084  20,232  6,855  13,377 
Compression 7,146  2,497  4,649  6,603  2,349  4,254 
Metering and other 1,668  883  785  1,589  830  759 
  29,311  10,793  18,518  28,424  10,034  18,390 
Under construction 503  —  503  787  —  787 
  29,814  10,793  19,021  29,211  10,034  19,177 
Canadian Mainline            
Pipeline 10,907  8,165  2,742  10,729  7,996  2,733 
Compression 4,540  3,448  1,092  4,437  3,354  1,083 
Metering and other 749  331  418  729  308  421 
  16,196  11,944  4,252  15,895  11,658  4,237 
Under construction 163  —  163  147  —  147 
  16,359  11,944  4,415  16,042  11,658  4,384 
Other Canadian Natural Gas Pipelines1
Other 2,927  1,742  1,185  2,846  1,682  1,164 
Under construction 31  —  31  23  —  23 
2,958  1,742  1,216  2,869  1,682  1,187 
49,131  24,479  24,652  48,122  23,374  24,748 
U.S. Natural Gas Pipelines
Columbia Gas          
Pipeline 14,826  1,472  13,354  12,952  1,247  11,705 
Compression 6,153  677  5,476  5,310  559  4,751 
Metering and other 4,570  455  4,115  4,074  372  3,702 
  25,549  2,604  22,945  22,336  2,178  20,158 
Under construction 891  —  891  771  —  771 
  26,440  2,604  23,836  23,107  2,178  20,929 
ANR            
Pipeline 2,477  745  1,732  2,117  657  1,460 
Compression 4,446  938  3,508  3,928  773  3,155 
Metering and other 1,832  521  1,311  1,625  458  1,167 
  8,755  2,204  6,551  7,670  1,888  5,782 
Under construction 853  —  853  404  —  404 
  9,608  2,204  7,404  8,074  1,888  6,186 
172 | TC Energy Consolidated Financial Statements 2024

at December 31 2024 2023
Cost Accumulated
Depreciation
Net
Book Value
 Cost Accumulated
Depreciation
Net
Book Value
(millions of Canadian $)
Other U.S. Natural Gas Pipelines
Columbia Gulf 4,127  304  3,823  3,600  256  3,344 
GTN 3,405  1,467  1,938  2,992  1,295  1,697 
Great Lakes 2,602  1,537  1,065  2,359  1,401  958 
Other2
 1,695  628  1,067  2,071  800  1,271 
11,829  3,936  7,893  11,022  3,752  7,270 
Under construction 694  —  694  584  —  584 
12,523  3,936  8,587  11,606  3,752  7,854 
48,571  8,744  39,827  42,787  7,818  34,969 
Mexico Natural Gas Pipelines3
Pipeline 2,590  523  2,067  2,290  422  1,868 
Compression 476  107  369  447  82  365 
Metering and other 398  99  299  395  85  310 
3,464  729  2,735  3,132  589  2,543 
Under construction 7,807  —  7,807  4,823  —  4,823 
11,271  729  10,542  7,955  589  7,366 
Power and Energy Solutions            
Natural Gas Power Generation 1,273  671  602  1,239  637  602 
Natural Gas Storage and Other 873  281  592  845  256  589 
Renewable Power Generation
 779  54  725  581  19  562 
  2,925  1,006  1,919  2,665  912  1,753 
Under construction 56  —  56  153  —  153 
  2,981  1,006  1,975  2,818  912  1,906 
Corporate 944  439  505  909  447  462 
  112,898  35,397  77,501  102,591  33,140  69,451 
1Includes Foothills, Ventures LP and Great Lakes Canada.
2Includes North Baja, Tuscarora, Louisiana Intrastate, Crossroads, U.S. Energy Marketing and mineral rights business. On August 15, 2024, the Company completed the sale of Portland Natural Gas Transmission System (PNGTS). Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
3During the year ended December 31, 2024, the Company derecognized nil (2023 – $407 million) of Plant, property and equipment and recorded a corresponding asset for Net investment in leases for the in-service TGNH pipelines. Refer to Note 10, Leases, for additional information.
TC Energy Consolidated Financial Statements 2024 | 173

10.  LEASES
As a Lessee
The Company has operating leases for corporate offices, other various premises, equipment and land. Some leases have an option to renew for periods of one to 25 years, and some may include options to terminate the lease within one year or when certain conditions are met. Payments due under lease contracts include fixed payments plus, for many of the Company's leases, variable payments such as a proportionate share of the buildings' property taxes, insurance and common area maintenance. The Company subleases some of the leased premises.
Operating lease cost was as follows:
year ended December 31
(millions of Canadian $) 2024 2023
Operating lease cost1
 117  105 
Sublease income (6) (4)
Net operating lease cost 111  101 
1    Includes short-term leases and variable lease costs.
Other information related to operating leases is noted in the following tables:
year ended December 31
(millions of Canadian $) 2024 2023
Cash paid for amounts included in the measurement of operating lease liabilities 74  72 
ROU assets obtained in exchange for new operating lease liabilities 96  83 
at December 31 2024 2023
Weighted average remaining lease term 13 years 13 years
Weighted average discount rate 3.3  % 3.3  %
Maturities of operating lease liabilities are as follows:
at December 31
(millions of Canadian $) 2024 2023
Less than one year 73  71 
One to two years 73  68 
Two to three years 66  66 
Three to four years 64  59 
Four to five years 63  58 
More than five years 275  224 
Total operating lease payments 614  546 
Imputed interest (103) (89)
Operating lease liabilities 511  457 
174 | TC Energy Consolidated Financial Statements 2024

The amounts recognized on TC Energy's Consolidated balance sheet for its operating lease liabilities were as follows:
at December 31
(millions of Canadian $) 2024 2023
Accounts payable and other (Note 17)
 60  57
Other long-term liabilities (Note 18)
 451  400
511  457
As at December 31, 2024, the carrying value of the ROU assets recorded under operating leases was $480 million         (2023 – $435 million) and is included in Plant, property and equipment on the Consolidated balance sheet.
As a Lessor
Operating Leases
The Grandview and Bécancour power plants in the Power and Energy Solutions segment are accounted for as operating leases. The Company has long-term PPAs for the sale of power from these assets which expire between 2026 and 2035.
Some operating leases contain variable lease payments that are based on operating hours and the reimbursement of variable costs, and options to purchase the underlying asset at fair value or based on a formula considering the remaining fixed payments. Lessees have rights under some leases to terminate under certain circumstances.
The fixed portion of the operating lease income recorded by the Company for the year ended December 31, 2024 was         $114 million (2023 – $112 million; 2022 – $110 million).
Future lease payments to be received under operating leases are as follows:
at December 31
(millions of Canadian $) 2024 2023
Less than one year 107  111 
One to two years 76  94 
Two to three years 9  70 
Three to four years 10  — 
Four to five years 10  — 
More than five years 55  — 
267  275 
At December 31, 2024, the cost and accumulated depreciation for facilities accounted for as operating leases was $697 million and $351 million, respectively (2023 – $646 million and $333 million, respectively).
TC Energy Consolidated Financial Statements 2024 | 175

Sales-Type Leases
The Tamazunchale, Villa de Reyes and Tula pipelines are part of a U.S. dollar-denominated take-or-pay TSA that extends through 2055 between TGNH and the Comisión Federal de Electricidad (CFE).
The consolidated TSA contains a lease with multiple lease and non-lease components. The lease components within the TSA represent the capacity available to the CFE provided by the in-service pipelines within TGNH at December 31, 2024. The non-lease components represent the Company’s services with respect to operation and maintenance of the TGNH pipelines     in service. The Company allocated a portion of the contract consideration to non-lease components for the provision of operating and maintenance services based on the stand-alone selling price using an expected cost plus margin approach. The remaining consideration was allocated to the lease components using the residual approach due to uncertainty surrounding the stand-alone selling price.
During 2024, the Company did not enter into any new sales-type lease arrangements (2023 – $407 million).
Future lease payments to be received under the existing sales-type leases are as follows:
at December 31
(millions of Canadian $) 2024 2023
Less than one year 333  305 
One to two years 333  305 
Two to three years 333  305 
Three to four years 333  305 
Four to five years 333  305 
More than five years 8,499  8,102 
10,164  9,627 
The following table lists the components of the aggregate net investment in leases reflected on the Company's Consolidated balance sheet:
at December 31
(millions of Canadian $)
 2024 2023
Net Investment in Leases
Minimum lease payments 10,164  9,627 
Unearned lease income
 (7,323) (7,006)
Lease receivable 2,841  2,621 
Expected credit loss provision1
 (59) (76)
Present value of unguaranteed residual value 28  24 
2,810  2,569 
Current portion included in Other current assets (Note 8)
 (333) (306)
2,477  2,263 
1Includes $6 million (2023 – nil) of foreign currency translation losses.
Future lease payments will increase as assets associated with sales-type leases come into service.
For the year ended December 31, 2024, the Company recorded $308 million (2023 – $279 million; 2022 - $127 million) of sales-type lease income.
For the year ended December 31, 2024, the Company recorded a $23 million ECL recovery (2023 – a recovery of $73 million; 2022 – an expense of $149 million) relating to net investment in leases in Plant operating costs and other. Refer to Note 28, Risk management and financial instruments, for additional information.
176 | TC Energy Consolidated Financial Statements 2024

11.  EQUITY INVESTMENTS
(millions of Canadian $)
Ownership 
 Interest at 
 December 31, 2024
Income (Loss) from Equity
Investments
 Equity
Investments
year ended December 31 at December 31
2024 2023 2022 2024 2023
Canadian Natural Gas Pipelines            
TQM1
 50  % 17  17  17  160  166 
Coastal GasLink1,2
 35  % 17  203  1  1,006  294 
U.S. Natural Gas Pipelines
Northern Border 50  % 130  101  92  647  599 
Millennium 47.5  % 95  109  103  (21) 476 
Iroquois 50  % 100  98  77  221  227 
Other Various 16  16  20  135  120 
Mexico Natural Gas Pipelines
Sur de Texas 60  % 283  78  150  1,403  1,078 
Power and Energy Solutions            
Bruce Power1
 48.3  % 900  690  537  7,043  6,242 
Other Various —  (2) 2  42  38 
    1,558  1,310  999  10,636  9,240 
1Classified as a VIE. Refer to Note 32, Variable interest entities, for additional information.
2Refer to Note 7, Coastal GasLink, for additional information.
Coastal GasLink Incentive Payment
The Coastal GasLink project reached mechanical completion in November 2023 and was ready to deliver commissioning gas to the LNGC facility by the end of 2023. These milestones entitled Coastal GasLink LP to receive a $200 million incentive payment from LNGC, which was recorded as Accounts receivable on the Consolidated balance sheet and Income (loss) from equity investments in the Consolidated statement of income as at and for the year ended December 31, 2023. The incentive payment was settled through a cash distribution in February 2024.
Distributions and Contributions
Distributions received from equity investments and contributions made to equity investments for the years ended December 31, 2024, 2023 and 2022 were as follows:
year ended December 31 2024 2023 2022
(millions of Canadian $)
Distributions      
Distributions received from operating activities of equity investments 1,607  1,158  955 
Coastal GasLink LP subordinated loan repayment1,2
 3,147  —  — 
Sur de Texas debt repayments2,3
 —  —  2,404 
Other2
 539  23  228 
5,293  1,181  3,587 
Contributions2
Contributions to Coastal GasLink LP1
 3,964  3,231  1,414 
Sur de Texas debt financing3
 —  —  1,199 
Contributions made to other equity investments
 719  918  783 
4,683  4,149  3,396 
1In December 2024, TC Energy made an equity contribution of $3,137 million to Coastal GasLink LP, which used the funds to repay the balance owing to TC Energy under the subordinated loan agreement. The contribution and repayment were included in Investing activities in the Consolidated statement of cash flows. Refer to Note 7, Coastal GasLink, for additional information.
2Included in Investing activities in the Consolidated statement of cash flows.
3Represents TC Energy's proportionate share of the Sur de Texas debt financing requirements and subsequent repayments. Refer to Note 12, Loans receivable from affiliates, for additional information.
TC Energy Consolidated Financial Statements 2024 | 177

Summarized Financial Information of Equity Investments
year ended December 31 2024 2023 2022
(millions of Canadian $)
Income      
Revenues 6,962  6,197  5,681 
Operating and other expenses (3,783) (3,343) (3,290)
Net income 3,026  2,457  2,031 
Net income attributable to TC Energy 1,558  1,310  999 
at December 31 2024 2023
(millions of Canadian $)
Balance Sheet    
Current assets 3,959  3,279 
Non-current assets 44,835  41,270 
Current liabilities (2,111) (2,403)
Non-current liabilities (21,729) (21,894)
At December 31, 2024, the cumulative carrying value of the Company’s equity investments was $769 million (2023 – $278 million) lower than the cumulative underlying equity in the net assets primarily due to the impairment of the equity investment in Coastal GasLink LP, partially offset by fair value adjustments at the time of acquisition or partial disposition, as well as interest capitalized during construction. Refer to Note 7, Coastal GasLink, for additional information.
12.  LOANS RECEIVABLE FROM AFFILIATES
Related party transactions are conducted in the normal course of business and are measured at the exchange amount, which is the amount of consideration established and agreed to by the related parties.
Coastal GasLink Pipeline Limited Partnership
TC Energy holds a 35 per cent equity interest in Coastal GasLink LP and has been contracted to develop, construct and operate the Coastal GasLink pipeline. The Company has a subordinated loan agreement and a subordinated demand revolving credit facility with Coastal GasLink LP. Refer to Note 7, Coastal GasLink, for additional information.
Sur de Texas
TC Energy holds a 60 per cent equity interest in a joint venture with IEnova to own the Sur de Texas pipeline, for which TC Energy is the operator. In 2017, TC Energy entered into a MXN$21.3 billion unsecured revolving credit facility with the joint venture, which bore interest at a floating rate and was fully repaid upon maturity on March 15, 2022 in the amount of $1.2 billion.
The Company's Consolidated statement of income reflects the related interest income and foreign exchange impact on this loan receivable until its repayment on March 15, 2022, which were fully offset upon consolidation with corresponding amounts included in TC Energy’s proportionate share of Sur de Texas equity earnings as follows:
year ended December 31
 Affected line item in the Consolidated statement of income
(millions of Canadian $) 2024 2023 2022
Interest income1
 —  —  19  Interest income and other
Interest expense2
 —  —  (19)
Income (loss) from equity investments
Foreign exchange losses1
 —  —  (28)
Foreign exchange (gains) losses, net
Foreign exchange gains1
 —  —  28 
Income (loss) from equity investments
1Included in the Corporate segment.
2Included in the Mexico Natural Gas Pipelines segment.
178 | TC Energy Consolidated Financial Statements 2024

On March 15, 2022, as part of refinancing activities with the Sur de Texas joint venture, the peso-denominated inter-affiliate loan discussed above was replaced with a new U.S. dollar-denominated inter-affiliate loan from TC Energy of an equivalent $1.2 billion (US$938 million) with a floating interest rate. On July 29, 2022, the Sur de Texas joint venture entered into an unsecured term loan agreement with third parties, the proceeds of which were used to fully repay the U.S. dollar-denominated inter-affiliate loan with TC Energy.
13.  RATE-REGULATED BUSINESSES
TC Energy's businesses that apply RRA currently include almost all of the Canadian, U.S. and Mexico natural gas pipelines and certain U.S. natural gas storage operations. Rate-regulated businesses account for and report assets and liabilities consistent with the resulting economic impact of the regulators' established rates, provided the rates are designed to recover the costs of providing the regulated service and the competitive environment makes it probable that such rates can be charged and collected. Certain revenues and expenses subject to utility regulation or rate determination that would otherwise be reflected in the statement of income are deferred on the balance sheet and are expected to be recovered from or refunded to customers in future service rates.
Canadian Regulated Operations
The majority of TC Energy's Canadian natural gas pipelines are regulated by the CER under the Canadian Energy Regulator Act. The CER regulates the construction and operation of facilities and the terms and conditions of services, including rates, for the Company's Canadian regulated natural gas transmission systems under federal jurisdiction. The Impact Assessment Agency of Canada continues to assess designated projects.
TC Energy's Canadian natural gas transmission services are supplied under natural gas transportation tariffs that provide for cost recovery, including return of and on capital as approved by the CER. Rates charged for these services are typically set through a process that involves filing an application with the regulator wherein forecasted operating costs, including a return of and on capital, determine the revenue requirement for the upcoming year or multiple years. To the extent actual costs and revenues are more or less than forecasted costs and revenues, the regulator generally allows the difference to be deferred to a future period and recovered or refunded in rates at that time. Differences between actual and forecasted costs that the regulator does not allow to be deferred are included in the determination of net income in the year they occur. The Company's most significant regulated Canadian natural gas pipelines, based on total operated pipe length, are described below.
NGTL System
Prior to December 31, 2024, the NGTL System operated under the 2020-2024 Revenue Requirement Settlement (the 2020-2024 Settlement). The 2020-2024 Settlement included an approved ROE of 10.1 per cent on 40 per cent deemed common equity, provided the NGTL System the opportunity to increase depreciation rates if tolls fell below specified levels and provided an incentive mechanism for certain operating costs where variances from projected amounts are shared with its customers.
In September 2024, the CER approved a new five-year negotiated revenue requirement settlement (the 2025–2029 NGTL Settlement) which commenced on January 1, 2025. The settlement enables an investment framework that supports the approval by the Company's Board of Directors (Board) to allocate approximately $3.3 billion of capital towards progression of a new multi-year growth plan for expansion facilities on the NGTL System. It is comprised of multiple distinct projects with targeted in-service dates between 2027 and 2030 that are subject to final Company and regulatory approvals.
The 2025-2029 NGTL Settlement maintains an ROE of 10.1 per cent on 40 per cent deemed common equity while increasing NGTL System depreciation rates, with an incentive that allows the NGTL System the opportunity to further increase depreciation rates if tolls fall below specified levels or if growth projects are undertaken. The 2025-2029 NGTL Settlement introduces a new incentive mechanism to reduce both physical emissions and emission compliance costs, which builds on the incentive mechanism for certain operating costs where variances from projected amounts and emissions savings are shared with customers. A provision for review exists in the current settlement if tolls exceed a pre-determined level or if final Company approvals of the multi-year growth plan are not obtained.
TC Energy Consolidated Financial Statements 2024 | 179

Canadian Mainline
The Canadian Mainline currently operates under the terms of the 2015-2030 Tolls Application approved in 2014 (the 2014 Decision). In April 2020, the CER approved the six-year unanimous negotiated settlement (the 2021-2026 Mainline Settlement) effective January 1, 2021. Similar to the previous settlement, the 2021-2026 Mainline Settlement maintains a base equity return of 10.1 per cent on 40 per cent deemed common equity and includes an incentive to either achieve cost efficiencies and/or increase revenues on the pipeline with a beneficial sharing mechanism to both customers and TC Energy.
Toll stabilization is achieved using deferral accounts, including the toll-stabilization account and the short-term adjustment accounts (STAA), which capture the surplus or shortfall between system revenues and cost of service each year under the 2021-2026 Mainline Settlement. A portion of the STAA commenced amortization in 2023 and the remainder commenced amortization in 2024, according to the terms outlined in the 2021-2026 Mainline Settlement as predetermined thresholds per the settlement agreement were met. Similar to the STAA, the long-term adjustment account (LTAA) and bridging account were used to capture the surplus or shortfall between the Company's revenues and cost of service during the previous settlement and are amortized over the life of 2021-2026 Settlement and the 2014 Decision respectively.
U.S. Regulated Operations
TC Energy's U.S. regulated natural gas pipelines operate under the provisions of the Natural Gas Act of 1938 (NGA), the Natural Gas Policy Act of 1978 and the Energy Policy Act of 2005, and are subject to the jurisdiction of FERC. The NGA grants FERC authority over the construction, acquisition and operation of pipelines and related facilities, including the regulation of tariffs which incorporates maximum and minimum rates for services and allows U.S. regulated natural gas pipelines to discount or negotiate rates on a non-discriminatory basis. The Company's most significant regulated U.S. natural gas pipelines, based on effective ownership and total operated pipe length, are described below.
Columbia Gas
Columbia Gas' natural gas transportation and storage services are provided under a tariff at rates subject to FERC approval. Columbia Gas operates under a settlement approved by FERC in February 2022 (the 2022 Columbia Gas Settlement). As part of the settlement, there is a moratorium on any further rate changes until April 1, 2025, and Columbia Gas must file for new rates with an effective date no later than April 1, 2026. Additionally, Columbia Gas maintains a FERC-approved modernization program allowing for the cost recovery and return on additional investment up to US$1.2 billion over a four-year period through 2024 to modernize the Columbia Gas system, thereby improving system integrity and enhancing service reliability and flexibility.
In September 2024, Columbia Gas filed a general NGA Section 4 rate case with FERC requesting an increase to Columbia Gas’ maximum transportation rates effective April 1, 2025, subject to refund based on the outcome of the proceeding.
ANR Pipeline
ANR Pipeline operates under rates established through a 2022 FERC-approved rate settlement (the 2022 ANR Settlement). The 2022 ANR Settlement reflects the agreement of ANR Pipeline, its customers and FERC staff to resolve all outstanding issues pertaining to the original rate case filing in January 2022 and was effective August 2022. The 2022 ANR Settlement received FERC approval on April 11, 2023. As part of the settlement, there is a moratorium on any further rate changes until November 1, 2025. ANR must file for new rates with an effective date no later than August 1, 2028. The settlement also included an additional rate step up effective August 2024 related to certain modernization projects. In 2023, previously accrued rate refund liabilities, including interest, were refunded to customers.
Columbia Gulf
Columbia Gulf operates under a settlement approved by FERC in August 2023, effective March 1, 2024 (the 2023 Columbia Gulf Settlement). The 2023 Columbia Gulf Settlement includes a moratorium on further rate changes through February 28, 2027, and Columbia Gulf must file for new rates no later than March 1, 2029.
Great Lakes
Great Lakes operates under a rate settlement approved by FERC on April 26, 2022 (the 2022 Great Lakes Settlement), which maintains Great Lakes’ existing maximum transportation rates through October 31, 2025. The 2022 Great Lakes Settlement contains a moratorium until October 31, 2025. Great Lakes will be required to file for new rates no later than April 30, 2025, with such new rates effective no later than November 1, 2025.
180 | TC Energy Consolidated Financial Statements 2024

Tuscarora
Tuscarora operates under rates established as part of the FERC-approved rate settlement on September 6, 2023 (the 2023 Tuscarora Settlement). The 2023 Tuscarora Settlement provided for phased rate reductions as of February 1, 2023, and additionally as of February 1, 2025. The 2023 Tuscarora Settlement contains a moratorium that expires December 1, 2028. Tuscarora is required to file new rates by December 1, 2028.
Gas Transmission Northwest
On September 29, 2023, Gas Transmission Northwest (GTN) filed a general NGA Section 4 Rate Case with FERC, requesting an increase to GTN's maximum rates to become effective April 1, 2024, and subject to refund. On August 9, 2024, GTN filed a settlement with FERC resolving all issues in the general NGA Section 4 Rate Case. On October 21, 2024, the settlement was approved by FERC.
Mexico Regulated Operations
TC Energy's Mexico natural gas pipelines are regulated by CRE and operate in accordance with CRE-approved tariffs. The rates in effect on TC Energy's Mexico natural gas pipelines provide for cost recovery, including a return of and on invested capital.
TC Energy Consolidated Financial Statements 2024 | 181

Regulatory Assets and Liabilities
at December 31
Remaining
Recovery/
Settlement
Period
(years)
 2024 2023
(millions of Canadian $)
Regulatory Assets
Deferred income taxes1
 n/a 2,593  2,204 
Operating and debt-service regulatory assets2
 1 56  29 
Pensions and other post-retirement benefits1,3
 n/a —  54 
Foreign exchange on long-term debt1,4
1-5
 39  11 
Other n/a 117  108 
  2,805  2,406 
Less: Current portion included in Other current assets (Note 8)
 123  76 
  2,682  2,330 
Regulatory Liabilities    
Pipeline abandonment trust balances5
 n/a 2,686  2,252 
Deferred income taxes – U.S. Tax Reform6
 n/a 1,197  1,137 
Canadian Mainline short-term adjustment and toll-stabilization accounts7,8
 n/a 553  437 
Cost of removal9
 n/a 376  351 
Canadian Mainline bridging amortization account7
 6 322  376 
Deferred income taxes1
 n/a 188  198 
Pensions and other post-retirement benefits3
 n/a 122  6 
Canadian Mainline long-term adjustment account7,10
 2 74  111 
Operating and debt-service regulatory liabilities2
 1 50  23 
ANR post-employment and retirement benefits other than pension11
 n/a 45  42 
Other n/a 43  54 
  5,656  4,987 
Less: Current portion included in Accounts payable and other (Note 17)
 353  284 
  5,303  4,703 
1These regulatory assets and liabilities are underpinned by non-cash transactions or are recovered without an allowance for return as approved by the regulator. Accordingly, these regulatory assets or liabilities are not included in rate base and do not yield a return on investment during the recovery period.
2Operating and debt-service regulatory assets and liabilities represent the accumulation of cost and revenue variances to be included in determination of rates in the following year.
3These balances represent the regulatory offset to pension plan and other post-retirement benefit obligations to the extent the amounts are expected to be collected from or refunded to customers in future rates.
4Foreign exchange on long-term debt of the NGTL System represents the variance resulting from revaluing foreign currency-denominated debt instruments to the current foreign exchange rate from the historical foreign exchange rate at the time of issue. Foreign exchange gains and losses realized when foreign debt matures or is redeemed early are expected to be recovered or refunded through the determination of future tolls.
5This balance represents the amounts collected in tolls from customers and included in the LMCI restricted investments to fund future abandonment of the Company's CER-regulated pipeline facilities.
6The U.S. corporate income tax rate was reduced from 35 per cent to 21 per cent in 2017 as a result of H.R.1, the Tax Cuts and Jobs Act (U.S. Tax Reform). This U.S. regulated operations balance, where applicable, represents established regulatory liabilities driven by 2018 FERC prescribed changes related to U.S. Tax Reform being amortized over varying terms that approximate the expected reversal of the underlying deferred tax liabilities that gave rise to the regulatory liabilities.
7These regulatory accounts are used to capture revenue and cost variances plus toll-stabilization adjustments during the 2015-2030 settlement term.
8Under the terms of the 2021-2026 Mainline Settlement, a portion of the STAA account commenced amortization in 2023 and the remainder commenced amortization in 2024, as predetermined thresholds were met, over the terms outlined per the settlement agreement.
9This balance represents anticipated costs of removal that have been, and continue to be, included in depreciation rates and collected in the service rates of certain rate-regulated operations for future costs to be incurred.
10Under the terms of the 2021-2026 Mainline Settlement, $223 million is amortized over the six-year settlement term.
11This balance represents the amount ANR estimates it would be required to refund to its customers for post-retirement and post-employment benefit amounts collected through its FERC-approved rates that have not been used to pay benefits to its employees. Pursuant to a FERC-approved rate settlement, the $45 million (US$32 million) balance at December 31, 2024 is subject to resolution through future regulatory proceedings and, accordingly, a settlement period cannot be determined at this time.
182 | TC Energy Consolidated Financial Statements 2024

14.  GOODWILL
The Company's Goodwill balance on the Consolidated balance sheet is comprised of the following amounts:
at December 31 2024 2023
(millions) Canadian
dollars
U.S.
dollars
 Canadian dollars
U.S.
dollars
Columbia Pipeline Group, Inc. 10,588  7,351  9,708  7,351 
ANR 2,803  1,946  2,570  1,946 
Great Lakes 176  122  161  122 
North Baja 70  48  63  48 
Tuscarora 33  23  30  23 
  13,670  9,490  12,532  9,490 
Changes in Goodwill were as follows:
(millions of Canadian $) U.S. Natural
Gas Pipelines
Balance at January 1, 2023 12,843 
Foreign exchange rate changes (311)
Balance at December 31, 20231
 12,532 
Foreign exchange rate changes 1,138 
Balance at December 31, 20241
 13,670 
1Represents gross amounts of goodwill as at December 31, 2024 of $15,405 million (2023 – $14,267 million), net of accumulated impairment of $1,735 million (2023 – $1,735 million).
As part of the annual goodwill impairment assessment at December 31, 2024, the Company evaluated qualitative factors impacting the fair value of the underlying reporting units. It was determined that it was more likely than not that the fair value of all reporting units exceeded their carrying amounts, including goodwill.
Columbia
On October 4, 2023, as part of the asset divestiture program announced in 2022, the Company successfully completed the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf. In conjunction with the process leading up to the sale, the Company performed a quantitative goodwill impairment test at June 30, 2023.
The estimated fair value measurements used in the Company's goodwill impairment analysis are classified as Level III of the fair value hierarchy. In the determination of the fair value utilized in the quantitative goodwill impairment test for the Columbia reporting unit, the Company performed a discounted cash flow model analysis using projections of future cash flows and applied a risk-adjusted discount rate and value multiple which involved significant estimates and judgments. It was determined that the fair value of the Columbia reporting unit, inclusive of the Columbia Gas and Columbia Gulf business units, exceeded its carrying value, including goodwill. Although goodwill was not impaired, the estimated fair value in excess of the carrying value was less than 10 per cent. There is a risk that reductions in future cash flow forecasts and adverse changes in other key assumptions could result in a future impairment of a portion of the goodwill balance relating to Columbia.
Great Lakes
In March 2022, an impairment loss of $571 million ($531 million after tax) was recognized for the excess carrying value over the estimated fair value of our Great Lakes reporting unit. There is a risk that reductions in future cash flow forecasts and adverse changes in other key assumptions could result in future impairment of the remaining goodwill balance.
TC Energy Consolidated Financial Statements 2024 | 183

15.  OTHER LONG-TERM ASSETS
at December 31 2024 2023
(millions of Canadian $)
Employee post-retirement benefits (Note 27)
 758  518 
Long-term contract assets (Note 6)
 608  457 
Deferred income tax assets (Note 19)
 428  1,319 
Capital projects in development 164  234 
Fair value of derivative contracts (Note 28)
 122  155 
Other 330  198 
  2,410  2,881 
184 | TC Energy Consolidated Financial Statements 2024

16.  NOTES PAYABLE
 at December 31
 2024 2023
(millions of Canadian $, unless otherwise noted)
Outstanding
Weighted
Average
Interest Rate
per Annum
Outstanding
Weighted
Average
Interest Rate
per Annum
Canada1
 308  4.7  % —  — 
U.S. (2024 – US$55; 2023 – nil)
 79  4.7  % —  — 
  387    —   
1At December 31, 2024, Notes payable consisted of Canadian dollar-denominated notes of nil (2023 – nil) and U.S. dollar-denominated notes of US$214 million (2023 – nil).
At December 31, 2024, Notes payable reflects short-term borrowings in Canada by TCPL and in the U.S. by TransCanada PipeLine USA Ltd. (TCPL USA).
At December 31, 2024, total committed revolving and demand credit facilities were $12.2 billion (2023 – $12.9 billion). When drawn, interest on these lines of credit is charged at negotiated floating rates of Canadian and U.S. banks, and at other negotiated financial bases. These unsecured credit facilities included the following:
at December 31
(billions of Canadian $, unless otherwise noted) 2024 2023
Borrowers Description Matures Total Facilities
Unused Capacity1
 Total Facilities
Committed, syndicated, revolving, extendible, senior unsecured credit facilities2:
TCPL
Supports commercial paper program and for general corporate purposes
December 2029
 3.0 3.0 3.0
TCPL / TCPL USA
Supports commercial paper programs and for general corporate purposes of the borrowers, guaranteed by TCPL
December 2025
 US 1.0 US 0.7 US 2.5
TCPL / TCPL USA
Supports commercial paper programs and for general corporate purposes of the borrowers, guaranteed by TCPL
December 2027
 US 2.5 US 2.5 US 2.5
Columbia Pipelines Holding Company LLC3
Supports commercial paper program and general corporate purposes of the borrower
December 2027
 US 1.5 US 1.5 US 1.0
Demand senior unsecured revolving credit facilities2:
TCPL / TCPL USA Supports the issuance of letters of credit and provides additional liquidity; TCPL USA facility guaranteed by TCPL Demand 2.0 
4
 1.1  2.0
4
1Unused capacity is net of commercial paper outstanding and facility draws.
2Provisions of various trust indentures and credit arrangements with the Company's subsidiaries can restrict their ability to declare and pay dividends or make distributions under certain circumstances. If such restrictions apply, they may, in turn, have an impact on the Company's ability to declare and pay dividends on common and preferred shares. These trust indentures and credit arrangements also require the Company to comply with various affirmative and negative covenants and maintain certain financial ratios. At December 31, 2024, the Company was in compliance with all financial covenants.
3Columbia Pipelines Holding Company LLC (CPHC LLC) is a partially-owned subsidiary of TC Energy with 40 per cent non-controlling interest.
4Or the U.S. dollar equivalent.
For the year ended December 31, 2024, the cost to maintain the above facilities was $18 million (2023 – $16 million; 2022 – $14 million).
TC Energy Consolidated Financial Statements 2024 | 185

17.  ACCOUNTS PAYABLE AND OTHER
at December 31 2024 2023
(millions of Canadian $)
Trade payables 3,699  3,092 
Fair value of derivative contracts (Note 28)
 507  415 
Regulatory liabilities (Note 13)
 353  284 
Income tax liabilities
 143  76 
Operating lease liabilities (Note 10)
 60  57 
Contract liabilities (Note 6)
 30  47 
Other 505  334 
  5,297  4,305 
18.  OTHER LONG-TERM LIABILITIES
at December 31 2024 2023
(millions of Canadian $)
Operating lease obligations (Note 10)
 451  400 
Fair value of derivative contracts (Note 28)
 209  106 
Asset retirement obligations 108  64 
Employee post-retirement benefits (Note 27)
 94  97 
Other 189  324 
  1,051  991 
186 | TC Energy Consolidated Financial Statements 2024

19.  INCOME TAXES
Geographic Components of Income before Income Taxes
year ended December 31 2024 2023 2022
(millions of Canadian $)
Canada 1,219  (344) (2,133)
Foreign 4,687  3,642  2,607 
Income before Income Taxes 5,906  3,298  474 
Provision for Income Taxes
year ended December 31 2024 2023 2022
(millions of Canadian $)
Current      
Canada 102  61  41 
Foreign 393  803  322 
  495  864  363 
Deferred      
Canada 135  8  (459)
Foreign 292  (30) 418 
  427  (22) (41)
Income Tax Expense 922  842  322 
Reconciliation of Income Tax Expense
year ended December 31 2024 2023 2022
(millions of Canadian $)
Income before income taxes 5,906  3,298  474 
Federal and provincial statutory tax rate 23.0  % 23.0  % 23.0  %
Expected income tax expense 1,358  759  109 
Mexico foreign exchange exposure
 (246) 132  9 
Income tax differential related to regulated operations (227) (260) (174)
Income from non-controlling interests and equity investments (224) (56) (54)
Foreign income tax rate differentials 167  (84) (216)
Non-taxable capital (gains) and losses 18  182  173 
Impact of Mexico inflationary adjustments
 7  1  24 
Valuation allowance (release)
 4  182  198 
Settlement of Mexico prior years' income tax assessments —  —  196 
Non-deductible goodwill impairment —  —  91 
Other 65  (14) (34)
Income Tax Expense 922  842  322 




TC Energy Consolidated Financial Statements 2024 | 187

Deferred Income Tax Assets and Liabilities
at December 31 2024 2023
(millions of Canadian $)
Deferred Income Tax Assets    
Tax loss and credit carryforwards 1,987  1,664 
Disallowed interest carryforward
 115  — 
Regulatory and other deferred amounts 612  583 
Unrealized foreign exchange losses on long-term debt 467  206 
Other 143  160 
  3,324  2,613 
Less: Valuation allowance 931  690 
2,393  1,923 
Deferred Income Tax Liabilities    
Difference in accounting and tax bases of plant, property and equipment 6,488  5,599 
Equity investments 1,280  1,043 
Taxes on future revenue requirement 612  496 
Financial instruments 168  168 
Other 301  270 
  8,849  7,576 
Net Deferred Income Tax Liabilities 6,456  5,653 
The above deferred tax amounts have been classified on the Consolidated balance sheet as follows:
at December 31 2024 2023
(millions of Canadian $)
Deferred Income Tax Assets    
Other long-term assets (Note 15)
 428  1,319 
Deferred Income Tax Liabilities    
Deferred income tax liabilities 6,884  6,972 
Net Deferred Income Tax Liabilities 6,456  5,653 
TC Energy recorded an income tax valuation allowance of $931 million and $690 million against the deferred income tax asset balances at December 31, 2024 and 2023, respectively. The increase in the valuation allowance is primarily a result of the foreign exchange movement on unrecognized capital losses. At December 31, 2023, the Company recorded a total of $358 million in valuation allowance as a result of the Coastal GasLink equity investment impairment that resulted in a portion of the impairment having unrealized non-taxable capital losses. These losses have not been recognized as of December 31, 2024. At each reporting date, the Company considers new evidence, both positive and negative, that could affect its view of the future realization of deferred tax assets. At December 31, 2024, the Company determined there was sufficient positive evidence to conclude that it is more likely than not that the net deferred tax assets will be realized.
At December 31, 2024, the Company has recognized the benefit of non-capital loss carryforwards of $6,740 million (2023 – $6,593 million) for federal and provincial purposes in Canada, which expire from 2030 to 2044. The Company has not yet recognized the benefit of capital loss carryforwards of $599 million (2023 – $478 million) for federal and provincial purposes in Canada which have no expiry date. The Company has Ontario corporate minimum tax (CMT) credits of $161 million         (2023 – $140 million), which expire from 2026 to 2044. As of December 31, 2024, the Company has not recognized the benefit of CMT credits of $22 million (2023 – $22 million). As of December 31, 2024, the Company has recognized the benefit of disallowed Canadian interest expense of $480 million (2023 - nil) which may be carried forward indefinitely.
At December 31, 2024, the Company has recognized the benefit of net operating loss carryforwards of US$518 million         (2023 – US$47 million) in Mexico, which expire from 2024 to 2034.
188 | TC Energy Consolidated Financial Statements 2024

Unremitted Earnings of Foreign Investments
Income taxes have not been provided on the unremitted earnings of foreign investments that the Company does not intend to repatriate in the foreseeable future. Deferred income tax liabilities would have increased at December 31, 2024 by approximately $1,728 million (2023 – $1,443 million) if there had been a provision for these taxes.
Income Tax Payments
Income tax payments of $387 million, net of refunds, were made in 2024 (2023 – payments, net of refunds, of $791 million;     2022 – payments, net of refunds, of $394 million).
Reconciliation of Unrecognized Tax Benefit
Below is the reconciliation of the annual changes in the total unrecognized tax benefit:
at December 31 2024 2023 2022
(millions of Canadian $)
Unrecognized tax benefit at beginning of year 85  91  80 
Gross increases – tax positions in prior years 3  9  6 
Gross decreases – tax positions in prior years (2) (1) — 
Gross increases – tax positions in current year 5  16  7 
Gross decrease – tax positions in current year
 (2) —  — 
Settlement (13) —  — 
Lapse of statutes of limitations (4) (30) (2)
Unrecognized Tax Benefit at End of Year 72  85  91 
TC Energy's practice is to recognize interest and penalties related to income tax uncertainties in Income tax expense. Income tax expense for the year ended December 31, 2024 reflects $1 million interest recovery (2023 – $3 million expense; 2022 – $6 million expense). At December 31, 2024, the Company accrued $19 million in interest expense (2023 – $20 million; 2022 – $18 million). The Company incurred no penalties associated with income tax uncertainties related to income tax expense for the years ended December 31, 2024, 2023 and 2022 and no penalties were accrued as at December 31, 2024, 2023 and 2022.
Subject to the results of audit examinations by taxing authorities and other legislative amendments, TC Energy does not anticipate further adjustments to the unrecognized tax benefits during the next 12 months that would have a material impact on its financial statements.
TC Energy and its subsidiaries are subject to either Canadian federal and provincial income tax, U.S. federal, state and local income tax or the relevant income tax in other international jurisdictions. The Company has substantially concluded all Canadian federal and provincial income tax matters for the years through 2016. Substantially all material U.S. federal, state and local income tax matters have been concluded for years through 2016. Substantially all material Mexico income tax matters have been concluded for years through 2018.
Mexico Tax Audit
In 2019, the Mexican tax authority, the Tax Administration Services (SAT), completed an audit of the 2013 tax return of one of the Company’s subsidiaries in Mexico. The audit resulted in a tax assessment that denied the deduction for all interest expense and an assessment of additional tax, penalties and financial charges totaling less than US$1 million. The Company disagreed with this assessment and commenced litigation to challenge it. In January 2022, TC Energy received the tax court’s ruling on the 2013 tax return, which upheld the SAT assessment. From September 2021 to February 2022, the SAT issued assessments for tax years 2014 through 2017 which denied the deduction of all interest expense as well as assessed incremental withholding tax on the interest. These assessments totaled approximately US$490 million in income and withholding taxes, interest, penalties and other financial charges.
During 2022, TC Energy settled with the SAT on all of the above matters for the tax years 2013 through 2021 and recorded $196 million (US$153 million) of income tax expense, inclusive of withholding taxes, interest, penalties and other financial charges for the year ended December 31, 2022.
TC Energy Consolidated Financial Statements 2024 | 189

20.  LONG-TERM DEBT
at December 31
   2024 2023
Maturity Dates
Outstanding
Interest
Rate1
Outstanding
Interest
Rate1
(millions of Canadian $, unless otherwise noted)
TRANSCANADA PIPELINES LIMITED          
Medium Term Notes          
Canadian
2025 to 2052
 13,141  4.7  % 15,466  4.6  %
Senior Unsecured Notes          
U.S. (2024 – US$11,792; 2023 – US$16,167)
 2025 to 2049 16,985  5.5  % 21,349  5.0  %
    30,126    36,815   
NOVA GAS TRANSMISSION LTD.          
Debentures and Notes          
Canadian —  —  100  9.9  %
Medium Term Notes          
Canadian 2025 to 2030 504  7.4  % 504  7.4  %
U.S. (2024 and 2023 – US$33)
 2026 47  7.5  % 43  7.5  %
  551    647   
COLUMBIA PIPELINES OPERATING COMPANY LLC
Senior Unsecured Notes
U.S. (2024 – US$6,500; 2023 – US$6,100)
 2025 to 2063 9,362  6.0  % 8,055  6.1  %
COLUMBIA PIPELINES HOLDING COMPANY LLC
Senior Unsecured Notes
U.S. (2024 – US$1,900; 2023 – US$1,000)
 2026 to 2034 2,737  5.9  % 1,320  6.2  %
ANR PIPELINE COMPANY          
Senior Unsecured Notes          
U.S. (2024 – US$1,047; 2023 – US$1,172)
 2025 to 2037 1,509  3.7  % 1,548  4.1  %
TC PIPELINES, LP
Senior Unsecured Notes
U.S. (2024 and 2023 – US$850)
 2025 to 2027 1,224  4.2  % 1,122  4.2  %
GAS TRANSMISSION NORTHWEST LLC        
Senior Unsecured Notes
U.S. (2024 and 2023 – US$375)
 2030 to 2035 540  4.4  % 495  4.4  %
PORTLAND NATURAL GAS TRANSMISSION SYSTEM2
Senior Unsecured Notes
U.S. (2024 – nil; 2023 – US$250)
 —  —  330  2.8  %
GREAT LAKES GAS TRANSMISSION LIMITED PARTNERSHIP        
Senior Unsecured Notes
 
        
U.S. (2024 – US$104; 2023 – US$125)
 2028 to 2030 150  7.6  % 165  7.6  %
190 | TC Energy Consolidated Financial Statements 2024

at December 31
   2024 2023
Maturity Dates
Outstanding
Interest
Rate1
Outstanding
Interest
Rate1
(millions of Canadian $, unless otherwise noted)
TC ENERGÍA MEXICANA, S. DE R.L. DE C.V.
Senior Unsecured Term Loan
U.S. (2024 – US$1,370; 2023 – US$1,800)
 2028 1,973  7.2  % 2,377  7.7  %
Senior Unsecured Revolving Credit Facility
U.S. (2024 – nil; 2023 – US$185)
 2028 —  —  244  7.7  %
1,973  2,621 
48,172  53,118 
Current portion of long-term debt   (2,955)   (2,938)  
Unamortized debt discount and issue costs (252) (312)
Fair value adjustments3
 11  108 
    44,976    49,976   
1Interest rates are the effective interest rates except for those pertaining to long-term debt issued for the Company's Canadian regulated natural gas operations, in which case the weighted average interest rate is presented as approved by the regulators. The effective interest rate is calculated by discounting the expected future interest payments, adjusted for loan fees, premiums and discounts. Weighted average and effective interest rates are stated as at the respective outstanding dates.
2On August 15, 2024, US$250 million of senior notes outstanding held at PNGTS were assumed by the purchaser as part of the sale of PNGTS. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
3The fair value adjustments include $109 million (2023 – $119 million) related to the acquisition of Columbia Pipeline Group, Inc. These adjustments also include a decrease of $139 million (2023 – $11 million) related to hedged interest rate risk and an increase of $41 million (2023 - nil) related to discontinued hedge interest rate risk. Refer to Note 28, Risk management and financial instruments, for additional information.
Principal Repayments
At December 31, 2024, principal repayments for the next five years on the Company's long-term debt are approximately as follows:
(millions of Canadian $) 2025 2026 2027 2028 2029
Principal repayments on long-term debt 2,955 2,810 3,158 6,083 1,333

TC Energy Consolidated Financial Statements 2024 | 191

Long-Term Debt Issued
The Company issued long-term debt over the three years ended December 31, 2024 as follows:
(millions of Canadian $, unless otherwise noted)
Company
 Issue Date Type Maturity Date Amount Interest Rate
TRANSCANADA PIPELINES LIMITED
August 2024
Term Loan1
 August 2024 US 1,242 Floating
May 2023
Senior Unsecured Term Loan2
 May 2026 US 1,024 Floating
March 2023
Senior Unsecured Notes3
 March 2026 US 850 6.20  %
March 2023
Senior Unsecured Notes3
 March 2026 US 400 Floating
March 2023 Medium Term Notes July 2030 1,250 5.28  %
March 2023
Medium Term Notes3
 March 2026 600 5.42  %
March 2023
Medium Term Notes3
 March 2026 400 Floating
May 2022 Medium Term Notes May 2032 800 5.33  %
May 2022 Medium Term Notes May 2026 400 4.35  %
May 2022 Medium Term Notes May 2052 300 5.92  %
COLUMBIA PIPELINES OPERATING COMPANY LLC
September 2024 Senior Unsecured Notes
October 2054
 US 400 5.70  %
August 2023
 Senior Unsecured Notes November 2033 US 1,500 6.04  %
August 2023
 Senior Unsecured Notes November 2053 US 1,250 6.54  %
August 2023
 Senior Unsecured Notes August 2030 US 750 5.93  %
August 2023
 Senior Unsecured Notes August 2043 US 600 6.50  %
August 2023
 Senior Unsecured Notes August 2063 US 500 6.71  %
COLUMBIA PIPELINES HOLDING COMPANY LLC
September 2024 Senior Unsecured Notes
October 2031
 US 400 5.10  %
January 2024 Senior Unsecured Notes
January 2034
 US 500 5.68  %
August 2023
 Senior Unsecured Notes August 2028 US 700 6.04  %
August 2023
 Senior Unsecured Notes August 2026 US 300 6.06  %
GAS TRANSMISSION NORTHWEST LLC
June 2023 Senior Unsecured Notes June 2030 US 50 4.92  %
TC ENERGÍA MEXICANA, S. DE R.L. DE C.V.
January 2023 Senior Unsecured Term Loan January 2028 US 1,800 Floating
January 2023 Senior Unsecured Revolving Credit Facility January 2028 US 500 Floating
ANR PIPELINE COMPANY
May 2022 Senior Unsecured Notes May 2032 US 300 3.43  %
May 2022 Senior Unsecured Notes May 2034 US 200 3.58  %
May 2022 Senior Unsecured Notes May 2037 US 200 3.73  %
May 2022 Senior Unsecured Notes May 2029 US 100 3.26  %
1In August 2024, TCPL entered into a term loan to facilitate the Spinoff Transaction and, in August 2024, the term loan was fully repaid and retired upon delivery of senior unsecured notes issued by 6297782 LLC. Refer to Note 4, Discontinued operations, for additional information.
2Fully repaid and retired in September 2023.
3In October 2024, callable notes were repaid and retired at par.
192 | TC Energy Consolidated Financial Statements 2024

Long-Term Debt Retired/Repaid
The Company retired/repaid long-term debt over the three years ended December 31, 2024 as follows:
(millions of Canadian $, unless otherwise noted)
Company Retirement/Repayment Date Type Amount Interest Rate
TRANSCANADA PIPELINES LIMITED
October 2024 Senior Unsecured Notes US 1,250  1.00  %
October 2024
Senior Unsecured Notes1
 US 850  6.20  %
October 2024
Senior Unsecured Notes2
 US 739  2.50  %
October 2024
Senior Unsecured Notes2
 US 441  4.88  %
October 2024
Senior Unsecured Notes1
 US 400  Floating
October 2024
Senior Unsecured Notes2
 US 313  4.75  %
October 2024
Senior Unsecured Notes2
 US 201  5.00  %
October 2024
Senior Unsecured Notes2
 US 180  5.10  %
October 2024
Medium Term Notes1
 600  5.42  %
October 2024
Medium Term Notes2
 575  4.18  %
October 2024
Medium Term Notes1
 400  Floating
August 2024
Term Loan3
 US 1,242 Floating
June 2024
 Medium Term Notes 750  Floating
October 2023 Senior Unsecured Notes US 625  3.75  %
September 2023
Senior Unsecured Term Loan

US 1,024 Floating
July 2023 Medium Term Notes 750 3.69  %
December 2022 Medium Term Notes 25  9.95  %
August 2022 Senior Unsecured Notes US 1,000 2.50  %
NOVA GAS TRANSMISSION LTD.
March 2024 Debentures 100 9.90  %
April 2023 Debentures US 200 7.88  %
ANR PIPELINE COMPANY
February 2024 Senior Unsecured Notes US 125 7.38  %
TC ENERGÍA MEXICANA, S. DE R.L. DE C.V.
Various 2024
Senior Unsecured Term Loan
 US 430 Floating
Various 2024 Senior Unsecured Revolving Credit Facility US 185 Floating
Various 2023 Senior Unsecured Revolving Credit Facility US 315 Floating
TUSCARORA GAS TRANSMISSION COMPANY
November 2023 Unsecured Term Loan US 32 Floating
1In October 2024, callable notes were retired at par.
2In October 2024, TCPL purchased and cancelled notes at a 7.73 per cent weighted average discount, as a settlement of cash tender offers.
3In August 2024, TCPL entered into a term loan to facilitate the Spinoff Transaction and, in August 2024, the term loan was fully repaid and retired upon delivery of senior unsecured notes issued by 6297782 LLC. Refer to Note 4, Discontinued operations, for additional information.
In October 2024, TCPL commenced and completed its cash tender offers to purchase and cancel certain senior unsecured notes and medium term notes at a 7.73 per cent weighted average discount. In addition, the Company repaid and retired outstanding callable notes at par. These extinguishments of debt resulted in a pre-tax net gain of $228 million, primarily due to the fair value discount and recognition of unamortized debt issue costs related to these notes. The net gain on debt extinguishment was recorded in Interest expense in the Consolidated statement of income.
TC Energy Consolidated Financial Statements 2024 | 193

Interest Expense
year ended December 31 2024 2023 2022
(millions of Canadian $)
Interest on long-term debt 2,800  2,562  1,883 
Interest on junior subordinated notes 638  617  543 
Interest on short-term debt 60  165  153 
Capitalized interest (191) (187) (27)
Amortization and other financial charges1
 158  106  36 
Gain on debt extinguishment
 (228) —  — 
3,237  3,263  2,588 
Interest allocated to discontinued operations (Note 4)
 (218) (297) (288)
  3,019  2,966  2,300 
1Amortization and other financial charges include amortization of transaction costs and debt discounts calculated using the effective interest method and losses on derivatives used to manage the Company's exposure to changes in interest rates.
The Company made interest payments of $3,398 million in 2024 (2023 – $2,931 million; 2022 – $2,478 million) on long-term debt, junior subordinated notes and short-term debt, net of interest capitalized.
194 | TC Energy Consolidated Financial Statements 2024

21.  JUNIOR SUBORDINATED NOTES
at December 31
   2024 2023
Maturity
Date
Outstanding
Effective
Interest Rate1
Outstanding
Effective
Interest Rate1
(millions of Canadian $, unless otherwise noted)
TRANSCANADA PIPELINES LIMITED          
US$1,000 issued 2007 at 6.35%2
 2067 1,440  6.2  % 1,320  6.5  %
US$750 issued 2015 at 5.88%3,4
 2075 1,080  7.5  % 990  7.8  %
US$1,200 issued 2016 at 6.13%3,4
 2076 1,729  8.0  % 1,585  8.3  %
US$1,500 issued 2017 at 5.55%3,4
 2077 2,161  7.2  % 1,981  7.5  %
$1,500 issued 2017 at 4.90%3,4
 2077 1,500  6.8  % 1,500  7.0  %
US$1,100 issued 2019 at 5.75%3,4
 2079 1,584  7.7  % 1,453  8.0  %
$500 issued 2021 at 4.45%3,5
 2081 500  5.7  % 500  5.7  %
US$800 issued 2022 at 5.85%3,5
 2082 1,152  7.3  % 1,056  7.1  %
11,146  10,385 
Unamortized debt discount and issue costs (98) (98)
11,048  10,287 
1The effective interest rate is calculated by discounting the expected future interest payments using the coupon rate and any estimated future rate resets, adjusted for issue costs and discounts.
2Junior subordinated notes of US$1.0 billion were issued in 2007 at a fixed rate of 6.35 per cent and converted in 2017 to bear interest at a floating rate.
3The Junior subordinated notes were issued to TransCanada Trust (the Trust), a financing trust subsidiary wholly-owned by TCPL. While the obligations of the Trust are fully and unconditionally guaranteed by TCPL on a subordinated basis, the Trust is not consolidated in TC Energy's financial statements since TCPL does not have a variable interest in the Trust and the only substantive assets of the Trust are junior subordinated notes of TCPL.
4The coupon rate is initially a fixed interest rate for the first 10 years and converts to a floating rate thereafter.
5The coupon rate is initially a fixed interest rate for the first 10 years and resets every five years thereafter.
The Junior subordinated notes are subordinated in right of payment to existing and future senior indebtedness or other obligations of TCPL.
In March 2022, TransCanada Trust (the Trust) issued US$800 million of Trust Notes – Series 2022-A to investors with a fixed interest rate of 5.60 per cent per annum for the first 10 years and resetting on the 10th anniversary and every five years thereafter. All of the proceeds of the issuance by the Trust were loaned to TCPL for US$800 million of junior subordinated notes of TCPL at an initial fixed rate of 5.85 per cent per annum, including a 0.25 per cent administration charge. The rate on the junior subordinated notes of TCPL will reset every five years commencing March 2032 until March 2052 to the then Five-Year Treasury Rate, as defined in the document governing the subordinated notes, plus 4.236 per cent per annum; from March 2052 until March 2082, the interest rate will reset every five years to the then Five-Year Treasury Rate plus 4.986 per cent per annum. The junior subordinated notes are callable at TCPL's option at any time from December 7, 2031 to March 7, 2032 and on each interest payment and reset date thereafter at 100 per cent of the principal amount plus accrued and unpaid interest to the date of redemption.
Pursuant to the terms of the notes issued between the Trust and TCPL (the Trust Notes) and related agreements, in certain circumstances: 1) TCPL may issue deferral preferred shares to holders of the Trust Notes in lieu of interest; and 2) TC Energy and TCPL would be prohibited from declaring or paying dividends on or redeeming their outstanding preferred shares (or, if none are outstanding, their respective common shares) until all deferral preferred shares are redeemed by TCPL. The Trust Notes may also be automatically exchanged for preferred shares of TCPL upon certain kinds of bankruptcy and insolvency events. All of these preferred shares would rank equally with any other outstanding first preferred shares of TCPL.
TC Energy Consolidated Financial Statements 2024 | 195

22.  FOREIGN EXCHANGE (GAINS) LOSSES, NET
year ended December 31 2024 2023 2022
(millions of Canadian $)
Derivative instruments held for trading (Note 28)
 418  (401) 151 
Other (271) 81  34 
147  (320) 185 
23.  NON-CONTROLLING INTERESTS
The Company's Net income (loss) attributable to non-controlling interests included in the Consolidated statement of income and Non-controlling interests included on the Consolidated balance sheet were as follows:
(millions of Canadian $)
Non-Controlling Interests
Ownership at 
December 31, 2024
 Income (Loss) Attributable to
Non-Controlling Interests		 Non-Controlling Interests
year ended December 31 at December 31
2024 2023 2022 2024 2023
Columbia Gas and Columbia Gulf 40  % 1 571  143  —  9,844  9,167 
Portland Natural Gas Transmission System nil 1 30  41  37  —  106 
Texas Wind Farms 100  %
1,2
 (29) (38) —  168  182 
TGNH 13.01  % 1 109  —  —  756  — 
681  146  37  10,768  9,455 
1    Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
2    Tax equity investors own 100 per cent of the Class A Membership Interests, to which a percentage of earnings, tax attributes and cash flows are allocated. TC Energy owns 100 per cent of the Class B Membership Interests.
24.  COMMON SHARES
  Number of Shares Amount
(thousands) (millions of Canadian $)
Outstanding at January 1, 2022 980,816  26,716 
Issued under public offering1
 28,400  1,754 
Dividend reinvestment and share purchase plan 5,916  342 
Exercise of options 2,830  183 
Outstanding at December 31, 2022 1,017,962  28,995 
Dividend reinvestment and share purchase plan 19,464  1,003 
Exercise of options 62  4 
Outstanding at December 31, 2023 1,037,488  30,002 
Exercise of options
 1,607  99 
Outstanding at December 31, 2024 1,039,095  30,101 
1Net of underwriting commissions and deferred income taxes.
Common Shares Issued and Outstanding
The Company is authorized to issue an unlimited number of common shares without par value.
Common Shares After Spinoff Transaction
On October 1, 2024, as part of the Spinoff Transaction, TC Energy shareholders received one new TC Energy common share and 0.2 of a South Bow common share in exchange for each TC Energy common share held. Refer to Note 1, Description of TC Energy's business, for additional information.
196 | TC Energy Consolidated Financial Statements 2024

Common Shares Issued Under Public Offering
On August 10, 2022, TC Energy issued 28,400,000 common shares at a price of $63.50 each for total gross proceeds of approximately $1.8 billion.
Dividend Reinvestment and Share Purchase Plan
Under the Company's Dividend Reinvestment and Share Purchase Plan (DRP), eligible holders of common and preferred shares of TC Energy can reinvest their dividends and make optional cash payments to obtain additional TC Energy common shares. From August 31, 2022 to July 31, 2023, common shares were issued from treasury at a discount of two per cent to market prices over a specified period.
For the periods between January 1, 2021 and August 31, 2022, and after July 31, 2023, common shares purchased with reinvested cash dividends under TC Energy's DRP are acquired on the open market at 100 per cent of the weighted average purchase price.
Basic and Diluted Net Income (Loss) per Common Share
Net income (loss) from continuing operations per common share is calculated by dividing Net income (loss) from continuing operations attributable to common shares by the weighted average number of common shares outstanding. Net income (loss) from discontinued operations is calculated by dividing Net income (loss) from discontinued operations by the weighted average number of common shares outstanding. The weighted average number of shares for the diluted earnings per share calculation includes options exercisable under TC Energy's Stock Option Plan and, from August 31, 2022 to July 31, 2023, common shares issuable from treasury under the DRP.
Weighted Average Common Shares Outstanding
at December 31
(millions) 2024 2023 2022
Basic 1,038  1,030  995 
Diluted 1,038  1,030  996 
Stock Options
Number of
Options 		Weighted Average Exercise Prices Weighted Average Remaining Contractual Life
(thousands) (years)
Options outstanding at January 1, 2024
 7,436  $62.36
Options exercised (363) $56.85
Options forfeited/expired (598) $63.70
Options Outstanding at September 30, 2024
 6,475  $62.54 3.5
Options Exercisable at September 30, 2024
 4,975  $63.54 3.0
Options cancelled on October 1, 2024
 (6,475) $62.54
Options issued on October 1, 2024
 5,889  $59.72
Options exercised
 (1,244) $54.49
Options forfeited/expired
 (171) $72.17
Options Outstanding at December 31, 2024
 4,474  $60.69 3.6
Options Exercisable at December 31, 2024
 3,169  $62.50 3.1
On October 1, 2024, as part of the Spinoff Transaction, all outstanding TC Energy stock options were cancelled and an equivalent number of new TC Energy stock options were issued to applicable remaining TC Energy employees and former TC Energy employees (other than those transferred to South Bow pursuant to the Spinoff Transaction) who still held TC Energy stock options. The exercise prices of the new TC Energy stock options were adjusted for the change in value of the TC Energy common shares following the Spinoff Transaction. No other stock options were granted in 2024.
TC Energy Consolidated Financial Statements 2024 | 197

At December 31, 2024, an additional 3,621,343 common shares were reserved for future issuance from treasury under TC Energy's Stock Option Plan. The contractual life of options granted is seven years. Options may be exercised at a price determined at the time the option is awarded and vest equally on the anniversary date in each of the three years following the award. Forfeiture of stock options results from their expiration and, if not previously vested, upon resignation or termination of the option holder's employment. Commencing in 2024, the Company no longer issues stock options to employees or officers.
The Company used a binomial model for determining the fair value of options granted and applied the following weighted average assumptions:
year ended December 31
20241
 2023 2022
Weighted average fair value —  $7.88 $8.24
Expected life (years)2
 —  5.1 5.4
Interest rate —  2.9  % 1.6  %
Volatility3
 —  24  % 22  %
Dividend yield —  6.3  % 5.5  %
1Commencing in 2024, the Company no longer issues stock options to employees or officers.
2Expected life is based on historical exercise activity.
3Volatility is derived based on the average of both the historical and implied volatility of the Company's common shares.
The amount expensed for stock options, with a corresponding increase in Additional paid-in capital, was $6 million in 2024 (2023 – $9 million; 2022 – $10 million). At December 31, 2024, unrecognized compensation costs related to non-vested stock options were less than $1 million. The cost is expected to be fully recognized over a weighted average period of 0.7 years.
The following table summarizes additional stock option information:
year ended December 31 2024 2023 2022
(millions of Canadian $, unless otherwise noted)
Total intrinsic value of options exercised 17  —  33 
Total fair value of options that have vested 99  76  89 
Total options vested 1.5 million 1.5 million 1.6 million
As at December 31, 2024, the aggregate intrinsic values of the total options exercisable and the total options outstanding were $20 million and $34 million, respectively.
Shareholder Rights Plan
TC Energy's Shareholder Rights Plan is designed to provide the Board of Directors with sufficient time to explore and develop alternatives for maximizing shareholder value in the event of a takeover offer for the Company and to encourage the fair treatment of shareholders in connection with any such offer. Attached to each common share is one right that, under certain circumstances, entitles certain holders to purchase an additional common share of the Company.
198 | TC Energy Consolidated Financial Statements 2024

25.  PREFERRED SHARES
at
December 31, 2024
Number of
Shares
Outstanding
 Current Yield
Annual Dividend Per Share1,2
 Redemption Price Per Share Redemption and Conversion Option Date Right to Convert Into
Carrying Value
December 313
2024 2023 2022
(thousands) (millions of Canadian $)
Cumulative First Preferred Shares
Series 1 18,424  4.94  %
4
 $1.23475  $25.00  December 31, 2029 Series 2 456  360  360 
Series 2 3,576  Floating
5
 Floating $25.00  December 31, 2029 Series 1 83  179  179 
Series 3 9,997  1.69  % $0.4235  $25.00  June 30, 2025 Series 4 246  246  246 
Series 4 4,003  Floating
5
 Floating $25.00  June 30, 2025 Series 3 97  97  97 
Series 5 12,071  1.95  % $0.48725  $25.00  January 30, 2026 Series 6 294  294  294 
Series 6 1,929  Floating
5
 Floating $25.00  January 30, 2026 Series 5 48  48  48 
Series 7 24,000  5.99  %
4
 $1.49625  $25.00  April 30, 2029 Series 8 589  589  589 
Series 9 16,703  5.08  %
4
 $1.27  $25.00  October 30, 2029 Series 10 410  442  442 
Series 10
 1,297  Floating
5
 Floating $25.00  October 30, 2029 Series 9 32  —  — 
Series 11 10,000  3.35  % $0.83775  $25.00  November 28, 2025 Series 12 244  244  244 
2,499  2,499  2,499 
1Each of the even-numbered series of preferred shares, if in existence, will be entitled to receive floating rate cumulative quarterly preferential dividends per share at an annualized rate equal to the 90-day Government of Canada Treasury bill rate (T-bill rate) plus 1.92 per cent (Series 2), 1.28 per cent (Series 4), 1.54 per cent (Series 6), 2.38 per cent (Series 8), 2.35 per cent (Series 10), or 2.96 per cent (Series 12). These rates reset quarterly with the then current T-Bill rate.
2The odd-numbered series of preferred shares, if in existence, will be entitled to receive fixed rate cumulative quarterly preferential dividends, which will reset on the redemption and conversion option date and every fifth year thereafter, at an annualized rate equal to the then Five-Year Government of Canada bond yield plus 1.92 per cent (Series 1), 1.28 per cent (Series 3), 1.54 per cent (Series 5), 2.38 per cent (Series 7), 2.35 per cent (Series 9), or 2.96 per cent (Series 11).
3Net of underwriting commissions and deferred income taxes.
4The fixed rate dividend for Series 1, Series 7 and Series 9 preferred shares increased from 3.48 per cent to 4.94 per cent on December 31, 2024, 3.90 per cent to 5.99 per cent on April 30, 2024 and from 3.76 per cent to 5.08 per cent on October 30, 2024, respectively, and is due to reset on every fifth anniversary thereafter. No Series 7 preferred shares were converted on the April 30, 2024 conversion date.
5The floating quarterly dividend rate for the Series 2 preferred shares is 5.40 per cent for the period starting December 31, 2024 to, but excluding, March 31, 2025. The floating quarterly dividend rate for the Series 4 preferred shares is 4.76 per cent for the period starting December 31, 2024 to, but excluding, March 31, 2025. The floating quarterly dividend rate for the Series 6 preferred shares is 5.52 per cent for the period starting October 30, 2024 to, but excluding, January 30, 2025 The floating quarterly dividend rate for the Series 10 preferred shares is 6.33 per cent for the period starting October 30, 2024 to, but excluding, January 30, 2025. These rates will reset each quarter going forward.
The holders of preferred shares are entitled to receive a fixed cumulative quarterly preferential dividend as and when declared by the Board with the exception of Series 2, Series 4, Series 6 and Series 10 preferred shares. The holders of Series 2, Series 4, Series 6 and Series 10 preferred shares are entitled to receive quarterly floating rate cumulative preferential dividends as and when declared by the Board. The holders will have the right, subject to certain conditions, to convert their first preferred shares of a specified series into first preferred shares of another specified series on the conversion option date and every fifth anniversary thereafter as indicated in the table above.
TC Energy may, at its option, redeem all or a portion of the outstanding preferred shares for the redemption price per share, plus all accrued and unpaid dividends on the applicable redemption option date and on every fifth anniversary thereafter. In addition, Series 2, Series 4, Series 6 and Series 10 preferred shares are redeemable by TC Energy at any time other than on a designated date for $25.50 per share plus all accrued and unpaid dividends on such redemption date.
On December 31, 2024, 42,200 Series 1 preferred shares were converted, on a one-for-one basis, into Series 2 preferred shares and 3,889,020 Series 2 preferred shares were converted, on a one-for-one basis, into Series 1 preferred shares.
On October 30, 2024, 1,297,203 Series 9 preferred shares were converted, on a one-for-one basis, into Series 10 preferred shares.
On May 31, 2022, TC Energy redeemed all 40,000,000 issued and outstanding Series 15 preferred shares at a redemption price of $25.00 per share and paid the final quarterly dividend of $0.30625 per Series 15 preferred share, for the period up to but excluding May 31, 2022. The Company used the proceeds from the March 2022 issuance of US$800 million of junior subordinated notes through the Trust to finance this preferred share redemption.
TC Energy Consolidated Financial Statements 2024 | 199

26.  OTHER COMPREHENSIVE INCOME(LOSS) AND ACCUMULATED OTHER COMPREHENSIVE INCOME(LOSS)
Components of other comprehensive income (loss), including the portion attributable to non-controlling interests and related tax effects, were as follows:
year ended December 31, 2024
Before Tax Amount
Income Tax (Expense) Recovery
Net of Tax Amount
(millions of Canadian $)
Foreign currency translation gains and losses on net investment in foreign operations
 1,582  20  1,602 
Reclassification of foreign currency translation (gains) on net investment on
disposal of foreign operations1
 (25) —  (25)
Change in fair value of net investment hedges (23) 5  (18)
Change in fair value of cash flow hedges 46  (11) 35 
Reclassification to net income of (gains) losses on cash flow hedges
 (20) 4  (16)
Unrealized actuarial gains (losses) on pension and other post-retirement benefit plans
 107  (24) 83 
Reclassification to net income of actuarial (gains) losses on pension and other
post-retirement benefit plans
 (6) —  (6)
Other comprehensive income (loss) on equity investments
 230  (57) 173 
Other Comprehensive Income (Loss)
 1,891  (63) 1,828 
1    Represents the controlling and non-controlling currency translation adjustment gains related to PNGTS. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
year ended December 31, 2023
Before Tax Amount
Income Tax (Expense) Recovery
Net of Tax Amount
(millions of Canadian $)
Foreign currency translation gains and losses on net investment in foreign operations
 (1,148) 7  (1,141)
Change in fair value of net investment hedges 23  (6) 17 
Reclassification to net income of (gains) losses on cash flow hedges
 97  (23) 74 
Unrealized actuarial gains (losses) on pension and other post-retirement benefit plans
 (15) 4  (11)
Other comprehensive income (loss) on equity investments
 (283) 72  (211)
Other Comprehensive Income (Loss)
 (1,326) 54  (1,272)
year ended December 31, 2022
Before Tax Amount
Income Tax (Expense) Recovery
Net of Tax Amount
(millions of Canadian $)
Foreign currency translation gains and losses on net investment in foreign operations
 1,410  84  1,494 
Change in fair value of net investment hedges (48) 12  (36)
Change in fair value of cash flow hedges (58) 19  (39)
Reclassification to net income of (gains) losses on cash flow hedges
 63  (21) 42 
Unrealized actuarial gains (losses) on pension and other post-retirement benefit plans
 81  (18) 63 
Reclassification to net income of actuarial (gains) losses on pension and other post-retirement benefit plans
 9  (3) 6 
Other comprehensive income (loss) on equity investments
 1,156  (289) 867 
Other Comprehensive Income (Loss)
 2,613  (216) 2,397 
200 | TC Energy Consolidated Financial Statements 2024

The changes in AOCI by component, net of tax, are as follows:
(millions of Canadian $)
Currency
Translation
Adjustments
Cash Flow
Hedges
Pension and Other Post-Retirement Benefit Plan Adjustments
Equity Investments
Total
AOCI balance at January 1, 2022 (1,009) (112) (113) (200) (1,434)
Other comprehensive income (loss) before reclassifications1
 1,450  (39) 63  870  2,344 
Amounts reclassified from AOCI —  42  6 (3) 45 
Net current period other comprehensive income (loss)
 1,450  3  69  867  2,389 
AOCI balance at December 31, 2022 441  (109) (44) 667  955 
Other comprehensive income (loss) before reclassifications1
 (231) —  (11) (195) (437)
Amounts reclassified from AOCI —  74  —  (16) 58 
Net current period other comprehensive income (loss) (231) 74  (11) (211) (379)
Impact of non-controlling interest2
 (527) —  —  —  (527)
AOCI balance at December 31, 2023 (317) (35) (55) 456  49 
Other comprehensive income (loss) before reclassifications1
 692  35  83  188  998 
Amounts reclassified from AOCI3,4
 (15) (16) (6) (15) (52)
Net current period other comprehensive income (loss)
 677  19  77  173  946 
Impact of non-controlling interest5
 (21) —  —  —  (21)
Impact of spinoff of Liquids Pipelines business6
 (741) —  —  —  (741)
AOCI balance at December 31, 2024 (402) (16) 22  629  233 
1Other comprehensive income(loss) before reclassifications of currency translation adjustments are net of non-controlling interest gains of $903 million (2023 – losses of $366 million; 2022 – gains of $8 million).
2Represents the AOCI attributable to the 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf upon its sale on October 4, 2023. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
3Gains related to cash flow hedges reported in AOCI and expected to be reclassified to net income in the next 12 months are estimated to be $5 million ($4 million, net of tax) at December 31, 2024. These estimates assume constant commodity prices, interest rates and foreign exchange rates over time; however, the amounts reclassified will vary based on the actual value of these factors at the date of settlement.
4Includes the controlling interest of the AOCI attributable to PNGTS recognized in Net gain (loss) on sale of assets upon the sale of PNGTS on August 15, 2024. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
5Represents the AOCI attributable to CFE's 13.01 per cent non-controlling equity interest in TGNH. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
6Represents the AOCI attributable to the Spinoff Transaction. Refer to Note 4, Discontinued operations, for additional information.
TC Energy Consolidated Financial Statements 2024 | 201

Details about reclassifications out of AOCI into the Consolidated statement of income were as follows:
year ended December 31
Amounts reclassified
from AOCI1
Affected line item in the Consolidated statement of income
2024 2023 2022
(millions of Canadian $)
Cash flow hedges      
Commodities 32  (85) (47) Revenues (Power and Energy Solutions)
Interest rate (12) (12) (16) Interest expense
20  (97) (63) Total before tax
(4) 23  21  Income tax (expense) recovery
  16  (74) (42)
Net of tax
Pension and other post-retirement benefit plan adjustments      
Amortization of actuarial gains (losses) 6  —  (11)
Plant operating costs and other2
Settlement gain (loss)
 —  —  2 
Plant operating costs and other2
6  —  (9) Total before tax
  —  —  3  Income tax (expense) recovery
  6  —  (6) Net of tax
Equity investments
Equity income (loss) 19  22  4 
Income (loss) from equity investments
(4) (6) (1) Income tax (expense) recovery
15  16  3  Net of tax
Currency translation adjustments
Foreign currency translation gains on disposal of foreign operations
 15  —  — 
Net gain (loss) on sale of assets
—  —  —  Income tax (expense) recovery
15  —  —  Net of tax
1Amounts in parentheses indicate expenses to the Consolidated statement of income.
2These AOCI components are included in the computation of net benefit cost. Refer to Note 27, Employee post-retirement benefits, for additional information.
202 | TC Energy Consolidated Financial Statements 2024

27.  EMPLOYEE POST-RETIREMENT BENEFITS
The Company sponsors DB Plans for certain employees. Pension benefits provided under the DB Plans are generally based on years of service and highest average earnings over three to five consecutive years of employment. Effective January 1, 2019, there were certain amendments made to the Canadian DB Plan for new members. Subsequent to that date, benefits provided for new members were based on years of service and highest average earnings over five consecutive years of employment. Upon commencement of retirement, pension benefits in the Canadian DB Plan increase annually by a portion of the increase in the Consumer Price Index for employees hired prior to January 1, 2019. On January 1, 2024 the Canadian DB Plans were closed to new entrants. In 2023, TC Energy announced a plan amendment to the Canadian OPEB Plan. This plan will be closed for any eligible active employees that did not retire by December 31, 2024. All active employees who no longer meet the eligibility for the OPEB Plan will be eligible for a new plan that provides an annual health spending account to retirees and their dependents from retirement to age 65.
The Company's U.S. DB Plan is closed to non-union new entrants and all non-union hires participate in the DC Plan. Net actuarial gains or losses are amortized out of AOCI over the EARSL of Plan participants, which was approximately nine years at December 31, 2024 (2023 – nine years; 2022 – nine years).
The Company also provides its employees with DC Plans and savings plans in Canada, DC Plans in Mexico, DC Plans consisting of a 401(k) Plan in the U.S. and post-employment benefits other than pensions, including termination benefits and life insurance and medical benefits beyond those provided by government-sponsored plans. Net actuarial gains or losses for the plans are amortized out of AOCI over the EARSL of employees, which was approximately 12 years at December 31, 2024 (2023 – 12 years and 2022 – 12 years). In 2024, the Company expensed $71 million (2023 – $64 million and 2022 – $64 million) for the savings and DC Plans.
As part of the Spinoff Transaction, certain TC Energy employees became employees of South Bow. Prior to the Spinoff Transaction, these employees in Canada and the U.S. participated in DB Plans, DC Plans and savings plans, as applicable. Effective October 1, 2024, the benefit obligations under the DB Plans in respect of the employees moving from TC Energy to South Bow were transferred to South Bow. An asset transfer application related to the Canadian DB Plan will be prepared in early 2025 outlining the proposed transfer of assets from TC Energy to South Bow. The Canadian DB Plan's assets to be transferred to South Bow are subject to regulatory approval and will be transferred when approval is received. As at December 31, 2024, these assets remain in the TC Energy DB Plan trust and have been reflected as Long-term assets of discontinued operations and a corresponding obligation to South Bow has been reflected as Long-term liabilities of discontinued operations on the Consolidated balance sheet. The assets related to the U.S. DB Plan were fully transferred to South Bow as at December 31, 2024.
Total cash contributions by the Company for employee post-retirement benefits were as follows:
year ended December 31 2024 2023 2022
(millions of Canadian $)
DB Plans —  28  78 
Other post-retirement benefit plans 8  9  8 
Savings and DC Plans 71  64  64 
79  101  150 
Current Canadian pension legislation allows for partial funding of solvency requirements over a number of years through letters of credit in lieu of cash contributions, up to certain limits. Total letters of credit provided to the Canadian DB plan at December 31, 2024 was $111 million (2023 – $244 million; 2022 – $322 million).
The most recent actuarial valuation of the pension plans for funding purposes was as at January 1, 2024 and the next required valuation is at January 1, 2025.
TC Energy Consolidated Financial Statements 2024 | 203

The Company's funded status was comprised of the following:
at December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
(millions of Canadian $) 2024 2023 2024 2023
Change in Benefit Obligation1
        
Benefit obligation – beginning of year 3,356  3,081  285  310 
Service cost 108  93  1  3 
Interest cost 160  158  14  16 
Employee contributions 11  7  2  2 
Benefits paid (194) (185) (24) (44)
Actuarial (gain) loss
 (39) 219  (5) 2 
South Bow - transition of benefit obligation2
 (118) —  (1) — 
Foreign exchange rate changes 58  (17) 16  (4)
Benefit obligation – end of year 3,342  3,356  288  285 
Change in Plan Assets        
Plan assets at fair value – beginning of year 3,697  3,481  358  354 
Actual return on plan assets 485  385  17  24 
Employer contributions3,4
 —  28  (41) 9 
Employee contributions 11  7  2  2 
Benefits paid (194) (185) (25) (23)
South Bow - transition of plan assets2
 (119) —  —  — 
Foreign exchange rate changes 68  (19) 28  (8)
Plan assets at fair value – end of year 3,948  3,697  339  358 
Funded Status – Plan Surplus 606  341  51  73 
1The benefit obligation for the Company’s pension benefit plans represents the projected benefit obligation. The benefit obligation for the Company’s other post-retirement benefit plans represents the accumulated post-retirement benefit obligation.
2Reflects the impact of the Spinoff Transaction of the Liquids Pipelines business on October 1, 2024.
3The Company reduced letters of credit by $133 million in the Canadian DB Plan (2023 – $78 million) for funding purposes.
4OPEB surplus of $49 million was transferred to pay future active employee medical expenses.
Additional pension benefit plan assets were as follows:
at December 31 Pension
Benefit Plans
(millions of Canadian $) 2024 2023
TC Energy plan assets at fair value
 3,948  3,697 
South Bow plan assets held in trust1
 110  — 
Plan assets at fair value – end of year
 4,058  3,697 
1    Related to the transfer of pension assets to South Bow. The final transfer will be adjusted for investment returns and benefit payments from October 1, 2024 to the transfer date. The $110 million is reflected in Long-term assets of discontinued operations.
The actuarial gain realized on the defined benefit plan obligation is primarily attributable to an increase in the weighted average discount rate from 4.75 per cent in 2023 to 4.90 per cent in 2024.
The actuarial gain realized on the OPEB Plan obligation is primarily due to an increase in the weighted average discount rate from 5.10 per cent in 2023 to 5.45 per cent in 2024.
204 | TC Energy Consolidated Financial Statements 2024

The amounts recognized on the Company's Consolidated balance sheet for its DB Plans and other post-retirement benefits plans were as follows:
at December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
(millions of Canadian $) 2024 2023 2024 2023
Other long-term assets (Note 15)
 606  341  152  177 
Accounts payable and other —  —  (7) (7)
Other long-term liabilities (Note 18)
 —  —  (94) (97)
  606  341  51  73 
Included in the above benefit obligation and fair value of plan assets were the following amounts for plans that were not fully funded:
at December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
(millions of Canadian $) 2024 2023 2024 2023
Projected benefit obligation1
 —  —  (101) (104)
Plan assets at fair value —  —  —  — 
Funded Status – Plan Deficit —  —  (101) (104)
1The projected benefit obligation for the pension benefit plans differs from the accumulated benefit obligation in that it includes an assumption with respect to future compensation levels.
The funded status based on the accumulated benefit obligation for all DB Plans was as follows:
at December 31 2024 2023
(millions of Canadian $)
Accumulated benefit obligation (3,097) (3,090)
Plan assets at fair value1
 4,058  3,697 
Funded Status – Plan Surplus 961  607 
1    Includes an estimated $110 million for future transfer to South Bow. The final transfer will be adjusted for investment returns and benefit payments from October 1, 2024, the date of the Spinoff Transaction to the transfer date.
The Company's DB Plans with respect to accumulated benefit obligations and the fair value of plan assets were fully funded as at December 31, 2024 and December 31, 2023.
The Company pension plans' weighted average asset allocations and target allocations by asset category were as follows:
at December 31 Percentage of
Plan Assets		 Target Allocations
2024 2023 2024
Fixed income securities 37  % 41  %
25% to 50%
Equity securities 49  % 44  %
25% to 55%
Other investments 14  % 15  %
10% to 35%
  100  % 100  %  
TC Energy Consolidated Financial Statements 2024 | 205

Fixed income and equity securities include the Company's and its related parties debt and common shares as follows:
at December 31 Percentage of
Plan Assets
(millions of Canadian $) 2024 2023 2024 2023
Fixed income securities 44  7  1.1  % 0.2  %
Equity securities 3  2  0.1  % 0.1  %
Pension plan assets are managed on a going concern basis, subject to legislative restrictions, and are diversified across asset classes to maximize returns at an acceptable level of risk. Asset mix strategies consider plan demographics and may include traditional equity and debt securities as well as alternative assets such as infrastructure, private equity, real estate and derivatives to diversify risk. Derivatives are not used for speculative purposes and may be used to hedge certain liabilities.
All investments are measured at fair value using market prices. Where the fair value cannot be readily determined by reference to generally available price quotations, the fair value is determined by considering the discounted cash flows on a         risk-adjusted basis and by comparison to similar assets which are publicly traded. In Level I, the fair value of assets is determined by reference to quoted prices in active markets for identical assets that the Company has the ability to access at the measurement date. In Level II, the fair value of assets is determined using valuation techniques such as option pricing models and extrapolation using significant inputs which are observable directly or indirectly. In Level III, the fair value of assets is determined using a market approach based on inputs that are unobservable and significant to the overall fair value measurement.
206 | TC Energy Consolidated Financial Statements 2024

The following table presents plan assets for DB Plans and OPEB Plans measured at fair value, which have been categorized into the three categories based on a fair value hierarchy. Refer to Note 28, Risk management and financial instruments, for additional information.
at December 31 Quoted Prices in
Active Markets
(Level I)		 Significant Other Observable Inputs
(Level II)		 Significant Unobservable Inputs
(Level III)		 Total Percentage of
Total Portfolio
(millions of Canadian $) 2024 2023 2024 2023 2024 2023 2024 2023 2024 2023
Asset Category1
Cash and Cash Equivalents 138  68  —  1  —  —  138  69  3  2 
Equity Securities:
Canadian 128  121  —  —  —  —  128  121  3  3 
U.S. 1,234  965  —  —  —  —  1,234  965  28  24 
International 182  167  209  187  —  —  391  354  9  9 
Global —  —  100  74  —  —  100  74  2  2 
Emerging 66  54  150  140  —  —  216  194  5  5 
Fixed Income Securities:
Canadian Bonds:
Federal —  —  55  266  —  —  55  266  1  7 
Provincial —  —  312  314  —  —  312  314  7  8 
Municipal —  —  14  16  —  —  14  16  —  — 
Corporate —  —  323  143  —  —  323  143  7  4 
U.S. Bonds:
Federal 151  185  255  240  —  —  406  425  9  10 
Municipal —  —  1  1  —  —  1  1  —  — 
Corporate 246  312  158  74  —  —  404  386  9  10 
International:
Government 4  4  17  11  —  —  21  15  1  — 
Corporate —  —  66  83  —  —  66  83  2  2 
Mortgage backed 37  43  23  17  —  —  60  60  1  1 
Net forward contracts —  —  (201) (131) —  —  (201) (131) (4) (4)
Other Investments:
Real estate —  —  —  —  276  283  276  283  6  7 
Infrastructure —  —  —  —  282  269  282  269  7  7 
Private equity funds —  —  —  —  32  10  32  10  1  — 
Funds held on deposit 138  138  —  —  —  —  138  138  3  3 
Derivatives
 —  —  1  —  —  —  1  —  —  — 
  2,324  2,057  1,483  1,436  590  562  4,397  4,055  100  100 
1    Includes an estimated $110 million for future transfer to South Bow. The final transfer will be adjusted for investment returns and benefit payments from October 1, 2024, the date of the Spinoff Transaction to the transfer date.
TC Energy Consolidated Financial Statements 2024 | 207

The following table presents the net change in the Level III fair value category:
(millions of Canadian $, pre-tax)
Balance at December 31, 2022 632 
Purchases and sales (76)
Realized and unrealized gains (losses)
 6 
Balance at December 31, 2023 562 
Purchases and sales (15)
Realized and unrealized gains (losses)
 43 
Balance at December 31, 2024 590 
In 2025, the Company's expects to make funding contributions of $6 million for the other post-retirement benefit plans, approximately $71 million for the savings plans and DC Plans and no contributions for the DB Plans. The Company is not expecting to issue any additional letters of credit for the funding of solvency requirements to the Canadian DB plan in 2025.
The following are estimated future benefit payments, which reflect expected future service:
at December 31 Other Post-Retirement Benefits
(millions of Canadian $) Pension Benefits
2025 209  24 
2026 212  24 
2027 216  24 
2028 218  24 
2029 221  23 
2030 to 2034 1,139  110 
The rate used to discount pension and other post-retirement benefit plan obligations was developed based on a yield curve of primarily corporate AA bond yields at December 31, 2024. This yield curve is used to develop spot rates that vary based on the duration of the obligations. The estimated future cash flows for the pension and other post-retirement benefit obligations were matched to the corresponding rates on the spot rate curve to derive a weighted average discount rate.
The significant weighted average actuarial assumptions adopted in measuring the Company's benefit obligations were as follows:
at December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
2024 2023 2024 2023
Discount rate 4.90  % 4.75  % 5.45  % 5.10  %
Rate of compensation increase 3.05  % 3.20  % —  — 
The significant weighted average actuarial assumptions adopted in measuring the Company's net benefit plan costs were as follows:
year ended December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
2024 2023 2022 2024 2023 2022
Discount rate 4.75  % 5.15  % 3.05  % 5.15  % 5.45  % 3.10  %
Expected long-term rate of return on plan assets 6.60  % 6.45  % 6.10  % 4.50  % 4.50  % 3.25  %
Rate of compensation increase 3.15  % 3.25  % 3.00  % —  —  — 
208 | TC Energy Consolidated Financial Statements 2024

The overall expected long-term rate of return on plan assets is based on historical and projected rates of return for the portfolio in aggregate and for each asset class in the portfolio. Assumed projected rates of return are selected after analyzing historical experience and estimating future levels and volatility of returns. Asset class benchmark returns and asset mix are also considered in determining the overall expected rate of return. The discount rate is based on market interest rates of high-quality bonds that match the timing and benefits expected to be paid under each plan.
A 6.15 per cent weighted-average annual rate of increase in the per capita cost of covered health care benefits was assumed for 2025 measurement purposes. The rate was assumed to decrease gradually to 4.85 per cent by 2032 and remain at this level thereafter.
The net benefit cost recognized for the Company’s pension benefit plans and other post-retirement benefit plans was as follows:
year ended December 31 Pension
Benefit Plans		 Other Post-Retirement
Benefit Plans
(millions of Canadian $) 2024 2023 2022 2024 2023 2022
Service cost1
 108  93  145  1  3  5 
Other components of net benefit cost1
Interest cost 160  158  125  14  16  13 
Expected return on plan assets (248) (234) (239) (14) (16) (14)
Amortization of actuarial loss —  —  10  —  —  1 
Amortization of regulatory asset —  —  12  (2) —  1 
Settlement gain – AOCI —  —  (2) —  —  — 
(88) (76) (94) (2) —  1 
Net Benefit Cost Recognized 20  17  51  (1) 3  6 
1    Service cost and other components of net benefit cost are included in Plant operating costs and other in the Consolidated statement of income.
Pre-tax amounts recognized in AOCI were as follows:
at December 31 2024 2023 2022
Pension
Benefits		 Other Post-
Retirement
Benefits		 Pension
Benefits		 Other Post-
Retirement
Benefits		 Pension
Benefits		 Other Post-
Retirement
Benefits
(millions of Canadian $)
Net loss (gain)
 (24) —  71  6  38  24 
Pre-tax amounts recognized in OCI were as follows:
year ended December 31 2024 2023 2022
Pension
Benefits		 Other Post-
Retirement
Benefits		 Pension
Benefits		 Other Post-
Retirement
Benefits		 Pension
Benefits		 Other Post-
Retirement
Benefits
(millions of Canadian $)
Amortization of net gain (loss) from AOCI to net income 6  —  —  —  (10) (1)
Settlement —  —  —  —  2  — 
Funded status adjustment (101) (6) 33  (18) (101) 20 
  (95) (6) 33  (18) (109) 19 
In 2022, a settlement occurred for the U.S. DB Plan as a result of lump sum payments made during the year. The impact of the settlement was determined using actuarial assumptions consistent with those employed at December 31, 2022. The settlement gain decreased the U.S. DB Plan's unrealized actuarial gain by $2 million which was included in OCI, and was recorded in net benefit cost in 2022.

TC Energy Consolidated Financial Statements 2024 | 209

28.  RISK MANAGEMENT AND FINANCIAL INSTRUMENTS
Risk Management Overview
TC Energy has exposure to various financial risks and has strategies, policies and limits in place to manage the impact of these risks on its earnings, cash flows and, ultimately, shareholder value.
Risk management strategies, policies and limits are designed to ensure TC Energy's risks and related exposures are in line with the Company's business objectives and risk tolerance. TC Energy's risks are managed within limits that are established by the Company's Board, implemented by senior management and monitored by the Company's risk management, internal audit and business segment groups. The Board's Audit Committee oversees how management monitors compliance with risk management policies and procedures and oversees management's review of the adequacy of the risk management framework.
Market Risk
The Company constructs and invests in energy infrastructure projects, purchases and sells commodities, issues short- and long‑term debt, including amounts in foreign currencies and invests in foreign operations. Certain of these activities expose the Company to market risk from changes in commodity prices, foreign exchange rates and interest rates, which may affect the Company's earnings, cash flows and the value of its financial assets and liabilities. The Company assesses contracts used to manage market risk to determine whether all, or a portion, meets the definition of a derivative.
Derivative contracts the Company uses to assist in managing exposure to market risk may include the following:
•forwards and futures contracts – agreements to purchase or sell a specific financial instrument or commodity at a specified price and date in the future
•swaps – agreements between two parties to exchange streams of payments over time according to specified terms
•options – agreements that convey the right, but not the obligation of the purchaser to buy or sell a specific amount of a financial instrument or commodity at a fixed price, either at a fixed date or at any time within a specified period.
Commodity price risk
The following strategies may be used to manage the Company's exposure to market risk resulting from commodity price risk management activities in the Company's non-regulated businesses:
•in the Company's natural gas marketing business, TC Energy enters into natural gas transportation and storage contracts as well as natural gas purchase and sale agreements. The Company manages exposure on these contracts using financial instruments and hedging activities to offset market price volatility
•in the Company's power businesses, TC Energy manages the exposure to fluctuating commodity prices through long-term contracts and hedging activities including selling and purchasing electricity and natural gas in forward markets
•in the Company's non-regulated natural gas storage business, TC Energy's exposure to seasonal natural gas price spreads is managed with a portfolio of third-party storage capacity contracts and through offsetting purchases and sales of natural gas in forward markets to lock in future positive margins.
Lower natural gas and electricity prices could lead to reduced investment in the development, expansion and production of these commodities. A reduction in the demand for these commodities could negatively impact opportunities to expand the Company's asset base and/or re-contract with TC Energy's shippers and customers as contractual agreements expire.
Physical and transition risks
The physical and transition risks related to climate change could impact commodity prices and fossil fuel supply and demand dynamics which could affect the Company's financial performance. TC Energy evaluates the financial resilience of its asset portfolio against a range of future pricing and supply and demand outcomes as part of its strategic planning process. TC Energy’s exposure to climate change-related transition risks and resulting policy changes is managed through its business model, which is based on a long-term, low-risk strategy whereby the majority of TC Energy’s earnings are underpinned by regulated cost-of-service arrangements and/or long-term contracts. The Company factors physical and transition risks into capital planning, financial risk management and operational activities and is working towards reducing the GHG emissions intensity of existing operations.
210 | TC Energy Consolidated Financial Statements 2024

Interest rate risk
TC Energy utilizes short- and long-term debt to finance its operations which exposes the Company to interest rate risk. TC Energy typically pays fixed rates of interest on its long-term debt and floating rates on short-term debt including its commercial paper programs and amounts drawn on its credit facilities. A small portion of TC Energy's long-term debt bears interest at floating rates. In addition, the Company is exposed to interest rate risk on financial instruments and contractual obligations containing variable interest rate components. The Company actively manages its interest rate risk using interest rate derivatives.
Foreign exchange risk
Certain of TC Energy's businesses generate all or most of their earnings in U.S. dollars and, since the Company reports its financial results in Canadian dollars, changes in the value of the U.S. dollar against the Canadian dollar can affect its net income. This exposure grows as the Company's U.S. dollar-denominated operations grow. A portion of this risk is offset by interest expense on U.S. dollar-denominated debt. The balance of the exposure is actively managed on a rolling basis up to three years in advance using foreign exchange derivatives; however, the natural exposure beyond that period remains.
A portion of the Company's Mexico Natural Gas Pipelines monetary assets and liabilities are peso-denominated, while TC Energy's Mexico operations' financial results are denominated in U.S. dollars. These peso‑denominated balances are revalued to U.S. dollars and, as a result, changes in the value of the Mexican peso against the U.S. dollar can affect the Company's net income. In addition, foreign exchange gains or losses calculated for Mexico income tax purposes on the revaluation of U.S. dollar‑denominated monetary assets and liabilities result in a peso‑denominated income tax exposure for these entities, leading to fluctuations in Income (loss) from equity investments and Income tax expense (recovery). These exposures are actively managed using foreign exchange derivatives, although some unhedged exposure remains.
Net investment in foreign operations
The Company hedges a portion of its net investment in foreign operations (on an after-tax basis) with U.S. dollar‑denominated debt, cross-currency interest rate swaps and foreign exchange options as appropriate.
The fair values and notional amounts for the derivatives designated as a net investment hedge were as follows:
at December 31 2024 2023
Fair
Value1,2
 Notional Amount
Fair
Value1,2
 Notional Amount
(millions of Canadian $, unless otherwise noted)
U.S. dollar cross-currency interest rate swaps (maturing 2025)3
 (11) US 100 2  US 200
U.S. dollar foreign exchange options
 —  —  8  US 1,000
  (11) US 100 10  US 1,200
1Fair value equals carrying value.
2No amounts have been excluded from the assessment of hedge effectiveness.
3In 2024 and 2023, Net income (loss) included net realized gains of less than $1 million related to the interest component of cross-currency swap settlements which are reported within Interest expense.
The notional amounts and fair values of U.S. dollar-denominated debt designated as a net investment hedge were as follows:
at December 31 2024 2023
(millions of Canadian $, unless otherwise noted)
Notional amount
26,000 (US 18,000)
27,800 (US 21,100)
Fair value
25,700 (US 17,800)
26,600 (US 20,200)
TC Energy Consolidated Financial Statements 2024 | 211

Counterparty Credit Risk
TC Energy's exposure to counterparty credit risk includes its cash and cash equivalents, accounts receivable, available-for-sale assets, the fair value of derivative assets, net investment in leases and certain contract assets in Mexico.
At times, the Company's counterparties may endure financial challenges resulting from commodity price and market volatility, economic instability and political or regulatory changes. In addition to actively monitoring these situations, there are a number of factors that reduce TC Energy's counterparty credit risk exposure in the event of default, including:
•contractual rights and remedies together with the utilization of contractually-based financial assurances
•current regulatory frameworks governing certain TC Energy operations
•the competitive position of the Company's assets and the demand for the Company's services
•potential recovery of unpaid amounts through bankruptcy and similar proceedings.
The Company reviews financial assets carried at amortized cost for impairment using the lifetime expected loss of the financial asset at initial recognition and throughout the life of the financial asset. TC Energy uses historical credit loss and recovery data, adjusted for management's judgment regarding current economic and credit conditions, along with reasonable and supportable forecasts to determine any impairment, which is recognized in Plant operating costs and other.
The Company’s net investment in leases and certain contract assets are financial assets subject to ECL. TC Energy’s methodology for assessing the ECL regarding these financial assets includes consideration of the probability of default (the probability that the customer will default on its obligation), the loss given default (the economic loss as a proportion of the financial asset balance in the event of a default) and the exposure at default (the financial asset balance at the time of a hypothetical default) with one‑year forward-looking information that includes assumptions for future macroeconomic conditions under three probability‑weighted future scenarios.
The macroeconomic factors considered most relevant to the Company's net investment in leases and contract assets include Mexico's GDP, Mexico's government debt to GDP and Mexico's inflation. The ECL amount is updated at each reporting date to reflect changes in assumptions and forecasts for future economic conditions.
For the year ended December 31, 2024, the Company recorded a $23 million ECL recovery (2023 – $73 million recovery; 2022 ‑ $149 million expense) with respect to the net investment in leases associated with the in-service TGNH pipelines and $1 million ECL expense (2023 – $10 million recovery; 2022 – $14 million expense) for contract assets related to certain other Mexico natural gas pipelines.
Other than the ECL provision noted above, the Company had no significant credit losses at December 31, 2024 and 2023. At December 31, 2024 and 2023, there were no significant credit risk concentrations and no significant amounts past due or impaired.
TC Energy has significant credit and performance exposure to financial institutions that hold cash deposits and provide committed credit lines and letters of credit that help manage the Company's exposure to counterparties and provide liquidity in commodity, foreign exchange and interest rate derivative markets. TC Energy's portfolio of financial sector exposure consists primarily of highly-rated investment grade, systemically important financial institutions.
Non-Derivative Financial Instruments
Fair value of non-derivative financial instruments
Available-for-sale assets are recorded at fair value which is calculated using quoted market prices where available including the Company's LMCI equity securities which are classified in Level I of the fair value hierarchy. Certain other non-derivative financial instruments included in Cash and cash equivalents, Accounts receivable, Other current assets, Net investment in leases, Restricted investments, Other long-term assets, Notes payable, Accounts payable and other, Dividends payable, Accrued interest and Other long-term liabilities have carrying amounts that approximate their fair value due to the nature of the item or the short time to maturity.
Credit risk has been taken into consideration when calculating the fair value of non-derivative financial instruments.
212 | TC Energy Consolidated Financial Statements 2024

Balance sheet presentation of non-derivative financial instruments
The following table details the fair value of non-derivative financial instruments, excluding those where carrying amounts approximate fair value, and would be classified in Level II of the fair value hierarchy:
at December 31 2024 2023
Carrying
Amount
Fair
Value
 Carrying
Amount		 Fair
Value
(millions of Canadian $)
Long-term debt, including current portion (Note 20)1,2
 (47,931) (48,318) (52,914) (52,815)
Junior subordinated notes (Note 21)
 (11,048) (10,824) (10,287) (9,217)
  (58,979) (59,142) (63,201) (62,032)
1Long-term debt is recorded at amortized cost, except for US$2.8 billion (2023 – US$2.0 billion) that is attributed to hedged risk and recorded at fair value.
2Net income (loss) for 2024 included unrealized gains of $128 million (2023 – unrealized losses of $53 million) for fair value adjustments attributable to the hedged interest rate risk associated with interest rate swap fair value hedging relationships.
Available-for-sale assets summary
The following tables summarize additional information about the Company's restricted investments that were classified as available-for-sale assets:
at December 31 2024 2023
LMCI Restricted Investments
Other Restricted Investments1
 LMCI Restricted Investments
Other Restricted Investments1
(millions of Canadian $)
Fair value of fixed income securities2,3
Maturing within 1 year —  33  —  35 
Maturing within 1-5 years 3  256  8  241 
Maturing within 5-10 years 1,578  —  1,340  — 
Fair value of equity securities2,4
 1,070  64  883  50 
2,651  353  2,231  326 
1Other restricted investments have been set aside to fund insurance claim losses to be paid by the Company's wholly-owned captive insurance subsidiary.
2Available-for-sale assets are recorded at fair value and included in Other current assets and Restricted investments on the Company's Consolidated balance sheet.
3Classified in Level II of the fair value hierarchy.
4Classified in Level I of the fair value hierarchy.
year ended December 31 2024 2023 2022

(millions of Canadian $)
LMCI Restricted Investments1
Other Restricted Investments2
LMCI Restricted Investments1
Other Restricted Investments2
LMCI Restricted Investments1
Other Restricted Investments2
Net unrealized gains (losses)
 218  9  179  13  (223) (7)
Net realized gains (losses)3
 3  2  (28) —  (28) — 
1Unrealized and realized gains (losses) arising from changes in the fair value of LMCI restricted investments impact the subsequent amounts to be collected through tolls to cover future pipeline abandonment costs. As a result, the Company records these gains and losses as regulatory liabilities or regulatory assets.
2Unrealized and realized gains (losses) on other restricted investments are included in Interest income and other in the Company's Consolidated statement of income.
3Realized gains (losses) on the sale of LMCI restricted investments are determined using the average cost basis.
TC Energy Consolidated Financial Statements 2024 | 213

Derivative Instruments
Fair value of derivative instruments
The fair value of foreign exchange and interest rate derivatives has been calculated using the income approach which uses year‑end market rates and applies a discounted cash flow valuation model. The fair value of commodity derivatives has been calculated using quoted market prices where available. In the absence of quoted market prices, third-party broker quotes or other valuation techniques have been used. The fair value of options has been calculated using the Black-Scholes pricing model. Credit risk has been taken into consideration when calculating the fair value of derivative instruments. Unrealized gains and losses on derivative instruments are not necessarily representative of the amounts that will be realized on settlement.
In some cases, even though the derivatives are considered to be effective economic hedges, they do not meet the specific criteria for hedge accounting treatment or are not designated as a hedge and are accounted for at fair value with changes in fair value recorded in net income in the period of change. This may expose the Company to increased variability in reported earnings because the fair value of the derivative instruments can fluctuate significantly from period to period.
The recognition of gains and losses on derivatives for Canadian natural gas regulated pipeline exposures is determined through the regulatory process. Gains and losses arising from changes in the fair value of derivatives accounted for as part of RRA, including those that qualify for hedge accounting treatment, are expected to be refunded or recovered through the tolls charged by the Company. As a result, these gains and losses are deferred as regulatory liabilities or regulatory assets and are refunded to or collected from the rate payers in subsequent years when the derivative settles.
Balance sheet presentation of derivative instruments
The balance sheet classification of the fair value of derivative instruments was as follows:
at December 31, 2024 Cash Flow Hedges Fair Value Hedges Net
 Investment Hedges		 Held for
 Trading
Total Fair
 Value of Derivative Instruments1
(millions of Canadian $)
Other current assets (Note 8)
      
Commodities2
 18  —  —  287  305 
Foreign exchange —  —  —  42  42 
18  —  —  329  347 
Other long-term assets (Note 15)
Commodities2
 9  —  —  104  113 
Foreign exchange —  —  —  9  9 
9  —  —  113  122 
Total Derivative Assets 27  —  —  442  469 
Accounts payable and other (Note 17)
Commodities2
 (1) —  —  (291) (292)
Foreign exchange —  —  (11) (183) (194)
Interest rate —  (21) —  —  (21)
(1) (21) (11) (474) (507)
Other long-term liabilities (Note 18)
Commodities2
 (1) —  —  (46) (47)
Foreign exchange —  —  —  (44) (44)
Interest rate —  (118) —  —  (118)
(1) (118) —  (90) (209)
Total Derivative Liabilities (2) (139) (11) (564) (716)
Total Derivatives 25  (139) (11) (122) (247)
1Fair value equals carrying value.
2Includes purchases and sales of power and natural gas.
214 | TC Energy Consolidated Financial Statements 2024

The balance sheet classification of the fair value of derivative instruments was as follows:
at December 31, 2023 Cash Flow Hedges Fair Value Hedges
Net
 Investment Hedges
Held for
 Trading
Total Fair
Value of Derivative Instruments1
(millions of Canadian $)
Other current assets (Note 8)
      
Commodities2
 9  —  —  499  508 
Foreign exchange —  —  10  71  81 
9  —  10  570  589 
Other long-term assets (Note 15)
Commodities2
 3  —  —  86  89 
Foreign exchange —  —  —  30  30 
Interest rate —  36  —  —  36 
3  36  —  116  155 
Total Derivative Assets 12  36  10  686  744 
Accounts payable and other (Note 17)
Commodities2
 (1) —  —  (382) (383)
Foreign exchange —  —  —  (14) (14)
Interest rate —  (18) —  —  (18)
(1) (18) —  (396) (415)
Other long-term liabilities (Note 18)
Commodities2
 —  —  —  (75) (75)
Foreign exchange —  —  —  (2) (2)
Interest rate —  (29) —  —  (29)
—  (29) —  (77) (106)
Total Derivative Liabilities (1) (47) —  (473) (521)
Total Derivatives 11  (11) 10  213  223 
1Fair value equals carrying value.
2Includes purchases and sales of power and natural gas.
The majority of derivative instruments held for trading have been entered into for risk management purposes and all are subject to the Company's risk management strategies, policies and limits. These include derivatives that have not been designated as hedges or do not qualify for hedge accounting treatment but have been entered into as economic hedges to manage the Company's exposures to market risk.
Derivatives in fair value hedging relationships
The following table details amounts recorded on the Consolidated balance sheet in relation to cumulative adjustments for fair value hedges included in the carrying amount of the hedged liabilities:
at December 31 Carrying Amount
Fair Value Hedging Adjustments1
(millions of Canadian $) 2024 2023 2024 2023
Long-term debt (3,935) (2,630) 98  11 
1At December 31, 2024, adjustments for discontinued hedging relationships included in this balance was a liability of $41 million (2023 – nil).
TC Energy Consolidated Financial Statements 2024 | 215

Notional and maturity summary
The maturity and notional amount or quantity outstanding related to the Company's derivative instruments excluding hedges of the net investment in foreign operations was as follows:
at December 31, 2024 Power Natural Gas Foreign Exchange Interest Rate
Net sales1
 10,192  53  —  — 
Millions of U.S. dollars —  —  5,648  2,800 
Millions of Mexican pesos —  —  16,750  — 
Maturity dates
2025-2044
2025-2031
2025-2027
2030-2034
1Volumes for power and natural gas derivatives are in GWh and Bcf, respectively.
at December 31, 2023 Power Natural Gas Foreign Exchange Interest Rate
Net sales1
 9,209  50  —  — 
Millions of U.S. dollars —  —  4,978  2,000 
Millions of Mexican pesos —  —  20,000 — 
Maturity dates 2024-2044 2024-2029 2024-2026 2030-2034
1Volumes for power and natural gas derivatives are in GWh and Bcf, respectively.
Unrealized and Realized Gains (Losses) on Derivative Instruments
The following summary does not include hedges of the net investment in foreign operations:
year ended December 31 2024 2023 2022
(millions of Canadian $)
Derivative Instruments Held for Trading1
Unrealized gains (losses) in the year
Commodities2
 (71) 132  (11)
Foreign exchange (Note 22)
 (266) 246  (149)
Interest rate
 (71) —  — 
Realized gains (losses) in the year
Commodities 199  192  46 
Foreign exchange (Note 22)
 (152) 155  (2)
Interest rate
 29  —  — 
Derivative Instruments in Hedging Relationships
Realized gains (losses) in the year
Commodities 33  (2) (73)
Interest rate (52) (43) (3)
1Realized and unrealized gains (losses) on held-for-trading derivative instruments used to purchase and sell commodities are included on a net basis in Revenues in the Consolidated statement of income. Realized and unrealized gains (losses) on foreign exchange held-for-trading derivative instruments are included on a net basis in Foreign exchange (gains) losses, net in the Consolidated statement of income. Realized and unrealized gains (losses) on interest rate derivatives are included on a net basis in Interest expense in the Consolidated statement of income.
2In 2024, unrealized gains of $6 million were reclassified to Net Income (loss) from AOCI related to discontinued cash flow hedges (2023 and 2022 – nil).
216 | TC Energy Consolidated Financial Statements 2024

Derivatives in cash flow hedging relationships
The components of OCI (Note 26) related to the change in fair value of derivatives in cash flow hedging relationships before tax and including the portion attributable to non-controlling interests were as follows:
year ended December 31 2024 2023 2022
(millions of Canadian $, pre-tax)
Gains (losses) in fair value of derivative instruments recognized in OCI1
Commodities 46  —  (94)
Interest rate —  —  36 
46  —  (58)
1No amounts have been excluded from the assessment of hedge effectiveness.
Effect of fair value and cash flow hedging relationships
The following table details amounts presented in the Consolidated statement of income in which the effects of fair value or cash flow hedging relationships were recorded:
year ended December 31 2024 2023 2022
(millions of Canadian $)
Fair Value Hedges
Interest rate contracts1
Hedged items (126) (98) (30)
Derivatives designated as hedging instruments (52) (43) (1)
Cash Flow Hedges
Reclassification of gains (losses) on derivative instruments from AOCI to
    Net income (loss)2,3
Commodities4
 32  (85) (47)
Interest rate1
 (12) (12) (16)
1Presented within Interest expense in the Consolidated statement of income.
2Refer to Note 26, Other comprehensive income (loss) and accumulated other comprehensive income (loss), for the components of OCI related to derivatives in cash flow hedging relationships including the portion attributable to non-controlling interests.
3There are no amounts recognized in earnings that were excluded from effectiveness testing.
4Presented within Revenues (Power and Energy Solutions) in the Consolidated statement of income. In 2024, unrealized gains of $6 million were reclassified to Net Income (loss) from AOCI related to discontinued cash flow hedges (2023 and 2022– nil).
Offsetting of derivative instruments
The Company enters into derivative contracts with the right to offset in the normal course of business as well as in the event of default. TC Energy has no master netting agreements; however, similar contracts are entered into containing rights to offset. The Company has elected to present the fair value of derivative instruments with the right to offset on a gross basis on the Consolidated balance sheet.
TC Energy Consolidated Financial Statements 2024 | 217

The following tables show the impact on the presentation of the fair value of derivative instrument assets and liabilities had the Company elected to present these contracts on a net basis:
at December 31, 2024 Gross Derivative Instruments
Amounts Available for Offset1
 Net Amounts
(millions of Canadian $)
Derivative Instrument Assets
Commodities 418  (290) 128 
Foreign exchange 51  (49) 2 
469  (339) 130 
Derivative Instrument Liabilities
Commodities (339) 290  (49)
Foreign exchange (238) 49  (189)
Interest rate (139) —  (139)
(716) 339  (377)
1Amounts available for offset do not include cash collateral pledged or received.
at December 31, 2023 Gross Derivative Instruments
Amounts Available for Offset1
 Net Amounts
(millions of Canadian $)
Derivative Instrument Assets
Commodities 597  (418) 179 
Foreign exchange 111  (16) 95 
Interest rate 36  (5) 31 
744  (439) 305 
Derivative Instrument Liabilities
Commodities (458) 418  (40)
Foreign exchange (16) 16  — 
Interest rate (47) 5  (42)
(521) 439  (82)
1Amounts available for offset do not include cash collateral pledged or received.
With respect to the derivative instruments presented above, the Company provided cash collateral of $133 million and letters of credit of $59 million at December 31, 2024 (2023 – $57 million and $83 million, respectively) to its counterparties. At December 31, 2024, the Company held less than $1 million in cash collateral and $75 million in letters of credit (2023 – less than $1 million and $12 million, respectively) from counterparties on asset exposures.
Credit-risk-related contingent features of derivative instruments
Derivative contracts entered into to manage market risk often contain financial assurance provisions that allow parties to the contracts to manage credit risk. These provisions may require collateral to be provided if a credit-risk-related contingent event occurs, such as a downgrade in the Company's credit rating to non-investment grade. The Company may also need to provide collateral if the fair value of its derivative financial instruments exceeds pre-defined exposure limits.
Based on contracts in place and market prices at December 31, 2024, the aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a net liability position was $10 million (2023 – $3 million), for which the Company has provided no collateral in the normal course of business. If the credit-risk-related contingent features in these agreements were triggered on December 31, 2024, the Company would have been required to provide collateral equal to the fair value of the related derivative instruments discussed above. Collateral may also need to be provided should the fair value of derivative instruments exceed pre-defined contractual exposure limit thresholds. The Company has sufficient liquidity in the form of cash and undrawn committed revolving credit facilities to meet these contingent obligations should they arise.
218 | TC Energy Consolidated Financial Statements 2024

Fair Value Hierarchy
The Company's financial assets and liabilities recorded at fair value have been categorized into three categories based on a fair value hierarchy.
Levels How Fair Value Has Been Determined
Level I Quoted prices in active markets for identical assets and liabilities that the Company has the ability to access at the measurement date. An active market is a market in which frequency and volume of transactions provides pricing information on an ongoing basis.
Level II
This category includes interest rate and foreign exchange derivative assets and liabilities where fair value is determined using the income approach and commodity derivatives where fair value is determined using the market approach.
Inputs include published exchange rates, interest rates, interest rate swap curves, yield curves and broker quotes from external data service providers.
Level III
This category includes long-dated commodity transactions in certain markets where liquidity is low. The Company uses the most observable inputs available or alternatively long-term broker quotes or negotiated commodity prices that have been contracted for under similar terms in determining an appropriate estimate of these transactions. Where appropriate, these long-dated prices are discounted to reflect the expected pricing from the applicable markets.
There is uncertainty caused by using unobservable market data which may not accurately reflect possible future changes in fair value.
The fair value of the Company's derivative assets and liabilities measured on a recurring basis, including both current and non‑current portions, were categorized as follows:
at December 31, 2024 Quoted Prices in Active Markets
(Level I)
Significant Other Observable Inputs
 (Level II)1
Significant Unobservable Inputs
(Level III)1
 Total
(millions of Canadian $)
Derivative Instrument Assets
Commodities 126  214  78  418 
Foreign exchange —  51  —  51 
Derivative Instrument Liabilities
Commodities (116) (217) (6) (339)
Foreign exchange —  (238) —  (238)
Interest rate —  (139) —  (139)
10  (329) 72  (247)
1There were no transfers from Level II to Level III for the year ended December 31, 2024.
The Company has entered into contracts to sell 50 MW of power commencing in 2025 with terms ranging from 15 to 20 years provided from specified renewable sources in the Province of Alberta. The fair value of these contracts is classified in Level III of the fair value hierarchy and is based on the assumption that the contract volumes will be sourced approximately 80 per cent from wind generation, 10 per cent from solar generation and 10 per cent from the market.
TC Energy Consolidated Financial Statements 2024 | 219

at December 31, 2023
Quoted Prices in Active Markets
(Level I)
Significant Other Observable Inputs
(Level II)1
Significant Unobservable Inputs
(Level III)1
 Total
(millions of Canadian $)
Derivative Instrument Assets
Commodities 387  200  10  597 
Foreign exchange —  111  —  111 
Interest rate —  36  —  36 
Derivative Instrument Liabilities
Commodities (307) (130) (21) (458)
Foreign exchange —  (16) —  (16)
Interest rate —  (47) —  (47)
80  154  (11) 223 
1There were no transfers from Level II to Level III for the year ended December 31, 2023.
The following table presents the net change in fair value of derivative assets and liabilities classified in Level III of the fair value hierarchy:
(millions of Canadian $, pre-tax) 2024 2023
Balance at beginning of year (11) (11)
Net gains (losses) included in Net income (loss)
 54  (2)
Transfers to Level II
 29  2 
Balance at End of Year1
 72  (11)
1Revenues include unrealized gains of $54 million attributed to derivatives in the Level III category that were still held at December 31, 2024 (2023 – unrealized losses of $2 million).
29.  CHANGES IN OPERATING WORKING CAPITAL
year ended December 31
2024¹
2023¹
2022¹
(millions of Canadian $)
(Increase) decrease in Accounts receivable
 (13) (394) (575)
(Increase) decrease in Inventories
 (16) (56) (190)
(Increase) decrease in Other current assets
 (97) 618  118 
Increase (decrease) in Accounts payable and other
 365  (206) (83)
Increase (decrease) in Accrued interest
 (40) 245  91 
(Increase) Decrease in Operating Working Capital 199  207  (639)
1    Includes continuing and discontinued operations.
220 | TC Energy Consolidated Financial Statements 2024

30.  STRATEGIC ALLIANCE, ACQUISITIONS AND DISPOSITIONS
U.S. Natural Gas Pipelines
Portland Natural Gas Transmission System (PNGTS)
In August 2024, the Company and its partner, Northern New England Investment Company, Inc., a subsidiary of Énergir L.P. (Énergir), completed the sale of PNGTS to a third party for a gross purchase price of approximately $1.6 billion     (US$1.1 billion), including the third party's assumption of US$250 million of senior notes outstanding at PNGTS, split pro-rata according to the PNGTS ownership interests (TC Energy – 61.7 per cent, Énergir – 38.3 per cent). The Company's share of the proceeds was $743 million (US$546 million), net of transaction costs. The pre-tax gain attributable to the Company of         $572 million (US$408 million) was included in Net gain (loss) on sale of assets in the Consolidated statement of income, and the after-tax gain attributable to the Company was $456 million (US$323 million). The gain includes foreign currency translation gains of $15 million which were reclassified from AOCI to Net income (loss). TC Energy is providing customary transition services and will continue to work jointly with the purchaser to facilitate a safe and orderly transition.
Columbia Gas and Columbia Gulf
In October 2023, TC Energy completed the sale of a 40 per cent non-controlling equity interest in Columbia Gas and Columbia Gulf to Global Infrastructure Partners (GIP) for proceeds of $5.3 billion (US$3.9 billion). The Company continues to have a controlling interest in these companies and will remain the operator of the pipelines. TC Energy and GIP will each fund their proportionate share of annual maintenance, modernization and sanctioned growth capital expenditures through internally generated cash flows, debt financing within the Columbia entities, or from proportionate contributions from TC Energy and GIP.
The sale was accounted for as an equity transaction of which $9.5 billion (US$6.9 billion) was recorded as non-controlling interests to reflect the 40 per cent change in the Company’s ownership interest in Columbia Gulf and Columbia Gas. The difference between the non-controlling ownership interest recognized and the consideration received was recorded as a reduction to Additional paid-in capital of $3.5 billion (US$3.0 billion), net of tax and transaction costs.
At December 31, 2024, as part of the contingent consideration included in the sale, TC Energy accrued a one-time special distribution to GIP of $33 million (US$23 million), or $24 million (US$17 million) net of tax, in Additional paid-in capital.
Mexico Natural Gas Pipelines
Transportadora de Gas Natural de la Huasteca
In second quarter 2024, in accordance with the terms of the Company's strategic alliance, and in exchange for cash and     non-cash consideration of $561 million (US$411 million), the CFE became a partner in TGNH with a 13.01 per cent equity interest in TGNH. The transaction was accounted for as an equity transaction of which $588 million was recognized as non-controlling interests and $21 million was recognized as AOCI attributable to the CFE’s non-controlling interest. The difference between these amounts and the consideration received was recorded as a reduction to Additional paid-in capital of $27 million.
Power and Energy Solutions
Texas Wind Farms
In the first half of 2023, TC Energy acquired 100 per cent of the Class B Membership Interests in Fluvanna Wind Farm (Fluvanna) and Blue Cloud Wind Farm (Blue Cloud), respectively. Each of these operating assets has a tax equity investor which owns     100 per cent of the Class A Membership Interests, to which a percentage of earnings, tax attributes and cash flows are allocated. The tax equity investors' interests were recorded as non-controlling interests at their aggregate estimated fair value of $222 million (US$167 million).
TC Energy has determined that the use of the Hypothetical Liquidation at Book Value (HLBV) method of allocating earnings between the Company and the tax equity investors is appropriate as the earnings, tax attributes and cash flows from Fluvanna and Blue Cloud are allocated to its Class A and Class B Membership Interest owners on a basis other than ownership percentages. Using the HLBV method, the Company's earnings from the projects is calculated based on how the projects would allocate and distribute cash if the net assets were sold at their carrying amounts on the reporting date under the provisions of the tax equity agreements.
TC Energy Consolidated Financial Statements 2024 | 221

TC Energy determined it has a controlling financial interest in both projects and has consolidated the acquired entities as voting interest entities. The tax equity investors’ interests were recorded as non-controlling interests at their estimated fair values of $106 million (US$80 million) for Fluvanna and $116 million (US$87 million) for Blue Cloud. These transactions are accounted for as asset acquisitions and therefore did not result in the recognition of goodwill.
31.  COMMITMENTS, CONTINGENCIES AND GUARANTEES
Commitments
TC Energy and its affiliates have long-term natural gas transportation and natural gas purchase arrangements as well as other purchase obligations, all of which are transacted at market prices and in the normal course of business. Purchases under these contracts in 2024 were $347 million (2023 – $335 million; 2022 – $314 million).
The Company has entered into PPAs with solar and wind-power generating facilities ranging from 2025 to 2038 that require the purchase of generated energy and associated environmental attributes. At December 31, 2024, the total planned capacity secured under the PPAs is approximately 750 MW with the generation subject to operating availability and capacity factors. These PPAs do not meet the definition of a lease or derivative. Future payments and their timing cannot be reasonably estimated as they are dependent on when certain underlying facilities are placed into service and the amount of energy generated. Certain of these purchase commitments have offsetting sale PPAs for all or a portion of the related output from the facility.
Capital expenditure commitments include obligations related to the construction of growth projects and are based on the projects proceeding as planned. Changes to these projects, including cancellation, would reduce or possibly eliminate these commitments as a result of cost mitigation efforts. At December 31, 2024, TC Energy had approximately $1.1 billion of capital expenditure commitments, primarily consisting of:
•$0.4 billion for its U.S. natural gas pipelines, primarily related to construction costs associated with ANR and other pipeline projects
•$0.3 billion for its Canadian natural gas pipelines related to construction costs associated with the Valhalla North and Berland River projects.
Contingencies
TC Energy is subject to laws and regulations governing environmental quality and pollution control. At December 31, 2024, the Company had accrued approximately $8 million (2023 – $19 million) related to operating facilities, which represents the present value of the estimated future amount it expects to spend to remediate the sites. However, additional liabilities may be incurred as assessments take place and remediation efforts continue.
TC Energy and its subsidiaries are subject to various legal proceedings, arbitrations and actions arising in the normal course of business. The Company assesses all legal matters on an ongoing basis, including those of its equity investments, to determine if they meet the requirements for disclosure or accrual of a contingent loss. With the potential exception of the matters discussed below, it is the opinion of management that the ultimate resolution of such proceedings and actions will not have a material impact on the Company's consolidated financial position or results of operations. The claims discussed below are material and there is a reasonable possibility of loss; however, they have not been assessed as probable and a reasonable estimate of loss cannot be made.

222 | TC Energy Consolidated Financial Statements 2024

Coastal GasLink LP
Coastal GasLink LP is in dispute with a number of contractors related to construction of the Coastal GasLink pipeline. Material legal matters pertaining to Coastal GasLink are summarized as follows:
Pacific Atlantic Pipeline Construction Ltd.
Coastal GasLink LP is in arbitration with one of its previous prime contractors, Pacific Atlantic Pipeline Construction Ltd. (PAPC). Coastal GasLink LP terminated its contract with PAPC for cause, due to the failure of PAPC to complete work as scheduled and made a demand on the parental guarantee for payment of the guaranteed obligations. Following Coastal GasLink LP’s demand on the guarantee, in August 2022, PAPC initiated arbitration. As of December 31, 2024, PAPC purports to seek at least $460 million in damages for wrongful termination for cause, termination damages and payments alleged to be outstanding. Coastal GasLink LP disputes the merits of PAPC’s claims and has counterclaimed against PAPC and its parent company and guarantor, Bonatti S.p.A., citing delays and failures by PAPC to perform and manage work in accordance with the terms of its contract. Coastal GasLink LP estimates its damages to be $1.3 billion. PAPC and Bonatti S.p.A. dispute Coastal GasLink LP's claims and assert that Coastal GasLink LP's damages, if any, are subject to a contractual limit of approximately $220 million. The hearing previously scheduled to commence in November 2024 has now been rescheduled to third quarter 2025. At December 31, 2024, the final outcome of this matter cannot be reasonably estimated.
Separately, Coastal GasLink LP has drawn on a $117 million irrevocable standby letter of credit (LOC) provided by PAPC based on a bona fide belief that Coastal GasLink LP’s damages are in excess of the face value of the LOC. PAPC applied for an injunction restraining Coastal GasLink LP from drawing on the LOC pending the completion of the arbitration between Coastal GasLink LP, PAPC and Bonatti S.p.A., but was unsuccessful. Coastal GasLink LP is now able to use the recovered LOC funds. PAPC and Bonatti S.p.A. have amended their original claims to seek additional damages in relation to the draw on the LOC. The amount claimed has not been articulated beyond the $117 million. The parties have agreed that the issue of damages arising from Coastal GasLink LP's draw on the LOC will be determined, if necessary, at a date subsequent to the arbitration hearing noted above.
Macro Spiecapag Coastal GasLink Joint Venture
Coastal GasLink LP is in arbitration with its former prime contractor, Macro Spiecapag Coastal GasLink Joint Venture (MSJV). In May 2021, Coastal GasLink LP terminated a portion of the work under its contract with MSJV. MSJV continued as prime contractor for the remaining portion of the work; however, it did not complete the remaining work as scheduled. Coastal GasLink LP claims damages in the approximate amount of $560 million for delay, owner indirect costs, contractor replacement costs and repayment of payments made on a without prejudice basis. MSJV has counterclaimed against Coastal GasLink LP for damages for wrongful termination and outstanding costs in the approximate amount of $480 million. An arbitration schedule is expected to be established in second quarter 2025. At December 31, 2024, the final outcome of this matter cannot be reasonably estimated.
2016 Columbia Pipeline Acquisition Lawsuit
In 2023, the Delaware Chancery Court (the Court) issued its decision in the class action lawsuit commenced by former shareholders of Columbia Pipeline Group Inc. (CPG) related to the acquisition of CPG by TC Energy in 2016. The Court found that the former CPG executives breached their fiduciary duties, that the former CPG Board breached its duty of care in overseeing the sale process and that TC Energy aided and abetted those breaches.
On May 15, 2024, the Court allocated responsibility for the total sale process damages of US$398 million in the amount of 50 per cent to the former Columbia CEO and CFO, collectively, and 50 per cent to TC Energy. Pursuant to the Final Order and Judgment (Final Judgment), TC Energy’s allocated share of the sale process claim damages is US$199 million, plus US$153 million in interest as of June 14, 2024. The Court also entered judgment related to a disclosure claim for which TC Energy’s allocated share of damages is US$84 million, plus US$64 million in interest as of June 14, 2024. The damages for the two claims are not cumulative and TC Energy would only be required to pay the greater of the sale process damages and disclosure claim damages after final determination of those amounts on appeal, including any additional interest assessed to the date of payment.
TC Energy disagrees with many of the Court’s findings and believes the Court’s ruling departs from established Delaware law. TC Energy has filed a notice of appeal, which is scheduled to be heard by the Delaware Supreme Court on March 12, 2025. A final decision is expected in mid-2025. During the appeal process, in lieu of paying the judgment, TC Energy posted an appeal bond in the amount of US$380 million, which approximates the amount of the Final Judgment plus nine months of post-judgment interest. The Company’s legal assessment is that it is not probable that TC Energy will incur a loss upon completion of the appeal process, and therefore, the Company has not accrued a provision for this claim at December 31, 2024.
TC Energy Consolidated Financial Statements 2024 | 223

Guarantees
TC Energy and its partner on the Sur de Texas pipeline, IEnova, have jointly guaranteed the financial performance of the entity which owns the pipeline. Such agreements include a guarantee and a letter of credit which are primarily related to the delivery of natural gas.
TC Energy and its joint venture partner on Bruce Power, BPC Generation Infrastructure Trust, have each severally guaranteed certain contingent financial obligations of Bruce Power related to a lease agreement and contractor and supplier services.
The Company and its partners in certain other jointly-owned entities have either: i) jointly and severally; ii) jointly or             iii) severally guaranteed the financial performance of these entities. Such agreements include guarantees and letters of credit which are primarily related to delivery of natural gas. For certain of these entities, any payments made by TC Energy under these guarantees in excess of its ownership interest are to be reimbursed by its partners.
The carrying value of these guarantees has been recorded in Other long-term liabilities on the Consolidated balance sheet. Information regarding the Company’s guarantees were as follows:
at December 31 2024 2023
Term
Potential Exposure1
 Carrying Value
Potential Exposure1
 Carrying Value
(millions of Canadian $)
Sur de Texas Renewable to 2053 93  —  97  — 
Bruce Power Renewable to 2065 88  —  88  — 
Other jointly-owned entities
to 2032
 59  1  24  1 
240  1  209  1 
1TC Energy's share of the potential estimated current or contingent exposure.
224 | TC Energy Consolidated Financial Statements 2024

32.  VARIABLE INTEREST ENTITIES
Consolidated VIEs
A significant portion of the Company’s assets are held through VIEs in which the Company holds a 100 per cent voting interest, the VIE meets the definition of a business and the VIE’s assets can be used for general corporate purposes. The consolidated VIEs whose assets cannot be used for purposes other than for the settlement of the VIE’s obligations, or are not considered a business, were as follows:
at December 31
(millions of Canadian $)
20241
20232
ASSETS
Current Assets
Cash and cash equivalents 311  188 
Accounts receivable 839  473 
Inventories 205  90 
Other current assets 121  49 
Current assets of discontinued operations
 —  5 
1,476  805 
Plant, Property and Equipment 49,904  27,477 
Equity Investments 865  823 
Restricted Investments
 950  — 
Goodwill 479  439 
Regulatory Assets
 53  12 
Other Long-Term Assets 59  — 
Long-Term Assets of Discontinued Operations
 —  172 
53,786  29,728 
LIABILITIES
Current Liabilities
Accounts payable and other 1,866  1,092 
Accrued interest 202  210 
Current portion of long-term debt 2,062  28 
Current liabilities of discontinued operations
 —  43 
4,130  1,373 
Regulatory Liabilities 1,232  280 
Other Long-Term Liabilities 70  46 
Deferred Income Tax Liabilities 7  22 
Long-Term Debt 12,387  11,388 
Long-Term Liabilities of Discontinued Operations
 —  10 
17,826  13,119 
1On April 1, 2024, the NGTL System was classified as a VIE when its ownership was transferred from Nova Gas Transmission Ltd. to NGTL GP Ltd. on behalf of NGTL Limited Partnership.
2Columbia Gas and Columbia Gulf were classified as a VIE upon TC Energy's sale of a 40 per cent non-controlling equity interest on October 4, 2023. Refer to Note 30, Strategic alliance, acquisitions and dispositions, for additional information.
TC Energy Consolidated Financial Statements 2024 | 225

Non-Consolidated VIEs
The carrying value of these VIEs and the maximum exposure to loss as a result of the Company's involvement with these VIEs were as follows:
at December 31
(millions of Canadian $) 2024 2023
Balance Sheet Exposure
Equity Investments
Bruce Power 7,043  6,241 
Coastal GasLink
 1,006  294 
Pipeline equity investments and other 160  166 
Long-Term Assets of Discontinued Operations
Pipeline equity investments and other —  951 
Off-Balance Sheet Exposure1
Bruce Power
 1,877  1,538 
Coastal GasLink2
 265  855 
Pipeline equity investments and other 2  2 
Discontinued operations
 —  56 
Maximum exposure to loss
 10,353  10,103 
1Includes maximum potential exposure to guarantees and future funding commitments.
2TC Energy is contractually obligated to fund the capital costs to complete the Coastal GasLink pipeline by funding the remaining equity requirements of Coastal GasLink LP through incremental capacity on the subordinated loan agreement with Coastal GasLink LP until final costs are determined. In December 2024, TC Energy made an equity contribution of $3,137 million to Coastal GasLink LP, which used the funds to repay the $3,147 million balance owing to TC Energy under the subordinated loan agreement. The repayment reduced the Company's funding commitment under the subordinated loan agreement to $228 million. In addition to the subordinated loan agreement, TC Energy has entered into an equity contribution agreement to fund a maximum of $37 million for its proportionate share of the equity requirements related to the Cedar Link project. Refer to Note 7, Coastal GasLink, for additional information.
226 | TC Energy Consolidated Financial Statements 2024
EX-23.1 5 trp-12312024xexx231.htm CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM Document
EXHIBIT 23.1


Consent of Independent Registered Public Accounting Firm
We consent to the use of:
•our report dated February 13, 2025 on the consolidated financial statements of TC Energy Corporation (the “Company”) which comprise the consolidated balance sheets as at December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, cash flows, and equity for each of the years in the three-year period ended December 31, 2024, and the related notes, and
•our report dated February 13, 2025 on the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024
each of which is included in the Annual Report on Form 40-F of the Company for the fiscal year ended December 31, 2024.
We also consent to the incorporation by reference of such reports in the:
•Registration Statements No. 333-5916, No. 333-8470, No. 333-9130, No. 333-151736, No. 333-184074, No. 333-227114 and No. 333-237979 on Form S-8 of TC Energy Corporation;
•Registration Statements No. 33-13564 and No. 333-6132 on Form F-3 of TC Energy Corporation;
•Registration Statements No. 333-250988 and No. 333-252123 on Form F-10 of TC Energy Corporation; and,
•Registration Statements No. 333-267323 and No. 333-283633 on Form F-10 of TransCanada PipeLines Limited.

/s/ KPMG LLP
Chartered Professional Accountants
February 13, 2025
Calgary, Canada
EX-31.1 6 trp-12312024xexx311tcetcpl.htm CEO CERTIFICATE PURSUANT TO SECTION 302 Document
EXHIBIT 31.1


Certifications

I, François L. Poirier, certify that:
1.I have reviewed this annual report on Form 40-F of TC Energy Corporation;
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the issuer as of, and for, the periods presented in this report;
4.The issuer's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the issuer and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the issuer, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)Evaluated the effectiveness of the issuer's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)Disclosed in this report any change in the issuer's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the issuer's internal control over financial reporting; and
5.The issuer's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer's auditors and the audit committee of the issuer's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the issuer's ability to record, process, summarize and report financial information; and
(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the issuer's internal control over financial reporting.

Dated February 14, 2025

/s/ FRANÇOIS L. POIRIER
François L. Poirier
President and Chief Executive Officer
1 of 2



Certifications

I, François L. Poirier, certify that:
1.I have reviewed this annual report on Form 40-F of TransCanada PipeLines Limited;
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the issuer as of, and for, the periods presented in this report;
4.The issuer's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the issuer and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the issuer, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)Evaluated the effectiveness of the issuer's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)Disclosed in this report any change in the issuer's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the issuer's internal control over financial reporting; and
5.The issuer's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer's auditors and the audit committee of the issuer's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the issuer's ability to record, process, summarize and report financial information; and
(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the issuer's internal control over financial reporting.

Dated February 14, 2025

/s/ FRANÇOIS L. POIRIER
François L. Poirier
President and Chief Executive Officer
2 of 2
EX-31.2 7 trp-12312024xexx312tcetcpl.htm CFO CERTIFICATE PURSUANT TO SECTION 302 Document
EXHIBIT 31.2


Certifications

I, Sean P. O'Donnell, certify that:
1.I have reviewed this annual report on Form 40-F of TC Energy Corporation;
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the issuer as of, and for, the periods presented in this report;
4.The issuer's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the issuer and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the issuer, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)Evaluated the effectiveness of the issuer's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)Disclosed in this report any change in the issuer's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the issuer's internal control over financial reporting; and
5.The issuer's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer's auditors and the audit committee of the issuer's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the issuer's ability to record, process, summarize and report financial information; and
(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the issuer's internal control over financial reporting.

Dated February 14, 2025

/s/ SEAN P. O'DONNELL
Sean P. O'Donnell
Executive Vice-President, Strategy and Corporate Development and
Chief Financial Officer
1 of 2



Certifications

I, Sean P. O'Donnell, certify that:
1.I have reviewed this annual report on Form 40-F of TransCanada PipeLines Limited;
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the issuer as of, and for, the periods presented in this report;
4.The issuer's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the issuer and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the issuer, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c)Evaluated the effectiveness of the issuer's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d)Disclosed in this report any change in the issuer's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the issuer's internal control over financial reporting; and
5.The issuer's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer's auditors and the audit committee of the issuer's board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the issuer's ability to record, process, summarize and report financial information; and
(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the issuer's internal control over financial reporting.

Dated February 14, 2025

/s/ SEAN P. O'DONNELL
Sean P. O'Donnell
Executive Vice-President, Strategy and Corporate Development and
Chief Financial Officer
2 of 2
EX-32.1 8 trp-12312024xexx321tcetcpl.htm CEO CERTIFICATE PURSUANT TO SECTION 906 Document
EXHIBIT 32.1


TC ENERGY CORPORATION

450 – 1st Street S.W.
Calgary, Alberta, Canada
T2P 5H1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER
UNDER SECTION 906 OF SARBANES-OXLEY ACT OF 2002

I, François L. Poirier, the Chief Executive Officer of TC Energy Corporation (the "Company"), in compliance with 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify, in connection with the Company's Annual report as filed on Form 40‑F for the fiscal year ended December 31, 2024 with the Securities and Exchange Commission (the "Report"), that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ FRANÇOIS L. POIRIER
François L. Poirier
Chief Executive Officer
February 14, 2025
1 of 2



TRANSCANADA PIPELINES LIMITED

450 – 1st Street S.W.
Calgary, Alberta, Canada
T2P 5H1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER
UNDER SECTION 906 OF SARBANES-OXLEY ACT OF 2002

I, François L. Poirier, the Chief Executive Officer of TransCanada PipeLines Limited (the "Company"), in compliance with 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify, in connection with TC Energy Corporation's Annual report as filed on Form 40-F for the fiscal year ended December 31, 2024 with the Securities and Exchange Commission (the "Report"), that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ FRANÇOIS L. POIRIER
François L. Poirier
Chief Executive Officer
February 14, 2025

2 of 2
EX-32.2 9 trp-12312024xexx322tcetcpl.htm CFO CERTIFICATE PURSUANT TO SECTION 906 Document
EXHIBIT 32.2


TC ENERGY CORPORATION

450 – 1st Street S.W.
Calgary, Alberta, Canada
T2P 5H1

CERTIFICATION OF CHIEF FINANCIAL OFFICER
UNDER SECTION 906 OF SARBANES-OXLEY ACT OF 2002

I, Sean P. O'Donnell, the Chief Financial Officer of TC Energy Corporation (the "Company"), in compliance with 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify, in connection with the Company's Annual report as filed on Form 40-F for the fiscal year ended December 31, 2024 with the Securities and Exchange Commission (the "Report"), that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ SEAN P. O'DONNELL
Sean P. O'Donnell
Chief Financial Officer
February 14, 2025

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TRANSCANADA PIPELINES LIMITED

450 – 1st Street S.W.
Calgary, Alberta, Canada
T2P 5H1

CERTIFICATION OF CHIEF FINANCIAL OFFICER
UNDER SECTION 906 OF SARBANES-OXLEY ACT OF 2002

I, Sean P. O'Donnell, the Chief Financial Officer of TransCanada PipeLines Limited (the "Company"), in compliance with 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify, in connection with TC Energy Corporation's Annual report as filed on Form 40-F for the fiscal year ended December 31, 2024 with the Securities and Exchange Commission (the "Report"), that:
1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ SEAN P. O'DONNELL
Sean P. O'Donnell
Chief Financial Officer
February 14, 2025

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EX-97.1 10 exhibit_971xtcex2023xhol.htm INCENTIVE COMPENSATION RECOUPMENT AND HOLDBACK POLICY exhibit_971xtcex2023xhol
UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 1 Policy. EXHIBIT 97.1 Incentive compensation recoupment and holdback policy. Purpose and scope The purpose of this Policy is to provide direction for the process of recouping Erroneously Awarded Compensation in order to satisfy the requirements of the NYSE Listing Standards and Rule 10D-1 as adopted by the U.S. SEC to implement Section 954 of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010. This Policy will operate in addition to any legal requirements that may apply to the Company and its Employees, officers and directors. This Policy is in addition to any other action or remedy available to the Company against such individuals under applicable law, policy or contract, up to and including termination of employment and/or legal action for breach of fiduciary duty or fraud. This Policy applies to all Covered Executives of TC Energy Corporation and their beneficiaries, heirs, executors, administrators or other legal representatives. Policy 1 Recoupment event 1.1 If TC Energy Corporation is required to prepare a Restatement, then, as determined by the Human Resources Committee, the Covered Executive’s Incentive-Based Compensation will be subject to forfeiture, recovery and recoupment, subject to the following: a) This Policy applies to Incentive-Based Compensation received by a Covered Executive: (i) on or after October 2, 2023, (ii) after beginning services as a Covered Executive, and any subsequent changes in a Covered Executive’s employment status, including retirement or termination of employment, do not affect the Company’s rights to recoup Erroneously Awarded Compensation pursuant to this Policy, and (iii) if the Covered Executive served as a Covered Executive at any time during the performance period for such Incentive-Based Compensation. b) The amount to be forfeited or recouped will equal the Erroneously Awarded Compensation. The Human Resources Committee will take actions necessary to recoup the Erroneously Awarded Compensation reasonably promptly following a Restatement. Where the amount of Erroneously Awarded Compensation is not subject to

 
Incentive compensation recoupment and holdback policy. UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 2 mathematical recalculation directly from the information in the Restatement, the amount must be based on a reasonable estimate of the effect of the Restatement on stock price or total shareholder return upon which the Incentive-Based Compensation was received. The Company will maintain documentation of the determination of that reasonable estimate and provide such documentation to the New York Stock Exchange (NYSE). The amount of the Erroneously Awarded Compensation must not be reduced based on, or otherwise calculated with regard to, any taxes paid by the Covered Executive with respect to such amounts. c) This Policy must only apply to Incentive-Based Compensation that was received during the Applicable Period and that was received (or would have been settled in the absence of an elective deferral of payment by the individual) while TC Energy Corporation has a class of securities listed on a U.S. national securities exchange or a national securities association. For purposes of this Policy, Incentive-Based Compensation is deemed received in the fiscal period during which the Financial Reporting Measure(s) specified in the applicable Incentive-Based Compensation is attained, even if the payment or grant of the Incentive-Based Compensation occurs after the end of such fiscal period. 1.2 In the event of a recoupment of Erroneously Awarded Compensation from a Covered Executive, the Human Resources Committee may also seek reimbursement of all reasonable costs, including legal fees, incurred in connection with the recoupment of the Erroneously Awarded Compensation from such Covered Executive. 2 Impracticability 2.1 The Company must recoup any Erroneously Awarded Compensation unless the conditions set forth in the following clauses (a), (b) or (c) are met and such recoupment would be impracticable, as determined by the Human Resources Committee in accordance with Rule 10D-1 and the NYSE Listing Standards. No recoupment will be required if: a) the direct expense paid to a third party to assist in enforcing this Policy would exceed the amount to be recouped, provided that before concluding that it would be impractical to recoup any amount of Erroneously Awarded Compensation based on this clause (a), the Company must make a reasonable attempt to recoup such Erroneously Awarded Compensation, document such reasonable attempt(s) and provide such documentation to the NYSE; b) recoupment would likely cause an otherwise tax-qualified retirement plan, under which benefits are broadly available to Employees of the Company, to fail to meet the applicable requirements of the U.S. Internal Revenue Code, or any successor provision thereof; or c) recoupment would violate home country law where that law was adopted prior to November 28, 2022, provided that before concluding that it would be impractical to recoup any amount of Erroneously Awarded Compensation based on this clause (c), the Company must obtain an opinion of home country legal counsel, acceptable to the NYSE, that recoupment would result in such violation, and must provide such opinion to the NYSE.

 
Incentive compensation recoupment and holdback policy. UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 3 3 No indemnification 3.1 The Company must not indemnify any current or former Covered Executive against the loss of Erroneously Awarded Compensation, and must not pay, or reimburse any Covered Executives for premiums, for any insurance policy to fund such Covered Executive’s potential repayment obligations. 4 Other recoupment rights 4.1 The Human Resources Committee may require that any employment agreement, equity award agreement, or similar agreement entered into, amended or restated on or after the Effective Date must, as a condition to the grant of any benefit thereunder, require a Covered Executive to agree to abide by the terms of this Policy and the application of this Policy to any award made prior to the Effective Date. 5 Notification requirements 5.1 In the event of a Restatement or potential Restatement, the Financial Reporting department must notify the Corporate Secretarial Legal department and the Human Resources department as soon as reasonably possible. 6 Effective Date 6.1 This Policy is effective as of the Effective Date. 6.2 To the extent there are any inconsistencies, as of the Effective Date, this Policy supersedes all prior contracts, agreements and understandings, written or oral, with any Covered Executive. In the event any contract, agreement or understanding with any Covered Executive is inconsistent with the terms of this Policy, the terms of this Policy will govern. 6.3 The terms of this Policy must apply to any Incentive-Based Compensation that is received by a Covered Executive on or after October 2, 2023, even if such Incentive-Based Compensation was approved, awarded, granted or paid to the Covered Executive prior to October 2, 2023. Subject to applicable law, the Human Resources Committee may effect forfeiture or recoupment under this Policy from any amount of compensation approved, awarded, granted, payable or paid to the Covered Executive prior to, on or after October 2, 2023.

 
Incentive compensation recoupment and holdback policy. UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 4 Your responsibility Employees must follow all applicable provisions and the spirit and intent of this corporate governance document and support others in doing so. Employees must promptly report any suspected or actual violation of this corporate governance document through available channels so that TC Energy can investigate and address it appropriately. Employees who violate this corporate governance document or knowingly permit others under their supervision to violate it, may be subject to appropriate corrective action, up to and including termination of employment or contract, as applicable, in accordance with the Company’s corporate governance documents, employment practices, contracts, collective bargaining agreements and processes. Interpretation and administration The Company has sole discretion to interpret, administer and apply this corporate governance document and to change it at any time to address new or changed legal requirements or business circumstances. Non-retaliation TC Energy supports and encourages Employees and Contractors to report suspected violations of corporate governance documents, applicable laws, regulations, and authorizations, as well as hazards, potential hazards, incidents involving health and safety or the environment, and near hits. Such reports can be made through available channels. TC Energy takes every report seriously and investigates it to identify facts and, when warranted, makes improvements to our corporate governance documents and practices. All Employees and Contractors making reports in good faith will be protected from retaliation, and all Employees and Contractors must report if they or someone they know is being or has been retaliated against for reporting. Good Faith Reporting will not protect Employees and Contractors who make intentionally false or malicious reports, or who seek to exempt their own negligence or willful misconduct by the act of making a report. Definitions Applicable Period means the three completed fiscal years prior to the earlier of: • the date TC Energy Corporation’s Board of Directors, a committee of the Board of Directors, or officer(s) authorized to take such action if action by the Board of Directors is not required, concludes, or reasonably should have concluded, that TC Energy Corporation is required to prepare a Restatement; or • the date a court, regulator, or other legally authorized body directs TC Energy Corporation to prepare a Restatement.

 
Incentive compensation recoupment and holdback policy. UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 5 In addition to the last three completed fiscal years described in the preceding sentence, the Applicable Period includes any transition period (that results from a change in TC Energy Corporation’s fiscal year) within or immediately following those three completed fiscal years; provided, however, a transition period between the last day of TC Energy Corporation’s previous fiscal year end and the first day of its new fiscal year that comprises a period of nine to 12 months would be deemed a completed fiscal year for purposes of the Applicable Period. Covered Executive means all of TC Energy Corporation’s current and former executive officers, as determined by the Human Resources Committee, in accordance with the Listing Standards and Rule 10D-1 and the definition of executive officer as defined in Rule 10D-1(d). Effective Date means December 1, 2023. Employee means full-time, part-time, temporary and student employees of the Company. Erroneously-Awarded Compensation means the amount of Incentive-Based Compensation received by a Covered Executive that exceeds the amount of Incentive-Based Compensation that otherwise would have been received had it been determined based on the Restatements. Exchange Act means the U.S. Securities Exchange Act of 1934, as amended. Financial Reporting Measures means measures that are determined and presented in accordance with the accounting principles used in preparing TC Energy Corporation’s financial statements, and any measures that are derived wholly or in part from such measures, including stock price and total shareholder return. Good Faith Reporting means an open, honest, fair and reasonable report without malice or ulterior motive. Human Resources Committee means the Human Resources Committee of the TC Energy Corporation Board of Directors. Incentive-Based Compensation means all compensation, such as cash bonuses or other cash incentive awards (including any deferred element thereof), and vested and unvested equity awards (including options, restricted stock and restricted stock units, performance stock unit awards and performance stock awards) from the Company that is granted, earned, or vested based wholly or in part upon the attainment of a Financial Reporting Measure. For the avoidance of doubt, Incentive-Based Compensation does not include annual salary, compensation awarded based on completion of a specified period of service, or compensation awarded based on subjective standards, strategic measures, or operational measures, unless also based on attainment of a Financial Reporting Measure. NYSE Listing Standards means Section 303A.14 of the New York Stock Exchange Listed Company Manual. Restatement means an accounting restatement of TC Energy Corporation’s financial statements due to material noncompliance with any financial reporting requirement under the U.S. federal securities laws, including any required accounting Restatement to correct an error in previously issued financial statements that is material to the previously issued financial statements, or that

 
Incentive compensation recoupment and holdback policy. UNCONTROLLED IF PRINTED DOCUMENT CLASSIFICATION: INTERNAL ID: 119865992 LAST REVIEWED: 2023/11/07 STATUS: APPROVED 2023/11/07 EFFECTIVE DATE: 2023/12/01 6 would result in a material misstatement if the error were corrected in the current period or left uncorrected in the current period. Rule 10D-1 means Rule 10D-1 promulgated under the Exchange Act. TC Energy or the Company means TC Energy Corporation and its wholly-owned subsidiaries and operated entities. U.S. SEC means the United States Securities and Exchange Commission. References Related corporate governance and supporting documents • Code of Business Ethics Policy Other References • Dodd-Frank Wall Street Reform • NYSE Listing Standards • U.S. Internal Revenue Code • U.S SEC How to contact us • Policy Questions and Comments TC Energy’s reporting channels • Ethics Helpline • Corporate Compliance • Internal Audit • Human Resources • Legal department • Compliance Coordinators

 
EX-99.1 11 exhibit_991xtcextcpl-feb.htm CODE OF BUSINESS ETHICS POLICY, AS AMENDED exhibit_991xtcextcpl-feb
MAKING THE RIGHT CHOICES – DOING THE RIGHT THING TC Energy’s Code of Business Ethics (COBE) Policy Home Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help Table of contents EXHIBIT 99.1

 
MESSAGE FROM FRANÇOIS POIRIER At TC Energy, we know what we do – and just as importantly – how we do it, matters. Our daily decisions and activities impact the Company and the communities we serve. That’s why we must ensure our actions are aligned with our values. It is important that stakeholders, rightsholders and the public are confident they can count on us to act with integrity no matter the circumstances. Our core values – Safety in every step, Personal accountability, One team, and Active learning – form the foundation of how we do business. Our Code of Business Ethics (COBE) helps us put those values into practice by clarifying what honest and ethical conduct look like in action. Every member of the TC Energy team is expected to read, understand and comply with the principles and requirements set out in COBE and is required to complete annual COBE training and certification. We encourage people to refer regularly to COBE to help guide decisions in ethical situations they may face at work, since it offers clear guidelines and examples of expected behaviour. COBE also provides a framework for asking questions and highlights resources in place to report concerns. Our reputation as a safe, reliable and honest company that moves, generates and stores the energy North America relies on is critical to our continued success. It will take all of us consistently living our values every day to ensure TC Energy continues to be a company that is trusted to make the right choices and do the right thing. François Poirier President & CEO TC Energy – Code of Business Ethics Policy 2 Home Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help Table of contents

 
OUR EXPECTATIONS AND YOUR RESPONSIBILITIES The Code of Business Ethics (COBE) Policy reinforces TC Energy Corporation’s (the Company’s or TC Energy’s) requirements and expectations for conducting business and behaviours, and provides guidance to ensure our daily activities and decisions appropriately reflect, and are consistent with, our core values of Safety in every step, Personal accountability, One team, and Active learning. Doing business ethically, fairly and responsibly is not just a concept at TC Energy, it is a commitment we make every day. The COBE Policy functions in conjunction with TC Energy’s other policies and applies to all Employees, directors, officers and Contingent Workforce Contractors (CWCs) of TC Energy and its wholly- owned subsidiaries and/or operated entities in all countries in which TC Energy conducts business. In addition, TC Energy has a Contractor Code of Business Ethics (COBE) Policy that communicates the same requirements in the COBE Policy, as applicable. You must understand these requirements and know how to meet TC Energy’s standards. We expect compliance with all applicable laws, regulations, policies and rules. Have a question? We’re here to help. If you are unsure of what standard you need to comply with, ask. Contact information is located in the Resources section of this document. Failure to comply with the requirements set out in this document, or any TC Energy policy, may lead to serious consequences and corrective action up to and including termination of employment or contract. Ꝓ Look for this symbol throughout the COBE Policy to guide you to relevant policies available on our websites at TCEnergy.com/about/governance and on our Policy Listing 1TC webpage. TC Energy – Code of Business Ethics Policy 3 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
TABLE OF CONTENTS MESSAGE FROM FRANÇOIS POIRIER . . . . . . . . . . . . . . . . . . . . 2 OUR EXPECTATIONS AND YOUR RESPONSIBILITIES . . . . . . . . . .3 OUR VALUES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 LIVING OUR VALUES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 Making the right choices and doing the right thing . . . . . . . . .7 Reporting safety, legal and ethical violations . . . . . . . . . . . . . 8 Ethics Help Line . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Leader responsibilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Safety in every step . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10 TC Energy’s Life Saving Rules . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Alcohol and drug use and being fit for work . . . . . . . . . . . . . 12 Human rights . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Diversity, employment equity and equal opportunity . . . . . . 14 Harassment and violence-free workplace . . . . . . . . . . . . . . . 14 Protecting everyone from weapons in the workplace . . . . . . . 15 ETHICAL BUSINESS CONDUCT . . . . . . . . . . . . . . . . . . . . . . . .16 Avoiding conflicts of interest . . . . . . . . . . . . . . . . . . . . . . . . . 17 Personal Relationships . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 Outside business activities and outside directorships . . . . . . .19 Other potential conflicts of interest . . . . . . . . . . . . . . . . . . . 20 Gifts, invitations and entertainment . . . . . . . . . . . . . . . . . . . 21 Engaging Government Officials . . . . . . . . . . . . . . . . . . . . . . .23 Political contributions and lobbying . . . . . . . . . . . . . . . . . . . 24 International trade . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Insider trading . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Complying with regulatory requirements . . . . . . . . . . . . . . .27 Inter-affiliate interactions . . . . . . . . . . . . . . . . . . . . . . . . . . 28 Competing fairly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29 Accounting, financial reporting and fraud prevention . . . . . 30 Preventing money laundering and terrorist financing . . . . . . . 31 COMMUNICATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .32 Being socially responsible . . . . . . . . . . . . . . . . . . . . . . . . . . . .33 Being a good ambassador of TC Energy . . . . . . . . . . . . . . . . . 34 Social media and communications with the public . . . . . . . . .35 Public disclosure of information . . . . . . . . . . . . . . . . . . . . . . 36 Dealing fairly with customers, Contractors and other stakeholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .37 Dealing fairly with competitors . . . . . . . . . . . . . . . . . . . . . . 38 ASSETS AND INFORMATION . . . . . . . . . . . . . . . . . . . . . . . . . 39 Protecting confidential information . . . . . . . . . . . . . . . . . . . 40 Generative Artificial Intelligence (AI) . . . . . . . . . . . . . . . . . . 40 Protecting personal information . . . . . . . . . . . . . . . . . . . . . . .41 Managing and maintaining the security of information . . . . 42 Protecting and respecting intellectual property rights . . . . . 43 Use and protection of TC Energy’s assets . . . . . . . . . . . . . . . 44 HAVE A QUESTION? WE’RE HERE TO HELP . . . . . . . . . . . . . . 46 Your responsibility. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .47 Interpretation and administration . . . . . . . . . . . . . . . . . . . . .47 Non-retaliation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .47 Asking questions and reporting concerns . . . . . . . . . . . . . . . 48 Ethics Help Line . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48 GLOSSARY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49 ETHICS HELP LINE Canada / U.S.: 1-888-920-2042 Mexico: 800-283-2783 (if calling from a cell phone) 0-800-283-2783 (if calling from a land line) TCEnergy.com/about/governance/code-of-business-ethics Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help TC Energy – Code of Business Ethics Policy 4

 
OUR VALUES Our values guide our behaviours, decisions and actions every day. SAFETY IN EVERY STEP I put safety first to protect myself, my teammates, the public and the environment. PERSONAL ACCOUNTABILITY I act with integrity and own my commitments and outcomes. ONE TEAM I am part of the greater whole, where our unique skills enable us to achieve more together. ACTIVE LEARNING I embrace learning in all aspects of my work with curiosity and creativity. Ꝓ Our Commitment Statement TC Energy – Code of Business Ethics Policy 5 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
LIVING OUR VALUES + Making the right choices and doing the right thing + Reporting safety, legal and ethical violations + Leader responsibilities + Safety in every step + Life Saving Rules + Alcohol and drug use and being fit for work + Human rights + Diversity, employment equity and equal opportunity + Harassment and violence-free workplace + Protecting everyone from weapons in the workplace TC Energy – Code of Business Ethics Policy 6 Home Table of contents Ethical business conduct Communication Assets and information Have a question? We’re here to help Living our values

 
MAKING THE RIGHT CHOICES AND DOING THE RIGHT THING At TC Energy, making the right choices and doing the right thing aren’t just words – these are fundamental requirements to how we do business that all Personnel must carry out in everything we do. But, what does it really mean to make the right choices and do the right thing? At a minimum, it means following the principles set out in COBE, including: • We report all health, safety and environment related hazards, potential hazards, incidents, near hits and unsafe acts • We comply with the applicable legal requirements and policies that impact us in our daily work • We report, through appropriate internal channels or the Ethics Help Line, any instances of actual or potential non-compliance with legal requirements or with our policies that we become aware of • We do not retaliate against anyone for good-faith reporting • We support others in making the right choices and doing the right thing Even if we try our best to make the right choices and do the right thing, there are times when the right thing isn’t completely clear. It’s at those times that we need to ask ourselves some necessary questions. The below guide to making the right choices and doing the right thing is intended to help you identify the right path in those situations. NO NOT SURE NO NOT SURE NO NOT SURE Is it legal? Would I want everyone to know? You are on the right track! Does it feel right, fair and honest? Contact any of the various safe and confidential resources available to steer you in the right direction. Does it follow COBE and our other policies? Does it support our values? YES YES YES YES YES NO NOT SURE NO NOT SURE TC Energy – Code of Business Ethics Policy 7 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
REPORTING SAFETY, LEGAL AND ETHICAL VIOLATIONS We report actual or potential non-compliances with our policies or our legal requirements, so they can be addressed appropriately. Retaliation for Good Faith Reporting is prohibited at TC Energy and your confidentiality and identity will be protected to the greatest extent possible. ETHICS HELP LINE Canada / U.S.: 1-888-920-2042 Mexico: 800-283-2783 (if calling from a cell phone) 0-800-283-2783 (if calling from a land line) TCEnergy.com/about/governance/code-of-business-ethics How do I report an issue or seek guidance? You are required to report any actual or suspected violation of the law or COBE and all health, safety and environment related hazards, potential hazards, incidents, near hits and unsafe acts of which you may become aware. We take every report seriously and provide immunity from disciplinary action for Good Faith Reporting of incidents and issues. Resources To report an issue, or if you would like guidance on how to make the right choices and do the right thing in a particular situation, the following resources are available to you • Your leader • Your Human Resources Business Partner • Your Compliance Coordinator • Corporate Compliance • Internal Audit • Legal department • Privacy Office • Harassment Investigation Coordinator • Safety Personnel • TC Energy’s Environment Health and Safety Management (EHSM) Incident Management System For contact information – click here. If you are uncomfortable speaking to any of these resources or if you would like to remain anonymous, you can contact the Ethics Help Line. TC Energy – Code of Business Ethics Policy 8 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
Our Enterprise Ethics and Compliance Committee is a senior leadership committee with members from across the Company who contribute to the development of our culture of integrity and ethics and support a consistent, comprehensive, and proactive approach to the management of compliance trends, issues and risks. The Board of Directors’ Governance Committee is responsible for assisting the board with maintaining strong governance policies and practices at TC Energy and recommends and reports to the board on corporate governance issues, principles and guidelines for review, discussion, approval, or other action by the board. LEADER RESPONSIBILITIES TC Energy’s leaders are here to help us make the right choices and do the right thing together. If you are a leader, in addition to acting in accordance with the principles set out in COBE, you are required to: • Inspire Personnel to act ethically by setting an ethical tone within your team • Reinforce the importance of making the right choices and doing the right thing when carrying out corporate objectives (for example, profits and cost management) and support those who are unsure how to make the right choices and do the right thing • Set an example by modeling exemplary ethical business conduct • Create a safe environment where individuals are encouraged to speak up if they become aware of or suspect a legal or ethical violation, and help prevent against retaliation for reporting • Ensure that your team members understand and act in accordance with all legal and ethical requirements that impact them in their jobs, that they know how to report actual or potential non- compliance with the law or COBE or to ask questions regarding ethical or legal matters, and that they complete all required ethics and compliance-related training • Understand your obligation to act on any actual or suspected violations of COBE, any of our other policies, or the law that may be reported to you and the requirement for you to report these issues, as appropriate, to your Compliance Coordinator, Corporate Compliance, Internal Audit, the Harassment Investigation Coordinator, Privacy Office or the Ethics Help Line • Engage with Human Resources, your Compliance Coordinator, Corporate Compliance or Internal Audit to ensure violations of legal requirements or COBE by your direct reports are addressed appropriately (including appropriate corrective action) TC Energy – Code of Business Ethics Policy 9 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
SAFETY IN EVERY STEP Protect myself, my teammates, the public and the environment Our commitment to safety isn’t just a mantra – it’s how we work 24/7, 365 days of the year across our entire organization. What started as a foundational value within our safety department decades ago has now come to mean much more to our Company. We ensure that when doing our work we put safety in every step to prevent all harm, loss and incidents. We expect all Personnel to share TC Energy’s commitment to safety. Whether you work in a field location or in an office setting, you must always ensure that you comply with all health, safety and environment related legal requirements, as well as the requirements set out by TC Energy in COBE and applicable policies. If it isn’t safe, we won’t do it. By reinforcing a disciplined set of rules and providing rigorous training, we approach everything we do with safety and performance at the forefront. TC Energy – Code of Business Ethics Policy 10 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
TC ENERGY’S LIFE SAVING RULES TC Energy’s Life Saving Rules guide the way we work and help us hold each other accountable to the highest possible safety standards. TC Energy’s Life Saving Rules are: • Drive safely and without distraction • Use the appropriate personal protective equipment (PPE) • Conduct a pre-job safety analysis (JSA) • Work with a valid work permit when required • Obtain authorization before entering a confined space • Verify isolation before work begins • Protect ourselves against a fall when working at heights • Follow prescribed lift plans and techniques • Control excavations and ground disturbances We report all health, safety and environment related hazards, potential hazards, incidents, near hits and unsafe acts. We take every report seriously, investigate to identify facts and ensure immunity from disciplinary action for the Good Faith Reporting of all incidents and issues. QUESTION: I’m working on a big project and it’s very important to the Company that it be completed on-time and on-budget. I’m concerned that I might be injured if I rush my work, but I’m feeling a lot of pressure to do so. What should I do? ANSWER: You should never compromise your or anyone else’s safety. If someone is pressuring you to do so, you should report the issue. Committing to TC Energy’s Life Saving Rules means meeting our goal of everyone going home safe from our offices, facilities and project sites, every day. Nothing is more important. TC Energy – Code of Business Ethics Policy 11 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
ALCOHOL AND DRUG USE AND BEING FIT FOR WORK We do not compromise our ability to do our jobs or the safety of others through the use of intoxicants, including alcohol, drugs or medications, whether they are legal or not. Given the nature of TC Energy’s business, it is essential that all Personnel be fit to perform their jobs. The use of alcohol or drugs can impair your judgment and productivity and can lead to serious accidents and health and safety concerns – not only for yourself, but also for your coworkers and the public. What does being fit for work mean? Fit for work means being able to safely and acceptably perform your assigned duties without any limitations due to the use or after-effects of any intoxicants. This can include legally- obtained medications (prescription and over the counter) which have the potential to change or adversely affect the way a person thinks, feels, or acts. TC Energy takes a zero-tolerance approach toward the use of alcohol, drugs and intoxication while working. You must always be fit for work while engaged in any TC Energy business. Inability to do so will result in serious consequences including being removed from our site(s) and subject to appropriate corrective action, up to and including termination of employment or contract. Ꝓ Alcohol and Drug Policy TC Energy – Code of Business Ethics Policy 12 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
HUMAN RIGHTS Consistent with Our Commitment Statement, TC Energy does not tolerate human rights abuses. In our business activities, including engaging with Indigenous groups and stakeholders across Canada, the United States and Mexico, we are committed to respecting human rights. We will not be complicit with, nor engage in, any business activity that supports or facilitates abuse of human rights. As a participant in the United Nations (UN) Global Compact, TC Energy supports the Ten Principles of the UN Global Compact on human rights, labour, environment and anti-corruption. We are committed to making the UN Global Compact and its principles part of the strategy, culture and day-to-day operations of our Company, and to engage in collaborative projects which advance the broader development goals of the UN, particularly the Sustainable Development Goals. TC Energy considers the International Bill of Human Rights, which consists of the Universal Declaration of Human Rights, and the core International Labour Organization (ILO) Conventions when adopting human rights best practices. This enables the Company to comply with all applicable international standards, federal, provincial, state, and local laws, rules, regulations, orders, and ordinances, including, without limitation, environmental protection, energy, health and safety, and labor laws and regulations, as well as applicable industry codes and standards. We stand firmly against the use of forced labour, including child labour, prison labour, bonded labour, military labour, modern forms of slavery, human trafficking and any form of physical or mental abuse within our business and operations, including the Contractors we do business with. TC Energy monitors and assesses its Contractors for compliance with human rights requirements, and may terminate business relationships in the event violations are confirmed. In addition to TC Energy complying with applicable legislated compensation standards, such as minimum wage, wage payment, maximum work hours, mandatory holidays, progressive remuneration in case of overtime and benefits laws, we are committed to providing a fair living wage for all Employees. Employment of individuals below the minimum age permitted by local law is strictly prohibited. Respect for human rights is covered in TC Energy’s annual online Code of Business Ethics training and certification, as well as other related training, as required. Additional mandatory online training includes, but is not limited to, the following courses: • Health and Safety Core training • Inclusion and Unconscious Bias training • Respectful Workplace training Ꝓ Our Commitment Statement Ꝓ Indigenous Relations Policy TC Energy – Code of Business Ethics Policy 13 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
Ꝓ Equal Employment Opportunity and Non- Discrimination Policy Ꝓ Reasonable Workplace Accommodation Policy Ꝓ Harassment-Free Workplace Policy Canada • U.S. • Mexico TC Energy requires you to be tolerant, inclusive and to demonstrate respect for others. TC Energy requires that we treat one another with dignity and respect, and we are committed to maintaining an inclusive and respectful work environment that is free of harassment and violence. DIVERSITY, EMPLOYMENT EQUITY AND EQUAL OPPORTUNITY TC Energy believes that our differences make us stronger and encourages a culture of diversity, inclusion and respect. We prohibit any form of discrimination and require reasonable accommodation of differences. We expect Personnel to create and reinforce an inclusive, creative and productive work environment in which everyone is accepted and respected. HARASSMENT AND VIOLENCE-FREE WORKPLACE Everyone deserves to do their job in a safe, respectful, and inclusive workplace, without fear of harassment or violence. You must always be respectful to our Employees and Contractors and be sensitive to the way in which others may react to your behaviours, comments, gestures or contacts. Always try to resolve differences in a calm and respectful manner, without resorting to insults, threats or violence. TC Energy prohibits any behaviour, including displaying any statements, messages, or images (e.g., on clothing, stickers on hard hats, decals on vehicles, etc.), that is: • Intimidating • Hostile • Offensive • Threatening • Violent • Demeaning or humiliating • Of a sexual nature • Creating an inappropriate work environment TC Energy will take allegations of harassment and violence seriously and address them promptly in a respectful, fair and thorough manner by trained investigators. If required, TC Energy will take appropriate corrective action, up to and including termination of employment or contract. In particular, you must never take actions or make unwanted comments or gestures or discriminate against anyone on the basis of: • Gender • Race • National or ethnic origin • Colour • Disability • Religion • Age • Sexual orientation • Gender identity • Marital status • Family status • Veteran status • National Guard or reserve unit obligations • A criminal conviction • Or any other legally protected grounds TC Energy – Code of Business Ethics Policy 14 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
PROTECTING EVERYONE FROM WEAPONS IN THE WORKPLACE We prohibit the possession, use, carrying or transportation of any dangerous or potentially dangerous weapons, as defined by TC Energy’s Weapons in the Workplace Policy, when conducting Company business: • On or off all Company owned or controlled premises • In all Company vehicles (whether owned, leased or rented) • In all personal vehicles being used while conducting Company business For individuals in jurisdictions that permit firearms to be kept in personal vehicles, when in a Company parking lot the vehicle must be locked, firearms must be hidden from plain view and be kept within a locked case or container within the vehicle. Ꝓ Weapons in the Workplace Policy Individuals who are licensed to carry firearms (openly or in a concealed manner) are not exempt from our Policy. TC Energy – Code of Business Ethics Policy 15 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
ETHICAL BUSINESS CONDUCT + Avoiding conflicts of interest + Personal Relationships + Gifts, invitations and entertainment + Engaging Government Officials + Political contributions and lobbying + International trade + Insider trading + Complying with regulatory requirements + Inter-affiliate interactions + Competing fairly + Accounting, financial reporting and fraud prevention + Preventing money laundering and terrorist financing TC Energy – Code of Business Ethics Policy 16 Home Table of contents Living our values Communication Assets and information Have a question? We’re here to help Ethical business conduct

 
AVOIDING CONFLICTS OF INTEREST We must act in the best interests of TC Energy, avoiding any situation that could place us in a conflict of interest, or create the perception of a conflict of interest. If, and when, a conflict of interest arises, you are required to report the conflict in a timely manner so it can be appropriately investigated and addressed. You should never make or influence business decisions on behalf of TC Energy based on personal relationships, bias or the potential for personal gain. Some examples of conflict of interest can include, but are not limited to: • Gifts, invitations and entertainment • Outside business activities • Corporate opportunities • Directorships or other board positions outside of TC Energy • Director independence • Personal Relationships • Intimate Relationships Ꝓ Conflict of Interest and Integrity Policy Personal accountability is a core value at TC Energy. In simple terms, this means acting with integrity and owning your commitments and outcomes. To act with integrity means we make the right choices and do the right thing – always. This is part of who we are and how we do business, every day. What is a conflict of interest? Conflict of interest means a situation in which Personnel have private interests that could conflict with their ability to act in good faith and the best interests of the Company, or where they may improperly benefit from knowledge acquired at the Company which is not available to the general public. TC Energy – Code of Business Ethics Policy 17 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
PERSONAL RELATIONSHIPS Personnel who have a Personal Relationship within the Company must not be in a direct or indirect reporting relationship with each other. In particular, the Company prohibits all Intimate Relationships between individuals in a direct or indirect reporting relationship. If Personnel are not certain whether a Personal Relationship within the Company is permissible, they should immediately discuss their situation with their TC Energy leader HR Business Partners, or HR Governance. QUESTION: I want to hire someone who I know has a family member already working for TC Energy. Is that allowed? ANSWER: Yes, it is acceptable to hire someone (Employee or CWC) who has family members already working for TC Energy provided that doing so does not result in the person directly or indirectly (through other leader(s)) reporting to their family member. The onus is on all Personnel to notify HR Governance when they become aware of a Personal Relationship where there is a direct or indirect reporting relationship within the Company. TC Energy – Code of Business Ethics Policy 18 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
OUTSIDE BUSINESS ACTIVITIES AND OUTSIDE DIRECTORSHIPS Personnel must not engage in outside business activities (e.g., as a consultant, employee, or director) or Advisory Relationships that could conflict with, or be perceived to conflict with, or are detrimental to the interests of TC Energy, and which may include: • Owning, controlling or directing a material financial interest (greater than one per cent) in a competitor, or in a vendor, supplier, customer or other business which does or seeks to do business with TC Energy • Advising or being involved in a business that competes with TC Energy or that does or seeks to do business with TC Energy • Outside business activities that interfere with Personnel’s day-to-day responsibilities at TC Energy • An outside business activity that requires Personnel to violate their confidentiality or other obligations to TC Energy TC Energy Personnel who have a Family Relationship with a supplier or potential supplier to the Company must ensure that they are not involved in the selection process or in directing or influencing the work of the supplier to whom they are related. In cases where the spouse, common law partner, or other family member of Personnel owns, controls, or directs a material financial interest in any of the outside business activities, that Personnel must contact the Corporate Compliance department for guidance. Personnel must declare all outside business activities and Advisory Relationships that could conflict with or be perceived to conflict with the interests of TC Energy to the Corporate Compliance department for guidance. Any outside business activities must be conducted outside of TC Energy work hours since your time and attention during TC Energy work hours is expected to be directly related to your employment with TC Energy. Personnel must declare all Outside Directorship positions on a board (e.g., board chair, treasurer, secretary, member, etc.) to Corporate Secretarial for review and approval, prior to accepting the position or upon joining the Company. TC Energy – Code of Business Ethics Policy 19 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
OTHER POTENTIAL CONFLICTS OF INTEREST Corporate opportunities Personnel must not take personal advantage of a business opportunity that you discover through the use of Company assets, property, information or your position with TC Energy, or use Company assets, property, information or your position with TC Energy for personal gain or to compete with TC Energy. Political office, appointments to boards or tribunals Personnel may not serve in a political office or on an administrative board or tribunal, if that office, board or tribunal has or may have decision-making authority in respect of any aspect of TC Energy’s business (such as the approval of projects or the issuing of permits). Executive leadership team - other business activities In addition to the conditions set out in the outside business activities and outside directorships section above, prior to serving in any capacity in an unaffiliated organization, the Chief Executive Officer and any member of the Executive Leadership Team must obtain the consent of the Chair of the Governance Committee. Directors’ independence To maintain their independence and to ensure that no relationships exist that may violate applicable corporate, securities and competition laws, all members of the Board of Directors of TC Energy must have their independence assessed: • Annually • In the event of a material change in their respective primary employment status • When they wish to join another board of directors, whether private or public All candidates to TC Energy’s Board of Directors must declare to the Corporate Secretarial group any material interest that they may have in a contract or transaction. All members of the TC Energy Board of Directors who have any material interest in a contract or transaction must recuse themselves from related deliberations and approval. TC Energy – Code of Business Ethics Policy 20 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
GIFTS, INVITATIONS AND ENTERTAINMENT Local customs with respect to providing gifts and other benefits can change depending on where we are doing business; however, these local customs must never compromise, or appear to compromise, our ability to act legally, ethically and objectively. While giving gifts can help to build and maintain strong business relationships, they can also cloud one’s judgement or be seen to improperly influence decisions depending on the nature and context of the gift. We must always be prudent in offering gifts, entertainment or anything of value to anyone or any organization that is a competitor, or that TC Energy does or seeks to do business with, or that TC Energy requires consent or approval from (e.g., a government authority). Corruption in business and government prevents fair and open competition based on merit and it can have a negative impact for both the Company and the individual. To mitigate these negative impacts, we must all comply with TC Energy’s Avoiding Bribery and Corruption Policy, Gift, Meals, Entertainment and Travel for Government Officials Standard, and Gifts and Entertainment Policy. TC Energy – Code of Business Ethics Policy 21 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
Accepting gifts, invitations and entertainment Accepting gifts or invitations from anyone or any organization can affect the way TC Energy is perceived and can run counter to our business objectives and values. We all have an obligation to conduct ourselves in a fair and impartial fashion in all business dealings with anyone or any organization. Careful consideration must be taken when offered a gift or an invitation to an event. Please see the Gifts and Entertainment Policy for more information. Ꝓ Avoiding Bribery and Corruption Policy Ꝓ Gifts and Entertainment Policy Ꝓ Gift, Meals, Entertainment and Travel for Government Officials Standard QUESTION: I have been invited by a shipper to attend the rodeo at the Calgary Stampede. Can I accept the invitation and attend the event? ANSWER: All Personnel must ensure they are acting in a manner which is fair and impartial and which does not create a real or perceived conflict of interest with those with whom we do business. As such, attendance at this event would only be acceptable if the criteria outlined in the Gifts and Entertainment Policy are met and, for Personnel below Vice-President (VP), prior approval is obtained from your VP or above. QUESTION: I sometimes receive items such as coffee mugs and pens from a company that I have a relationship with and which is a supplier to TC Energy. Am I able to accept these items? ANSWER: Employees may accept occasional promotional gifts (such as pens, coffee mugs, calendars) as a customary business courtesy, provided that the gift does not exceed a value of CAD $150/ USD $150/ MXN $1000 per instance or total more than CAD $300/ USD $300/ MXN $2000 in aggregate for the calendar year from the same individual or organization. All dollar amounts for occasional promotional gifts are in local currency where they are being accepted. QUESTION: One of our existing auto leasing suppliers has invited me to attend their annual product roll-out, which will be held in Las Vegas. It is a big event that all customers are invited to. The supplier has offered to pay for all flights and accommodation, in addition to the meals that will be provided as part of the event. The supplier’s contract is not currently up for renewal, and I am not the person responsible for making the decision whether to renew. Can I attend? ANSWER: Given the location of the event, the business benefit to TC Energy should be carefully considered and discussed with your leader. Additionally, since the value of the event is significant, the supplier’s payment for flights and accommodation could create a perception of conflict and/or an obligation on the part of TC Energy. As a result, flights and accommodation should be paid for by TC Energy. You may accept the meals provided by the supplier as part of the event, provided they are not lavish in nature. Further, attendance at this event would only be acceptable if the criteria outlined in the Gifts and Entertainment Policy are met and, for Personnel below Vice-President (VP), prior approval is obtained from your VP or above. Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help TC Energy – Code of Business Ethics Policy 22

 
ENGAGING GOVERNMENT OFFICIALS Engaging with Government Officials is an important part of TC Energy’s business, and during those engagements, expenses for Government Officials may be incurred. You should never provide Government Officials with bribes, payments, kickbacks, gifts or anything else of value for the purpose of improperly influencing their actions or decisions in TC Energy’s favour. These benefits can include entertainment, private parties, charitable contributions or employment opportunities. Even if there is no intent to influence, you should not provide a payment or benefit to any third party if it could appear to be improper. Ꝓ Avoiding Bribery and Corruption Policy Ꝓ Gifts and Entertainment Policy Ꝓ Community Investment Standard Ꝓ Gift, Meals, Entertainment and Travel for Government Officials Standard We are prohibited from offering, paying, promising or authorizing a compensation, payment or benefit to any Government Official, directly or indirectly, to secure any contract, concession or other improper advantage for TC Energy. Such action is prohibited even if the intent is not to influence a Government Official(s), as it could appear to be improper. With the exception of Mexico, many anti-corruption laws allow reasonable gifts or entertainment for Government Officials in limited circumstances. Only gifts, meals, and entertainment that are reasonable, do not influence business decisions and are not otherwise prohibited may be offered. All gifts, meals or entertainment must be provided in accordance with local laws and regulations, be appropriately recorded in TC Energy’s books and records, and follow the appropriate approval processes and thresholds as set out in TC Energy’s Gift, Meals, Entertainment and Travel for Government Officials Standard. TC Energy – Code of Business Ethics Policy 23 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
POLITICAL CONTRIBUTIONS AND LOBBYING TC Energy respects the political process and only makes political contributions and engages in lobbying activities that are legal and transparent. Legal requirements concerning political contributions and lobbying are aimed at preventing corruption in government and at ensuring the proper functioning of the political system. These legal requirements can be complex and vary by jurisdiction (we are not allowed to make political donations at all in some jurisdictions). You must seek approval from the External Relations department before engaging in these activities on behalf of TC Energy. QUESTION: I am very politically active. Is that allowed? ANSWER: TC Energy encourages you to participate in the political process as an individual, in accordance with your own political views and the laws and regulations governing this activity. In doing so, however, you may not use TC Energy’s name, nor indicate that you represent TC Energy, unless you have been authorized to do so. Ꝓ Political Contributions and Activities Policy Ꝓ Political Action Committee Standard TC Energy – Code of Business Ethics Policy 24 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
INTERNATIONAL TRADE When engaging in international business and procuring products from the global marketplace, TC Energy complies with all applicable international trade laws, as well as all customs and taxation requirements. International trade laws prohibit or restrict trade with certain countries that are subject to embargoes or sanctions, as well as with certain individuals and organizations (e.g., entities that have ties to actual or suspected terrorists or drug traffickers). These laws also prohibit or restrict imports and exports of certain types of goods, information and technologies and often impose stringent reporting obligations. Ꝓ Customs and Trade Policy Prior to engaging in any transaction, you must ensure: • that it is legally permitted • that all applicable licensing requirements and reporting and customs obligations are met And consider: • the types and use of the goods, information or technology • the counterparty with which you are dealing • the country in which the counterparty is located Even if TC Energy does not have ownership of a product we have purchased when it crosses a border (e.g., because we take ownership or title on delivery), we may nevertheless be responsible for import and/or export compliance based on certain terms of the purchase contract. It is important to ensure the contract does not contain terms that result in TC Energy inadvertently taking on these obligations. TC Energy – Code of Business Ethics Policy 25 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
INSIDER TRADING We engage only in transactions that have a legitimate business purpose, and we do not interfere with the normal functioning of the markets in which we operate and transact. We also report transactions in accordance with all legal requirements. Through the course of your work with TC Energy, you may have access to non-public information regarding TC Energy, our customers, Contractors and other business partners. You must always maintain the confidentiality of any non-public information encountered through the course of business with TC Energy. To the extent non-public information that you are aware of could be material to a decision to buy or sell shares in TC Energy or another company: • You and your immediate family members must not trade TC Energy shares or other securities based on that information • You must not share material non-public information with another person, except as necessary in the course of business, as outlined in the Public Disclosure Policy. Ꝓ Trading Policy Ꝓ Public Disclosure Policy QUESTION: I own units of a mutual fund that invests in shares of one of our suppliers. Is that a problem? ANSWER: Your ownership of mutual fund units is likely not a problem. If your investment in the supplier is through a mutual fund, you would need to ensure that you do not own more than one per cent of the stock of the supplier; however, because of the indirect nature of the investment, it is also less of a concern than if you owned the shares directly. We conduct business in a way that promotes a fair, efficient and openly competitive operation of markets we participate in and which complies with market manipulation laws. Insider trading is a serious offence and can have significant reputational and legal impacts. For Securities and Insider trading inquiries contact Corporate Secretarial Filing Desk. TC Energy – Code of Business Ethics Policy 26 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
COMPLYING WITH REGULATORY REQUIREMENTS TC Energy is committed to meeting our obligations under all regulations and tariffs. As a regulated Company, TC Energy is subject to many regulatory requirements, including those of the Canada Energy Regulator (CER), the Federal Energy Regulatory Commission (FERC), the North American Energy Reliability Corporation (NERC), and the Comisión Nacional de Hidrocarburos, among others. In addition, TC Energy’s transmission providers are subject to tariffs that we must comply with. Although it is impossible to list all of these requirements here, you must ensure you are familiar with the specific requirements applicable to you in your job. These can include reporting requirements and compliance with technical or other standards. To the extent the requirements of more than one jurisdiction apply, you must comply with the highest of the various standards. TC Energy – Code of Business Ethics Policy 27 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
INTER-AFFILIATE INTERACTIONS As a transmission provider, TC Energy is subject to the Canadian Gas Pipelines Code of Conduct (Code) in Canada, the FERC Standards of Conduct (SOC) in the U.S., and the TC Energía Code of Conduct in Mexico (Inter-Affiliate Codes/Standards of Conduct). These Inter- Affiliate Codes/ Standards of Conduct are intended to ensure that our non-regulated affiliates do not receive an unfair advantage over other customers, whether as a result of discriminatory treatment or the improper sharing of information, Personnel or resources. The Inter-Affiliate Codes/Standards of Conduct also prohibit cross-subsidization at the expense of our transmission customers. In order to ensure compliance with the Inter-Affiliate Codes/Standards of Conduct, you must observe the following rules in your day-to-day activities: All customers must be treated equally Regulated transmission providers cannot give undue preference to any customer, whether affiliated with a TC Energy entity or not. Independent functioning Regulated Personnel must function independently of non-regulated Personnel (e.g., they cannot perform the same jobs). No conduit of information Regulated and shared Personnel must not share, or act as a conduit for the sharing of regulated information* with non-regulated Personnel. Pay fair share Non-regulated entities must pay their fair share of any costs incurred by our regulated transmission providers, so as not to burden our transmission customers with costs our non-regulated entities benefit from. Reporting violations Any violations of the Inter-Affiliate Codes/Standards of Conduct must be reported to the Corporate Compliance department, since TC Energy may be legally required to either publicly post such information on its web site or report it to our regulators. *Regulated information (which may not be shared with non-regulated Personnel or affiliates) includes commercial, financial, strategic, planning, operational and customer information of our transmission providers. Ꝓ TC Energy’s Inter-affiliate Codes/Standards of Conduct TC Energy – Code of Business Ethics Policy 28 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
COMPETING FAIRLY A competitive marketplace in the energy and transmission services that TC Energy provides helps ensure fair prices and customer choice and, in turn, results in the industry as a whole providing more effective and better service. We believe in vigorous, fair competition and comply with all laws designed to protect the ability of companies to compete freely. You should never enter into agreements to: • Fix prices • Decrease capacity or volume available to customers • Allocate customers or markets among competitors • Boycott certain customers or Contractors You need to be very careful whenever you have contact with competitors (whether in trade association meetings, at conferences, through participation in benchmarking groups or in negotiating or otherwise dealing with actual or potential joint venture partners who are also TC Energy competitors) to avoid sharing competitively sensitive information. You must never enter into an agreement to reduce competition, or that is likely to have that effect. QUESTION: While at a trade association meeting recently, a few competitors I was sitting with at dinner started talking about their pricing. I knew it wasn’t appropriate, so I didn’t say anything. Did I do the right thing? ANSWER: While you were right not to participate in the discussion, when in such a situation, it’s a good idea to take the further step of making clear to everyone that the discussion is inappropriate and that you will not participate. If the inappropriate discussion continues, you should excuse yourself from the situation. You should also document what happened and report the matter. This will help to protect you and TC Energy in case anyone ever points to the fact that you were part of a group in which an inappropriate discussion took place. Employees must seek approval from the External Relations department before making any corporate membership payments to trade associations. TC Energy – Code of Business Ethics Policy 29 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
ACCOUNTING, FINANCIAL REPORTING AND FRAUD PREVENTION TC Energy ensures that our accounting, financial records and reporting are fair, accurate, understandable and complete, and we do not falsify financial documents or records, or misstate or misrepresent the nature of costs or expenditures. You must ensure all transactions that you engage in, or that you approve, whether under a TC Energy contract or as an individual business expense, are true and reported accurately, completely and in compliance with all applicable accounting and legal requirements. You must also follow TC Energy’s corporate policies and other requirements respecting the transaction (for example, obtaining of approvals). You must never engage in “off-the-record” or other transactions or accounts that do not fully and accurately state the nature and amount of specific transactions. You must also never falsify any invoice, expenditure, time sheet or other document related to Company cost or revenue. Doing so constitutes fraud and may result in appropriate corrective action, up to and including termination of employment or contract. Ꝓ Avoiding Bribery and Corruption Policy Ꝓ Procurement Policy Ꝓ Business Expense Policy TC Energy’s Procurement Policy and Business Expense Policy TC Energy’s Procurement Policy provides a governing framework for all acquisitions, mandating legal, governance and safety compliance for all Personnel involved in procurement. The Business Expense Policy governs proper management of low-cost, low-risk business expenses, including expectations for corporate credit card use. This Policy prohibits splitting transactions to bypass limits and requires the most senior-level Employee present to incur expenses with multiple Employees from the same unit. Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help TC Energy – Code of Business Ethics Policy 30

 
PREVENTING MONEY LAUNDERING AND TERRORIST FINANCING We expect all our Personnel to be vigilant in ensuring the payments we make and the methods of payment we use are legitimate and legal. Legal requirements concerning money laundering and terrorist financing are in place to deter criminal and terrorist activities of those with whom we might do business. To ensure compliance with these legal requirements you must: • Exercise care before agreeing to do business with a third-party, including ensuring that they were reviewed as part of Supply Chain’s qualification process • Ensure the third-party is legitimate and reputable • Recognize and report any suspicious payments or transactions Ignoring the signs that a transaction or payment initiated by a third party is not legitimate can result in TC Energy being found complicit in any illegal activity that may be associated with the transaction, even if the Company did not expressly authorize it or even know about it. Examples of suspicious payments or transactions include: • Any request by a third-party to have a payment deposited into a personal account rather than a business account • Transactions with entities other than those involved in the underlying contract or business deal • Payments or other transactions involving a country other than that in which the parties to the contract or business deal are located Payments of cash, unusual financing arrangements, fictitious invoices or other efforts by a third party to conceal the true purpose of a payment or transaction also raise concerns. TC Energy – Code of Business Ethics Policy 31 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
COMMUNICATION + Being socially responsible + Being a good ambassador of TC Energy + Social media and communication with the public + Public disclosure of information + Dealing fairly with customers, Contractors and other stakeholders + Dealing fairly with competitors TC Energy – Code of Business Ethics Policy 32 Home Table of contents Living our values Ethical business conduct Assets and information Have a question? We’re here to help Communication

 
BEING SOCIALLY RESPONSIBLE TC Energy is committed to being a good neighbour and supporting and enhancing the communities in which we live and work. Some of the most important communities our business impacts are Indigenous communities. We are committed to working with these communities, to develop positive, long-term relationships based on mutual trust and respect, and recognizing their diversity and the importance they place on the land, their culture and their traditional way of life. In addition to working with Indigenous communities, we also work hard to build and maintain relationships with landowners. We recognize the importance of farming to their communities, and actively support farming-related organizations. Ꝓ Our Commitment Statement Ꝓ Indigenous Relations Policy TC Energy understands the importance that community, charitable and similar non-governmental organizations play in making the communities in which we live and work better places. We actively support these organizations and encourage our Personnel to become involved by volunteering and contributing to charitable and other community-based organizations, including during work hours if approved by your leader. TC Energy – Code of Business Ethics Policy 33 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
BEING A GOOD AMBASSADOR OF TC ENERGY We recognize that we are ambassadors of TC Energy and conduct ourselves in a manner that is respectful and appropriate, and that will not harm TC Energy’s reputation. You must always keep in mind that you are a representative of TC Energy. The things you say and do should reflect the Company’s core values. You should not speak publicly on behalf of TC Energy unless authorized to do so. Any posting or statement on an external website, including personal sites or in other media, should be considered a public statement. Even on your personal time, you must not participate in any illegal or inappropriate statements or activities that could be detrimental to the Company or its reputation. Ꝓ Public Disclosure Policy Ꝓ Communications Policy TC Energy – Code of Business Ethics Policy 34 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
SOCIAL MEDIA AND COMMUNICATIONS WITH THE PUBLIC In the age of social media, it is easy to communicate information broadly and publicly. You need to be particularly aware of your obligations and our expectations when it comes to the disclosure of Company information and ensuring it is in accordance with legal and internal requirements. When sharing information on social media, keep the following requirements in mind: • Do not speak on behalf of, or giving the impression that you are speaking on behalf of, TC Energy unless you have been authorized to do so • Never falsely represent yourself • Do not post anything that reflects negatively on TC Energy and ensure posts are not discriminatory, offensive, or in poor taste • Share only approved TC Energy content, add value to the conversation, and be accurate • Do not post pictures of TC Energy’s facilities or operations unless you are authorized to do so TC Energy – Code of Business Ethics Policy 35 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
PUBLIC DISCLOSURE OF INFORMATION TC Energy ensures that public statements regarding the Company are provided in a timely manner, are fair, accurate and complete, comply with legal requirements and corporate policies, and preserve and protect our reputation and brand. TC Energy has prescribed Personnel who are authorized to speak on our behalf. If you receive an inquiry for information or comment, you should direct it to the appropriate Company representative for response. If you are not sure who the appropriate company representative is to respond, please direct the inquiry to our media line 1-800-608-7859. Ꝓ Public Disclosure Policy Ꝓ Communications Policy Use of Company name for personal gain You must never use the Company’s name or purchasing power or your employment status to obtain personal discounts or rebates from Contractors unless those discounts or rebates are available to all Employees. TC Energy – Code of Business Ethics Policy 36 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
DEALING FAIRLY WITH CUSTOMERS, CONTRACTORS AND OTHER STAKEHOLDERS We consider the impact of our actions on stakeholders, rightsholders, the environment and the communities in which we operate. We follow the requirements of our policies, procedures and commitment statements to make sure we act responsibly to protect us, our co-workers, our workplace and assets and the communities we work in. We act as responsible stewards of the environment and manage risk, share knowledge and best practices to ensure continual improvement. You should never make business decisions on behalf of TC Energy based on personal relationships, unfair bias or the potential for personal gain. We are fair and honest in our dealings with customers, Contractors and other stakeholders and we honour our obligations and commitments to them. Treating customers, Contractors and other stakeholders fairly requires that you: • Enter into business relationships based on merit • Use objective criteria to evaluate them, such as: – Price – Quality – Service It also requires that you are honest and forthright when dealing with others (never omitting important facts, manipulating another person or situation, or misrepresenting yourself or TC Energy), and that you honour TC Energy’s contractual, regulatory and other commitments. TC Energy – Code of Business Ethics Policy 37 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
DEALING FAIRLY WITH COMPETITORS You must ensure that you use only legitimate means (such as searches of public information) to obtain competitive intelligence. You must never use deceit or misrepresent yourself to obtain such information, and you should never take advantage of information you receive in error, for example: • Emails or faxes received in error • Physical documents left in a meeting room or in a public place or which have been sent to you in error • Information you overheard TC Energy – Code of Business Ethics Policy 38 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
ASSETS AND INFORMATION + Protecting confidential information + Protecting personal information + Managing and maintaining the security of information + Protecting and respecting intellectual property rights + Use and protection of TC Energy assets TC Energy – Code of Business Ethics Policy 39 Home Table of contents Living our values Ethical business conduct Communication Have a question? We’re here to help Assets and information

 
PROTECTING CONFIDENTIAL INFORMATION We protect TC Energy’s confidential information, and that of our customers, Contractors and other stakeholders, from improper disclosure and use. We all have access to confidential information. TC Energy confidential information includes all non-public Company information because it may be of use to competitors or harmful to TC Energy or its customers, Contractors or other stakeholders, if disclosed. Confidential information about TC Energy’s projects and operations, such as project delays, costs or outage timing and the resulting system capacity impacts can influence the decisions of participants in the gas market. Such information must be disclosed to all customers and other gas market participants at the same time through our typical communication protocols, such as a bulletin. Because such information is commercially sensitive and can be used by competitors or others to TC Energy’s detriment, it must be protected. You must not disclose such information to anyone who does not need to know the information for legitimate business purposes (including within TC Energy or to a future or potential employer). All confidential information must be protected from unauthorized access. When disposing of confidential information, you must do so in a secure manner, which may include shredding of hard copies. See additional information in the Managing and Maintaining the Security of Information and the Use and Protection of TC Energy’s Assets sections. GENERATIVE ARTIFICIAL INTELLIGENCE (AI) The use of generative AI presents many opportunities, but its misuse can also present potential threats to confidential information. To further protect confidential information, Personnel must never create, transmit or store non-public Company information on non-TC Energy accounts and must use only Company-approved generative AI software on TC Energy computer systems. Confidential information can include: • Marketing information and field notes • Sketches and photographs • Electronic information assets (including emails, voicemails, and text messages) • Computer records or software, specifications, models • Other information which is or may be either applicable to or related in any way to the assets, business or affairs of TC Energy • Information regarding TC Energy’s business, operations, finances, strategies, business plans, or projects • Proposed mergers, acquisitions and divestitures • Engineering designs and reports • Legal proceedings, contracts • Environmental report TC Energy – Code of Business Ethics Policy 40 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
PROTECTING PERSONAL INFORMATION TC Energy takes seriously the fact that its Employees, Contractors, customers and other stakeholders have entrusted the Company with their personal information. Personal information is any information that on its own or when combined with other information, can be used to identify an individual. Personal information may include, but is not limited to, name, contact information, date of birth, demographics, biometrics, employment history, performance appraisals, training records, Employee or national identification numbers, health or medical records, and banking information. Use of personal information must be limited to the business purposes for which the information was provided. To the extent that you collect, store, access, or use personal information of any individual as a result of your work with TC Energy, you may not disclose that personal information to others, or use it for a purpose other than that for which it was collected, without the express approval of TC Energy’s Privacy Office or the individual’s written consent. You should never collect, store, access, use, or disclose personal information for an inappropriate purpose or by inappropriate or illegal means. If you are ever unsure if information can be disclosed or used for a new purpose, check with TC Energy’s Privacy Office before taking any action. For more information, please see the Protection of Personal Information Policy. Ꝓ Protection of Personal Information Policy TC Energy is committed to protecting personal information in compliance with all legal requirements and requires that our Personnel share this commitment to information security. You should protect and safeguard personal information from inappropriate access by applying physical, administrative, and technological safeguards (e.g., keeping physical records in a locked cabinet, and keeping electronic records in a password protected or otherwise restricted folder). TC Energy – Code of Business Ethics Policy 41 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
MANAGING AND MAINTAINING THE SECURITY OF INFORMATION Company records are valuable assets of TC Energy and you must ensure appropriate and reasonable efforts are made to manage, protect and preserve these assets. All of these information assets are important Company records that TC Energy may be required to produce in the event of a legal or regulatory proceeding, audit or investigation. It is important that you manage and retain these assets in accordance with all legal requirements and TC Energy’s corporate policies. In particular, you must never destroy an information asset in the event of a legal hold or an actual or pending legal or regulatory proceeding. Ꝓ Information Management Policy Ꝓ Cybersecurity Policy Ꝓ Records Retention Schedule What are information assets? • Memos • Emails • Accounting records • Invoices and contracts • Technical drawings • Recordings of trade-related phone calls • Records of safety or other incidents • Marketing literature • Other similar types of records What form can an information asset take? An information asset can take any form or on any media, including: • Paper • Digital files • Voice or video recordings • Text and instant messages • Other electronic formats TC Energy – Code of Business Ethics Policy 42 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
PROTECTING AND RESPECTING INTELLECTUAL PROPERTY RIGHTS We preserve TC Energy’s intellectual property rights and respect and honour those of third parties. Intellectual property can include trade secrets, which is any information that gives the owner an economic advantage over its competitors and that the owner takes reasonable steps to keep confidential, as well as copyrights, trademarks and patents, and also includes inventions, innovations, discoveries and copyrighted material developed while employed by TC Energy. We must take steps to protect intellectual property rights. This includes keeping trade secrets confidential, consistently using TC Energy’s trademarks solely as authorized, and respecting the intellectual property rights of third parties. TC Energy respects and honours intellectual property rights by: • Complying with the terms of license agreements that TC Energy has entered into with Contractors • Complying with copyright legislation • Not using improper means to obtain third-party information or trade secrets • Using confidential third-party information only for the purpose for which it was provided TC Energy – Code of Business Ethics Policy 43 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
USE AND PROTECTION OF TC ENERGY’S ASSETS TC Energy assets that you have access to for the completion of your duties must be protected and only used for legitimate business purposes. You have an obligation to be a good steward of the assets that TC Energy provides to you in the course of your work and you must protect these assets from loss, theft, damage and misuse. Additionally, using Company facilities, equipment and/or Company time to work on your personal assets, for personal activities or to store personal assets is not allowed. Limited personal use of Company assets such as accessing Internet or printing is acceptable provided that it does not interfere with your job duties. TC Energy regularly monitors Company internet use, and individuals should not assume any right of privacy with respect to either their use of or data stored on TC Energy’s computer systems. Any misuse of Company assets or services, including inappropriate use of TC Energy’s computer equipment and systems, may lead to serious consequences including appropriate corrective action up to and including termination of employment or contract. Ꝓ Acceptable Use Policy Ꝓ Corporate Security Policy QUESTION: I sometimes use my Company computer to access Facebook during my lunch break and I post about my personal life. Is that allowed? ANSWER: Limited personal use of Company assets to access social media during a break is acceptable; however, you need to keep in mind that you are using a Company computer and accessing the Internet through a TC Energy IP address. You must ensure that you do not post content that is inappropriate or could reflect poorly on TC Energy. The Company regularly monitors the use of its equipment and systems and you should not expect your personal use of TC Energy assets to be private. Any inappropriate or offensive use of Company assets by Personnel may result in disciplinary action. What are Company assets? Company assets can include: • Company time • Equipment • Facilities • Furniture • Computers • Telephones • Supplies • Tools • Personal protective equipment • Corporate credit cards • Other resources What can Company assets NOT be used for? Company assets must not be used for: • Engaging in hate-based activities • Downloading illegal material • Viewing pornography • Other inappropriate uses Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help TC Energy – Code of Business Ethics Policy 44

 
QUESTION: I send my claims to TC Energy benefits providers and use my TC Energy address to receive trade publications, contact lenses and books for the book club that I started with my coworkers. Is that allowed? ANSWER: Personal shipments and mail must not be sent to your TC Energy address. Personal shipments include: • Personal online purchases, such as electronics, clothing, footwear, hygiene/beauty products, food, contact lenses/glasses, book of the month/wine of the month or any other shipments for interest group meetings, including those created by and for Personnel • Personal magazine and newspaper subscriptions, except for business correspondence, trade publications and vendor catalogues • Gifts from friends and family, except for flower deliveries and gifts from Contractors which must comply with all applicable TC Energy corporate policies As an exception to this rule, Personnel may send their claims to TC Energy benefits providers (e.g., Manulife and MetLife) or send personal mail with the appropriate postage affixed through Company mailrooms. QUESTION: I live in a very small condominium and keep my bike chained to an outside bike rack except for winters, when I store it in a paid facility. My co-worker told me about an empty shed in one of the Company’s sites near my condo. Would it be acceptable for me to keep my bike in the Company’s shed for winter? ANSWER: Storing your bike in the Company’s shed for the winter is not acceptable. Storing personal property that is not required during work hours, such as motorized and nonmotorized vehicles, including but not limited to bicycles, motorcycles, RVs and boats, on the Company premises is generally prohibited. There are two exceptions: • Subject to the site management’s approval, Personnel who commute to remote worksites to perform their job duties may park their personal vehicle used to reach the site on the Company premises for the duration of their work shift • Parking spaces on the Company premises that are either designated or paid for by Personnel may be used to park a personal vehicle, subject to notices to vacate the parking space for seasonal cleaning, maintenance or repair TC Energy – Code of Business Ethics Policy 45 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
HAVE A QUESTION? WE’RE HERE TO HELP + Your responsibility and non-retaliation + Asking questions and reporting concerns TC Energy – Code of Business Ethics Policy 46 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
YOUR RESPONSIBILITY Personnel must follow all applicable provisions and the spirit and intent of this corporate governance document and support others in doing so. Personnel must promptly report any suspected or actual violation of this corporate governance document through available channels so that TC Energy can investigate and address it appropriately. Personnel who violate this corporate governance document or knowingly permit others under their supervision to violate it, may be subject to appropriate corrective action, up to and including termination of employment or contract, as applicable, in accordance with the Company’s corporate governance documents, employment practices, contracts, collective bargaining agreements and processes. INTERPRETATION AND ADMINISTRATION The Company has sole discretion to interpret, administer and apply this corporate governance document and to change it at any time to address new or changed legal requirements or business circumstances. NON-RETALIATION TC Energy supports and encourages Employees and Contractors to report suspected violations of corporate governance documents, applicable laws, regulations, and authorizations, as well as hazards, potential hazards, incidents involving health and safety or the environment, and near hits. Such reports can be made through available channels. TC Energy takes every report seriously and investigates it to identify facts and, when warranted, makes improvements to our corporate governance documents and practices. All Employees and Contractors making reports in good faith will be protected from retaliation, and all Employees and Contractors must report if they or someone they know is being or has been retaliated against for reporting. Good Faith Reporting will not protect Employees and Contractors who make intentionally false or malicious reports, or who seek to exempt their own negligence or willful misconduct by the act of making a report. TC Energy – Code of Business Ethics Policy 47 Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help

 
ASKING QUESTIONS AND REPORTING CONCERNS You are required to report in a timely manner any actual or potential non-compliance with COBE, any other TC Energy policies, or any legal obligation, as it applies to you or the Company, so it can be appropriately investigated and addressed. You can do so with confidence that your confidentiality and identity will be protected to the greatest extent possible and that retaliation for good faith reporting is prohibited. ETHICS HELP LINE Although TC Energy has various reporting resources available for Personnel to report a concern or to seek guidance, there may be times when you are not comfortable raising concerns through those resources. TC Energy’s Ethics Help Line is operated by an independent third- party service provider and reporting through the Ethics Help Line is confidential and may be done anonymously. ETHICS HELP LINE Canada / U.S.: 1-888-920-2042 Mexico: 800-283-2783 (if calling from a cell phone) 0-800-283-2783 (if calling from a land line) TCEnergy.com/about/governance/code-of-business-ethics All calls to the Ethics Help Line are free of charge, and can be made in English, French, or Spanish 24 hours a day, seven days a week, 365 days a year. You may use the Ethics Help Line either to report any actual or suspected issues or to ask questions on topics such as: • Accounting irregularities • Alcohol and drug abuse • Conflicts of interest • Employee concerns • Employment practices • Engineering concerns • Environment concerns • Equitable treatment • Harassment • Human rights • Safety • Theft and fraud • Workplace violence • Other improprieties If the issue raises an immediate threat to safety or security, you should contact Corporate Security, local police or other emergency services as appropriate. All reports are taken seriously Regardless of the means used to report, your report will be taken seriously and it will be investigated and addressed appropriately. If you are reporting through the Ethics Help Line, please make note of your key code for your case file since the investigator may contact you through your case file for further information or clarification prior to initiating an investigation. Participation in investigations and audits Personnel, including directors and officers are required to participate in investigations and audits if, and as, requested. QUESTION: I suspect one of my colleagues has violated part of COBE, but I’m not sure my suspicions are correct. I’m concerned I’ll be labeled a tattle-tale (or worse) if I report it. What should I do? ANSWER: If you suspect misconduct, you should report it in a timely manner so it can be investigated. If it turns out not to be an issue, there will be no harm done. However, violations of the law or COBE that are not reported, cannot be addressed, and that can seriously undermine the Company. If that happens, we all suffer. If you report the issue, your confidentiality and identity will be protected and if any retaliation is found to occur, it will be taken very seriously. Home Table of contents Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help TC Energy – Code of Business Ethics Policy 48

 
GLOSSARY Advisory Relationship means a relationship where one provides advice, counsel, suggestions, recommendations, intelligence, guidance or any other similar types of information or opinion. Contingent Workforce Contractor (CWC) means an individual who: • is employed by a third party to work on behalf of TC Energy; • uses TC Energy’s assets (e.g., workstation, email, phone) and corporate services; • is compensated on an hourly or daily rate basis; and • works under the direction of a TC Energy leader. Contractor means a third party hired by TC Energy to perform services for or supply equipment, materials, or goods to the Company. Contractors include, without limitation, Contingent Workforce Contractors and Excluded Contractors. Employee means full-time, part-time, temporary and student employees of TC Energy. Excluded Contractor means a third party or individual employed by a third party who: • delivers services, equipment, materials, or goods to the Company using their own tools and assets (e.g., work station, laptop, email, phone, PPE, vehicle); • does not increase TC Energy corporate headcount and overhead costs; • does not use TC Energy’s assets and corporate services; and • directs their own work or receives direction from their employer. Family Relationship means relatedness or connection by blood, marriage or adoption and includes, but is not limited to: • a marriage/common law spouse; • parent and grandparent; • child and grandchild; • sibling; • aunt and uncle; • niece and nephew; • first cousin; and • any “step”, “common law”, or “in law” variations of the above relationships. Good Faith Reporting means an open, honest, fair and reasonable reporting without malice or ulterior motive. Government Officials means any appointed, elected, or honorary official or any employee of a government, of a government owned or controlled company, or of a public or international organization. This definition encompasses officials in all branches and at all levels of government: federal, state/provincial or local. This definition also includes political parties and party officials and candidates for political office. Indigenous officials may also be considered Government Officials. A person does not cease to be a Government Official by claiming to act in a private capacity or by the fact that he/she serves without compensation. Examples of Government Officials relevant to TC Energy’s business include: • government ministers and their staff; • members of legislative bodies or other elected officials; • officials or employees of government departments; • employees of regulatory agencies; • judges and judicial officials; • employees of government-owned or controlled corporations; • customs, immigration, tax, and police personnel; and • employees of public international organizations, such as the United Nations or World Bank. Intimate Relationship means any romantic and/or dating and/or sexual relationship, including casual encounters. Personal Relationship means all Family Relationships and Intimate Relationships and any other personal relationship that is sufficiently close to create a real or perceived conflict of interest. Personnel means full-time, part-time and temporary Employees and Contingent Workforce Contractors of TC Energy. TC Energy or the Company means TC Energy Corporation and its wholly-owned subsidiaries and/or operated entities. TC Energy – Code of Business Ethics Policy 49 Home Living our values Ethical business conduct Communication Assets and information Have a question? We’re here to help Table of contents

 
February 2025 MAKING THE RIGHT CHOICES – DOING THE RIGHT THING