Methanex Corp 40-F for FY2024
Methanex Corp (MEOH)
40-F
2025-03-07
For: 2024-12-31
View Original
Added on
April 09, 2026
About this 40-F
Methanex Corp filed this 40-F on March 7, 2025, covering the fiscal year ended December 31, 2024 (FY2024).
Headline figures
Fiscal year ended December 31, 2024, as reported in this filing, compared with the same period a year earlier where the filing states it.
- Revenue
- $3.72B
- down 0.1% from $3.72B a year earlier
- Net income
- $250.25M
- down 11.9% from net income of $284.12M a year earlier
- Diluted EPS
- $2.39
- down 7.0% from $2.57 a year earlier
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 40-F
OR
For the fiscal year ended December 31 , 2024000-20115
(Exact name of Registrant as specified in its charter)
not applicable
(Translation of Registrant’s name into English (if applicable))
(Province or other jurisdiction of incorporation or organization)
(Primary Standard Industrial Classification Code Number (if applicable))
not applicable
(I.R.S. Employer Identification Number (if applicable))
Telephone: (604 ) 661-2600
(Address and telephone number of Registrant’s principal executive offices)
Telephone: 212 -894-8940
(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 | Name of each exchange on which registered | ||||||
Securities registered or to be registered pursuant to Section 12(g) of the Act.
| None | ||
| (Title of Class) | ||
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act.
5.125% Senior Notes due October 15, 2027 5.25% Senior Notes due December 15, 2029 5.65% Senior Notes due December 1, 2044 | ||
(Title of Class) | ||
For annual reports, indicate by check mark the information filed with this Form:
Indicate 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.
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 for such shorter period that the Registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.
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).
No ☐ | ||||||||
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 12b-2 of the Exchange Act.
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.
☐ | ||||||||
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.
| PCAOB Auditor Firm ID Number: | Auditor Name: | Auditor Location: | ||||||
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).
☐ | ||||||||
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ANNUAL INFORMATION FORM, AUDITED FINANCIAL STATEMENTS, AND
MANAGEMENT’S DISCUSSION AND ANALYSIS
MANAGEMENT’S DISCUSSION AND ANALYSIS
Methanex Corporation (the “Registrant” or the “Company”) is a Canadian public company whose common shares are listed on the Toronto Stock Exchange (the “TSX”) in Canada (trading symbol: MX) and on the Nasdaq Global Select Market in the United States (trading symbol: MEOH). The Registrant is a “foreign private issuer” as defined in Rule 3b-4 under Securities Exchange Act of 1934, as amended (the “Exchange Act”), and is eligible to file this annual report on Form 40-F pursuant to the multi-jurisdictional disclosure system.
The following documents of the Company are filed as exhibits to, and incorporated by reference into, this Annual Report:
| Document | Exhibit No. | ||||
| Annual Information Form of the Company for the year ended December 31, 2024 | 99.1 | ||||
| Management’s Discussion and Analysis of the Company for the year ended December 31, 2024 (the "2024 MD&A") | 99.2 | ||||
| Audited financial statements of the Company for the years ended December 31, 2024 and 2023, including the reports of Independent Registered Public Accounting Firm with respect thereto | 99.3 | ||||
Pursuant to Rule 3a12-3 under the Exchange Act, the Company’s equity securities are exempt from sections 14(a), 14(b), 14(c), 14(f) and 16 of the Exchange Act.
FORWARD-LOOKING STATEMENTS
This annual report includes or incorporates by reference certain statements that constitute “forward-looking statements” within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements appear in a number of places in this annual report and documents incorporated by reference herein and include statements regarding the Registrant’s intent, belief or current expectations and those of the Registrant’s management. These forward-looking statements involve known and unknown risks and uncertainties that may cause the Registrant’s actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. When used in this annual report or in documents incorporated by reference in this annual report, words such as “believes,” “expects,” “may,” “will,” “should,” “potential,” “estimates,” “anticipates,” “aims,” “goal,” or the negative version of those words or other comparable terminology and similar statements of a future or forward-looking nature are intended to identify these forward-looking statements. These forward-looking statements are based on various factors and were derived utilizing numerous assumptions that could cause the Registrant’s actual results to differ materially from those in the forward-looking statements. Accordingly, readers are cautioned not to put undue reliance on these forward-looking statements. For additional information, please refer to the disclosure contained under the heading, “Caution Regarding Forward-Looking Statements” in the Registrant’s Annual Information Form filed as Exhibit 99.1 to this report.
NOTE TO UNITED STATES READERS REGARDING DIFFERENCES
BETWEEN UNITED STATES AND CANADIAN REPORTING PRACTICES
BETWEEN UNITED STATES AND CANADIAN REPORTING PRACTICES
The Registrant is permitted to prepare this annual report in accordance with Canadian disclosure requirements, which are different from those of the United States. The Registrant prepares its consolidated financial statements in accordance with International Financial Reporting Standards (“IFRS”), as issued by the International Accounting Standards Board, which principles differ in certain respects from generally accepted accounting principles applicable in the United States (“U.S. GAAP”) and from practices prescribed by the SEC. Therefore, the Company’s financial statements incorporated by reference in this annual report may not be comparable to financial statements prepared in accordance with U.S. GAAP.
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CURRENCY
Unless otherwise indicated, all dollar amounts in this Annual Report are in United States dollars. The exchange rate of United States dollars into Canadian dollars on December 31, 2024, the last trading day of the year, based upon the daily exchange rate published by the Bank of Canada, was U.S.$1.00=CDN $1.4389. The exchange rate of United States dollars into Canadian dollars, on March 5, 2025, based upon the daily exchange rate as published by the Bank of Canada, was U.S.$1.00=CDN$1.4370.
CONTROLS AND PROCEDURES
Disclosure controls and procedures are defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act to mean controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission (the “Commission”). Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
At the end of the period covered by this annual report on Form 40-F, being the fiscal year ended December 31, 2024, an evaluation was carried out under the supervision and with the participation of the Registrant’s management, including the principal executive and principal financial officers (its Chief Executive Officer and Chief Financial Officer). Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the Registrant’s disclosure controls and procedures are effective as of December 31, 2024.
MANAGEMENT’S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is defined in Rule 13a-15(f) and 15d-15(f) of the Exchange Act as a process designed by, or under the supervision of, the Registrant’s principal executive officer and principal financial officer, and effected by the Registrant’s board of directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and preparation of the Registrant’s consolidated financial statements for external purposes in accordance with generally accepted accounting principles (which, in the case of the Registrant, are International Financial Reporting Standards, as issued by the International Accounting Standards Board). Internal control over financial reporting includes policies and procedures that:
•pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Registrant;
•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 are being made only in accordance with authorizations of management and directors of the Registrant; and
•provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Registrant’s assets that could have a material effect on the financial statements.
Internal control over financial reporting has inherent limitations. Internal control over financial reporting is a process that involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting also can be circumvented by collusion or improper management override. Because of such limitations, there is a risk that material misstatements will not be prevented or detected on a timely basis by internal control over financial reporting. However, these inherent limitations are known features of the financial reporting process. Therefore, it is possible to design into the process safeguards to reduce, though not eliminate, this risk.
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Management’s Assessment and Auditor’s Attestation Report
In connection with the Company’s reporting obligations in Canada and its obligations under Rule 13a-15(c) under the Exchange Act, management, under the supervision and with the participation of its Chief Executive Officer and Chief Financial Officer, conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024, based on the framework set forth in Internal Control – Integrated Framework, issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission (the “COSO Framework”). Based on its evaluation under this framework, management concluded that our internal control over financial reporting was effective as at that date.
KPMG LLP, an independent registered public accounting firm that audited and reported on our consolidated financial
statements, has issued an attestation report on the effectiveness of our internal control over financial reporting as of
December 31, 2024. The attestation report is included on the fourth page of our consolidated financial statements filed as Exhibit 99.3 to this report.
Changes in Internal Control over Financial Reporting
There have been no changes in the Company’s internal control over financial reporting that occurred during the year ended December 31, 2024 that has materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
AUDIT COMMITTEE
The Registrant’s Board of Directors has established a separately-designated Audit, Finance and Risk Committee (the “Audit Committee”) in accordance with Section 3(a)(58)(A) of the Exchange Act and Nasdaq Listing Rule 5605(c). As at the date of this annual report, the Registrant’s Audit Committee is comprised of the following directors, each of whom is independent as determined under each of Rule 10A-3 under the Exchange Act and Nasdaq Listing Rule 5605(a):
Benita Warmbold, Chair
Paul Dobson
Maureen Howe
Leslie O’Donoghue
Roger Perreault
Margaret Walker
All members of the Audit Committee are financially literate, meaning they are able to read and understand the Company's financial statements and to understand the breadth and level of complexity of the issues that can reasonably be expected to be raised by the Company's financial statements. The Audit Committee meets the composition requirements set forth by Nasdaq Listing Rule 5605(c)(2).
A description of the mandate of the Audit Committee (the “Audit Committee Charter”), together with the relevant education and experience of its members and other Committee information, may be found in the “Audit Committee Information” section of the Registrant’s Annual Information Form for the year ended December 31, 2024, filed as Exhibit 99.1 to this annual report. The full text of the Audit Committee Charter is attached as Appendix “A” to the Annual Information Form.
AUDIT COMMITTEE FINANCIAL EXPERT
The Registrant’s Board of Directors has determined that Ms. Benita Warmbold is an audit committee financial expert (as that term is defined in paragraph (8)(b) of General Instruction B to Form 40-F under the Exchange Act). The Commission has indicated that the designation of Ms. Warmbold as an audit committee financial expert does not make Ms. Warmbold an “expert” for any other purpose (including without limitation for purposes of section 11 of the Securities Act of 1933, as amended), impose any duties, obligations or liability on Ms. Warmbold that are greater than those imposed on members of the Audit Committee and the board of directors who do not carry this designation, or affect the duties, obligations or liability of any other member of the Audit Committee or the board of directors.
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CODE OF ETHICS
The Registrant has adopted a Code of Business Conduct (the “Code of Ethics”) that applies to directors, officers and employees, including the Registrant’s principal executive officer, principal financial officer and principal accounting officer. The Code of Ethics materially complies with NASDAQ Marketplace Rule 5610, and meets the requirements for a “code of ethics” within the meaning of that term in Form 40-F. A copy of the Code of Ethics can be found on the Registrant’s website at www.methanex.com.
No waivers from or substantive amendments to the provisions of the Code of Ethics were made in 2024.
PRINCIPAL ACCOUNTANT FEES AND SERVICES
KPMG LLP, Chartered Professional Accountants, Vancouver, are the independent auditors of the Registrant. The holders of the Registrant’s common shares have resolved to have the directors of the Registrant determine the auditors’ remuneration.
The Registrant’s Audit Committee annually reviews and approves the terms and scope of the external auditors’ engagement. The Audit Committee oversees the Audit and Non-Audit Pre-Approval Policy, which sets forth the procedures and the conditions under which permissible services proposed to be performed by KPMG LLP, the Registrant’s external auditors, are pre-approved. The Audit Committee has delegated to the Chair of the Audit Committee pre-approval authority for any services not previously approved by the Audit Committee. All such services approved by the Chair of the Audit Committee are subsequently reviewed by the Audit Committee.
All non-audit service engagements, regardless of the cost estimate, are required to be coordinated and approved by the Chief Financial Officer to further ensure that adherence to this policy is monitored.
Audit and Non-Audit Fees Billed by the Independent Auditors
KPMG LLP’s global fees relating to the years ended December 31, 2024 and December 31, 2023 are as follows:
| US$000s | 2024 | 2023 | ||||||
| Audit Fees | 2979 | 2415 | ||||||
| Audit-Related Fees | 155 | 160 | ||||||
| Tax Fees | 203 | 165 | ||||||
| All Other Fees | — | — | ||||||
| Total | 3337 | 2740 | ||||||
Each fee category is described below.
Audit Fees
Audit fees for professional services rendered by the external auditors for the audit of the Company’s consolidated financial statements; statutory audits of the financial statements of the Company’s subsidiaries; quarterly reviews of the Company’s financial statements; consultations as to the accounting or disclosure treatment of transactions reflected in the financial statements; and services associated with registration statements, prospectuses, periodic reports and other documents filed with securities regulators.
Audit fees for professional services rendered by the external auditors for the audit of the Company’s consolidated financial statements were in respect of an "integrated audit" performed by KPMG LLP globally. The integrated audit encompasses an opinion on the fairness of presentation of the Company’s financial statements as well as an opinion on the effectiveness of the Company’s internal controls over financial reporting.
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Audit-Related Fees
Audit-related fees for professional services rendered by the auditors for financial audits of employee benefit plans; procedures and audit or attest services not required by statute or regulation; and consultations related to the accounting or disclosure treatment of other transactions.
Tax Fees
Tax fees for professional services rendered for tax compliance, including the review of tax returns; assistance in completing routine tax schedules and calculations; review of transfer pricing and indirect tax items.
Other Fees
There were no other fees in 2024 and 2023.
OFF-BALANCE SHEET ARRANGEMENTS
At December 31, 2024, we did not have any off-balance sheet arrangements, that have, or are reasonably likely to have, a current or future material effect on our results of operations or financial condition.
CONTRACTUAL AND OTHER OBLIGATIONS
The information provided under the heading "Liquidity and Capital Resources" (pages 19-24) contained in the 2024 MD&A, filed as Exhibit 99.2 to this annual report on Form 40-F, is incorporated by reference herein.
NOTICES PURSUANT TO REGULATION BTR
There were no notices required by Rule 104 of Regulation BTR that the Company sent during the financial year ended December 31, 2024, concerning any equity security subject to a blackout period under Rule 101 of Regulation BTR.
NASDAQ CORPORATE GOVERNANCE
The Company is subject to corporate governance requirements prescribed under applicable Canadian securities laws, rules and policies. The Company is also subject to corporate governance requirements prescribed by the listing standards of the Nasdaq Stock Market, and the rules and regulations promulgated by the SEC under the Exchange Act (including those applicable rules and regulations mandated by the Sarbanes-Oxley Act of 2002).
Nasdaq Listing Rule 5615(a)(3) permits a foreign private issuer to follow its home country practice in lieu of certain corporate governance requirements of the Nasdaq Listing Rules. A foreign private issuer that follows a home country practice in lieu of one or more provisions of the Nasdaq Listing Rules is required to disclose in its annual report filed with the Commission, or on its website, each corporate governance requirement of the Nasdaq Listing Rules that it does not follow and describe the home country practice followed by the issuer in lieu of such Nasdaq corporate governance requirements.
A description of the significant ways in which the Company’s governance practices differ from those followed by domestic companies pursuant to Nasdaq standards is as follows:
•Shareholder Meeting Quorum Requirement: Nasdaq Listing Rule 5620(c) provides that the minimum quorum requirement for a shareholder meeting is 331/3% of the outstanding shares of common stock. In addition, a company listed on Nasdaq is required to provide for a quorum requirement in its bylaws. The Company’s by-laws provide that at any meeting of shareholders a quorum shall be two persons present in person, or represented by proxy, holding common shares representing not less than 25% of the votes entitled to be cast at the meeting.
•Distribution of Annual Reports: Nasdaq Listing Rule 5250(d) requires a Nasdaq-listed company to make available to shareholders an annual report containing audited financial statements of the company and its subsidiaries (which, for example, may be on 40-F under the Exchange Act) within a reasonable period of time
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following the filing of the annual report with the Commission. The Company may comply with this requirement either:
◦by mailing the report to shareholders (as opposed to electronic or notice-and-access delivery);
◦by satisfying the requirements for furnishing an annual report contained in Rule 14a-16 under the Exchange Act (which rule is not applicable to the Company, as explained in more detail below); or
◦by posting the annual report to shareholders on or through the company's website, along with a prominent undertaking in the English language to provide shareholders, upon request, a hard copy of the annual report free of charge. A company that chooses to satisfy this requirement in this manner must, simultaneously with this posting, issue a press release stating that its annual report has been filed with the Commission. The press release must also state that: (a) the annual report is available on the company's website and include the website address, and (b) shareholders may receive a hard copy free of charge upon request.
The Company is a “foreign private issuer” as defined in Rule 3b-4 under the Exchange Act, and the Company is accordingly exempt from the proxy rules promulgated by the Commission pursuant to Sections 14(a), 14(b), 14(c) and 14(f) of the Exchange Act (including Exchange Act Rule 14a-16). The Company solicits proxies in accordance with applicable rules and regulations in Canada.
Pursuant to the provisions of the Canada Business Corporations Act (the “CBCA”), the Company, as a “distributing corporation” under the CBCA, is required to send a copy of the annual audited comparative financial statements to each registered shareholder determined as of a set record date, except to a shareholder who has informed the Company in writing that he or she does not want a copy of these documents.
Section 437 of the TSX Company Manual requires that: (a) every TSX-listed company must forward annually to each shareholder who has requested them its annual financial statements and its MD&A in accordance with Canadian National Instrument 51-102 - Continuous Disclosure Obligations ("NI 51-102"); and (b) if a listed company produces an annual report, it must be filed publicly through the System for Electronic Document Analysis and Retrieval + (commonly referred to as “SEDAR+”), an electronic database maintained on behalf of the Canadian provincial securities regulators (the “Canadian Securities Administrators”) and available at www.sedarplus.ca.
Pursuant to NI 51-102, the Company is required to send annually a request form to the registered holders and beneficial owners of its securities, other than debt instruments, that registered holders and beneficial owners may use to request a copy of the Company's annual financial statements and related Management’s Discussion and Analysis (“MD&A”), the interim financial statements and related MD&A, or both. If a registered holder or beneficial owner of securities, other than debt instruments, of the Company requests the Company's annual or interim financial statements, the Company must send a copy of the requested financial statements to the person or company that made the request, without charge, by the later of: (a) 10 days after the filing deadline for the financial statements, or (b) 10 calendar days after the Company receives the request. If the Company sends financial statements it must also send, at the same time, the annual or interim MD&A relating to the financial statements.
The Company has elected to use the notice-and-access (“Notice-and-Access”) provisions adopted by the Canadian Securities Administrators for delivery of proxy materials to its shareholders, as contained in NI 51-102 and National Instrument 54-101 – Communication with Beneficial Owners of Securities of a Reporting Issuer. Pursuant to Notice-and-Access, the Company’s shareholders will receive a notice containing only certain prescribed information in plain language (including the website addresses for SEDAR+ and the non-SEDAR+ websites where the proxy-related materials are posted, as well as a toll-free telephone number for use by shareholders to obtain information about Notice-and-Access and to request paper copies of the proxy materials). Such notice may be sent by the Company by prepaid mail, courier (or the equivalent) or electronically if prior consent has been obtained, along with the applicable voting instruction form.
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If a shareholder requests paper copies of an information circular, the Company will be required to send, free of charge, the items requested within three business days for requests received prior to the date of the meeting, and within 10 calendar days for requests received on or after the date of the meeting but within one year of the information circular being filed on SEDAR+. When responding to such requests, the Company will be prohibited from asking for any other information about the requestor, other than the name and address to which the requested materials are to be sent.
Since the foregoing corporate governance practices of the Company are consistent with the laws, customs and practices in Canada, the Company has sought and received relief from the differing Nasdaq standards pursuant to Nasdaq Listing Rule 5615(a)(3).
The Company believes that there are otherwise no significant differences between its corporate governance policies and those required to be followed by United States domestic issuers listed on the Nasdaq Stock Market. In particular, in addition to having a separate Audit Committee, the Registrant’s Board of Directors has established a separately-designated Human Resources Committee that materially meets the requirements for a compensation committee under Nasdaq Listing Rule 5605(d), as currently in force. The Human Resources Committee's responsibilities include administering the Company's Policy for the Recovery of Erroneously Awarded Incentive-Based Compensation (the "Recovery Policy"), which has been adopted by the Board of Directors pursuant to Rule 5608 of the Nasdaq Listing Rules. A copy of the Recovery Policy is filed as Exhibit 97 to this Annual Report.
The Company is required by National Instrument 58-101 of the Canadian Securities Administrators, Disclosure of Corporate Governance Practices, to describe its practices and policies with regard to corporate governance in management information circulars that are furnished to the Company’s shareholders in connection with annual meetings of shareholders.
MINE SAFETY DISCLOSURE
Not applicable.
DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not applicable.
RECOVERY OF ERRONEOUSLY AWARDED COMPENSATION
Not applicable.
UNDERTAKING
The 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 in relation to which the obligation to file an annual report on Form 40-F arises, or transactions in said securities.
CONSENT TO SERVICE OF PROCESS
A Form F-X signed by the Registrant and the Registrant’s agents for service of process: (a) with respect to the Common Shares, was filed with the Commission together with the Form 40-F of the Registrant on June 16, 1995; (b) with respect to the 5.65% Senior Notes due December 1, 2044 was filed with the Commission together with the Form F-10 of the Registrant on October 31, 2014; (c) with respect to the 5.25% Senior Notes due December 15, 2029, was filed with the Commission together with the Form F-10 of the Registrant on August 22, 2019; and (d) with respect to the 5.125% Senior Notes due October 15, 2027, was filed with the Commission together with the Form F-10 of the Registrant on September 9, 2020.
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EXHIBITS
| Exhibit No | Description | ||||
| 23.1 | |||||
| 31.1 | |||||
| 31.2 | |||||
| 32.1 | |||||
| 32.2 | |||||
97 | |||||
| 99.1 | |||||
| 99.2 | |||||
| 99.3 | |||||
| 101.SCH | Inline XBRL Taxonomy Extension Schema Document | ||||
| 101.CAL | Inline XBRL Taxonomy Extension Calculation Linkbase Document | ||||
| 101.DEF | Inline XBRL Taxonomy Extension Definitions 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, the 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.
METHANEX CORPORATION
Date: March 7, 2025
By: /s/ KEVIN PRICE
Name: Kevin Price
Title: SVP, General Counsel & Corporate Secretary
Exhibit 23.1
Consent of Independent Registered Public Accounting Firm
The Board of Directors of Methanex Corporation
We consent to the use of:
•our report dated March 7, 2025 on the consolidated financial statements of Methanex Corporation (the “Entity”) which comprise the consolidated statements of financial position as of December 31, 2024 and December 31, 2023, the related consolidated statements of income, comprehensive income, changes in equity and cash flows for each of the years in the two-year period ended December 31, 2024, and the related notes, and
•our report dated March 7, 2025 on the effectiveness of the Entity’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 Entity for the fiscal year ended December 31, 2024.
We also consent to the incorporation by reference of such reports in the Registration Statements (No. 333-112624, No. 333-141833, No. 333-194850, and No. 33-217591) on Form S-8 of the Entity.
/s/ KPMG LLP
Chartered Professional Accountants
March 7, 2025
Vancouver, Canada
Exhibit 31.1
CERTIFICATION
I, Rich Sumner, certify that:
1.I have reviewed this annual report on Form 40-F of Methanex 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 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 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.
Date: March 7, 2025
/s/ RICH SUMNER
Rich Sumner
President and Chief Executive Officer
Exhibit 31.2
CERTIFICATION
I, Dean Richardson, certify that:
1.I have reviewed this annual report on Form 40-F of Methanex 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 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 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.
Date: March 7, 2025
/s/ DEAN RICHARDSON
Dean Richardson
Senior Vice President, Finance
and Chief Financial Officer
Exhibit 32.1
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of Methanex Corporation (the “Company”) on Form 40-F for the year ended December 31, 2024 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Rich Sumner, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:
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/ RICH SUMNER
Rich Sumner
President and Chief Executive Officer
March 7, 2025
Exhibit 32.2
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of Methanex Corporation (the “Company”) on Form 40-F for the year ended December 31, 2024 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Dean Richardson, Senior Vice President, Finance and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:
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/ DEAN RICHARDSON
Dean Richardson
Senior Vice President, Finance
and Chief Financial Officer
and Chief Financial Officer
March 7, 2025
MANAGE PEOPLE PROCESSES
Exhibit 97
RECOUPMENT POLICY
As adopted by the Board of Directors on November 16, 2023
PART 1
GENERAL PROVISIONS
Purpose
1.1 This document sets forth the Methanex Corporation Recoupment Policy as amended and restated effective November 16, 2023. This Recoupment Policy has been adopted by resolution of the Board in accordance with certain listing standards of the Nasdaq Stock Market LLC mandated by Rule 10D-1, to facilitate reasonably prompt recovery by the Company of the amount of any Incentive- Based Compensation that is deemed to have been erroneously awarded in the event that the Company is required to restate its financial statements due to material non-compliance with any financial reporting requirement under relevant Securities Laws.
Definitions
1.2 In this Recoupment Policy, the following terms will have the following meanings:
(a) “Accounting Restatement” means an accounting restatement due to material noncompliance of the Company with any financial reporting requirement under the 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 would result in a material misstatement if the error were corrected in the current period or left uncorrected in the current period;
(b) “Board” means the Board of Directors of the Company;
(c) “Canadian Securities Laws” means all applicable securities laws of each of the provinces of Canada in which the Company is a “reporting issuer”, and the respective rules and regulations made and forms prescribed under such laws, together with all applicable published instruments, policy statements, blanket orders, rulings and notices adopted by the securities regulatory authorities in such provinces;
(d) “Company” means Methanex Corporation;
(e) “Human Resources Committee” means the Human Resources Committee of the Board;
(f) “Effective Date” means the effective date of this Recoupment Policy, being the 16th day of November, 2023;
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(g) “Erroneously Awarded Incentive-Based Compensation” means that portion of any Incentive-Based Compensation that has been paid to an Executive Officer and is recoverable under Section 4.1 of this Recoupment Policy, as such Erroneously Awarded Incentive-Based Compensation is determined under this Recoupment Policy;
(h) “Exchange Act” means the United States Securities Exchange Act of 1934, as amended;
(i) “Executive Officer” means any individual deemed to be an “executive officer” of the Company under Rule 10D-1;
(j) “Financial Reporting Measures” means any measures that are determined and presented in accordance with the accounting principles used in preparing the Company’s financial statements, and any measures derived wholly or in part from such measures whether or not the measure is presented within the financial statements or included in a filing with the SEC. For greater certainty, stock price and TSR are included in the definition of Financial Reporting Measures;
(k) “Incentive-Based Compensation” means any compensation that is granted, earned or vested based wholly or in part upon the attainment of a Financial Reporting Measure;
(l) “MJDS” means the United States/Canada multi-jurisdictional disclosure system;
(m) “Nasdaq” means The Nasdaq Stock Market LLC:
(n) “Received” means, in the context of Incentive-Based Compensation, the actual or deemed receipt in the Company’s fiscal period during which the Financial Reporting Measure specified in the Incentive-Based Compensation is attained, even if the payment or grant of the Incentive-Based Compensation occurs after the end of that period;
(o) “Recovery Period” has the meaning set forth in Section 4.4;
(p) “Recoupment Policy” means this policy for the recovery of erroneously awarded executive compensation;
(q) “Rule 10D-1” means Rule 10D-1 adopted by the SEC under the Exchange Act;
(r) “SEC” means the United States Securities and Exchange Commission;
(s) “SEC Final Release” means the final release no. 34-96159 of the SEC entitled “Listing Standards of Recovery of Erroneously Awarded Compensation” in respect of the adoption of Rule 10D-1 pursuant to the requirements of Section 10D of the Exchange Act;
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(t) “Securities Laws” means the Exchange Act and the U.S. Securities Act and, to the extent that the Company has filed any of its financial statements with the SEC under the Exchange Act in reliance on the MJDS, Canadian Securities Laws;
(u) “TSR” means total shareholder return; and
(v) “U.S. Securities Act” means the United States Securities Act of 1933, as amended.
PART 2
ADMINISTRATION
Administration
2.1 This Recoupment Policy will be administered by the Human Resources Committee which will be empowered to, with consideration of applicable Securities Laws,
(a) interpret and administer this Recoupment Policy,
(b) make determinations as to whether any Incentive-Based Compensation that has been Received by the current and former Executive Officers of the Company constitutes Erroneously Awarded Incentive-Based Compensation in the event of an Accounting Restatement,
(c) take action to enforce on behalf of the Company any recovery of any Erroneously Awarded Incentive-Based Compensation pursuant to the provisions of this Recoupment Policy,
(d) make any other determinations that the Human Resources Committee deems necessary or desirable to give effect to the objectives of this Recoupment Policy, and
(e) periodically review legislative developments that may have an impact on this Recoupment Policy, and report to the Board any recommendations.
Interpretations
2.2 This Recoupment Policy is intended to meet the requirements of Nasdaq Listing Rule 5608 and will be interpreted by the Human Resources Committee consistent with the SEC’s interpretation of Rule 10D-1, including the guidance of the SEC set forth in the SEC Final Release and any other applicable law, regulation, rule or interpretation of the SEC or Nasdaq promulgated or issued in connection therewith. This Recoupment Policy is in addition to the requirements of Section 304 of the Sarbanes-Oxley Act of 2002 that are applicable to the Company’s chief executive officer and chief financial officer.
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Compliance
2.3 The Human Resources Committee may require that any employment agreement, offer letter, compensation plan, equity award agreement, or any other agreement entered into on or after the Effective Date require an Executive Officer to agree to abide by the terms of this Recoupment Policy.
PART 3
SCOPE AND INTERPRETATION OF THIS RECOUPMENT POLICY
Effective Period
3.1 This Recoupment Policy will be applied to all Incentive-Based Compensation that is Received by an Executive Officer on or after the Effective Date.
Scope of Executive Officers Subject to Recoupment Policy
3.2 The Human Resources Committee will determine from time-to-time the individuals that are deemed to be subject to the Recoupment Policy by virtue of being considered an Executive Officer.
Scope of Accounting Restatements Subject to Recoupment Policy
3.3 The Accounting Restatements that will trigger the obligation to recover Erroneously Awarded Incentive-Based Compensation will include any restatement of any of the financial statements of the Company filed with the SEC under the Exchange Act to correct an error in previously issued financial statements that is material to the previously issued financial statements, or that would result in a material misstatement if the error were corrected in the current period or left uncorrected in the current period. For clarity, Accounting Restatements include for the purposes of this Recoupment Policy both:
(a) big “R” restatements, being restatements to correct an error material to previously issued financial statements; and
(b) little “r” restatements, being restatements to correct errors that were not material to those previously issued financial statements but would result in a material misstatement if (i) the errors were left uncorrected in the current report or (ii) the error correction was recognized in the current period.
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Determination of When Incentive-Based Compensation is Received
3.4 Incentive-Based Compensation will be deemed Received in the fiscal period during which the Financial Reporting Measure specified in the Incentive-Based Compensation award was attained, even if the payment or grant occurs after the end of that period.
PART 4
RECOVERY OF ERRONEOUSLY AWARDED INCENTIVE-BASED COMPENSATION
Recovery
4.1 In that event that the Company is required to prepare an Accounting Restatement, the Company will reasonably promptly take action to recover the amount of any Erroneously Awarded Incentive-Based Compensation that has been Received by each applicable Executive Officer:
(a) after beginning services as an Executive Officer;
(b) who served as Executive Officer at any time during the performance period for that Incentive-Based Compensation;
(c) while the Company has a class of securities listed on Nasdaq (or another national securities exchange in the United States); and
(d) during the three completed fiscal years immediately preceding the date on which the Company was required to prepare the Accounting Statement, as this three-year period is determined under Section 4.4 below.
4.2 Recovery will be required on a “no fault” basis, without regard to whether an Executive Officer engaged in any misconduct or whether the Executive Officer was responsible for the erroneous financial statements that led to the Accounting Restatement.
Trigger for Recovery of Erroneously Award Compensation
4.3 The date on which the Company is deemed to be required to prepare an Accounting Statement for the purposes of determining the Recovery Period under Section 4.1 will be the earlier to occur of:
(a) the date that the Board or a committee of the Board concludes, or reasonably should have concluded that the Company, is required to prepare an Accounting Restatement; or
(b) the date that a court, regulator or other legally authorized body directs the Company to prepare an Accounting Restatement.
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Determination of Recovery Period
4.4 The recovery period for the determination of Erroneously Awarded Incentive-Based Compensation (the “Recovery Period”) will be determined as the three completed fiscal years immediately preceding the date that the Company is required to prepare an Accounting Restatement, as that date is determined under Section 4.3. In the event of a change in the financial year of the Company, the Recovery Period will also include any transition period that results from a change in the Company’s fiscal year within or immediately following those three completed fiscal years, provided that a transition period between the last day of the Company’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.
Scope of Incentive-Based Compensation Subject to Recovery
4.5 Recovery will be made against each current and former Executive Officer who has Received Incentive-Based Compensation during the three-year Recovery Period to the extent that such Incentive-Based Compensation is determined to be Erroneously Awarded Incentive-Based Compensation. Recovery of Incentive-Based Compensation received while an individual was serving in a non-executive capacity prior to becoming an Executive Officer is not subject to this Recoupment Policy and recovery will not be required. An award of incentive-based compensation granted to an individual before the individual becomes an Executive Officer will be subject to this Recoupment Policy, so long as the Incentive-Based Compensation was received by the individual at any time during the performance period after beginning service as an Executive Officer.
Determination of Amount of Erroneously Awarded Compensation
4.6 The amount of any Erroneously Awarded Incentive-Based Compensation to be recovered under Section 4.1 will be determined as follows for each applicable Executive Officer:
(a) the amount of Incentive-Based Compensation that has been Received by the Executive Officer during the Recovery Period to which this Recoupment Policy applies, less
(b) the amount of the Incentive-Based Compensation that would have been received in respect of the Recovery Period had the Incentive-Based Compensation been determined based on the restated amount.
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4.7 Erroneously Awarded Incentive-Based Compensation will include any Incentive-Based Compensation that was based on stock price or TSR to the extent that the Incentive-Based Compensation was inaccurate as a result of the Accounting Restatement. For Incentive-Based Compensation based on stock price or TSR, where the amount of Erroneously Awarded Incentive- Based Compensation is not subject to mathematical recalculation directly from the information in the Accounting Restatement:
(a) the amount must be based on a reasonable estimate of the effect of the Accounting Restatement on the stock price or TSR upon which the Incentive-Based Compensation was received, and
(b) the amount of the Incentive-Based Compensation that would have been received in respect of the Recovery Period had the Incentive-Based Compensation been determined based on the restated amount.
4.8 The Human Resources Committee shall promptly notify each Executive Officer with a written notice containing the amount of any Erroneously Awarded Compensation and a demand for repayment or return of such compensation.
4.9 The amount of any Erroneously Awarded Incentive-Based Compensation will be computed without regard to any taxes paid by the Executive Officer.
4.10 To the extent that the Executive Officer has already reimbursed the Company for any Erroneously Awarded Compensation Received under any duplicative recovery obligations established by the Company or applicable law, it shall be appropriate for any such reimbursed amount to be credited to the amount of Erroneously Awarded Compensation that is subject to recovery under this Recoupment Policy.
4.11 Notwithstanding anything in this Recoupment Policy, in no event will the Company be required to award any Executive Officer an additional payment or other compensation if the Accounting Restatement would have resulted in the grant, payment or vesting of Incentive-Based Compensation that is greater than the Incentive-Based Compensation actually received by the affected Executive Officer. The recovery of Erroneously Awarded Incentive-Based Compensation is not dependent on if or when the restatement is filed.
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PART 5
ENFORCEMENT OF RECOVERY
Requirement to Recover
5.1 Upon a determination by the Human Resources Committee that the Company is obligated to recover Erroneously Awarded Incentive-Based Compensation under Section 4.1, the Company will take steps to recover such Erroneously Awarded Incentive-Based Compensation other than in circumstances where the Human Resources Committee, or a majority of the independent directors of the Board, has made a determination that recovery would be impracticable.
Deferred Payment Plans
5.2 The Human Resources Committee may consider the establishment of a deferred payment where recovery is required from an Executive Officer and where the deferred payment plan allows the Executive Officer to repay the Erroneously Awarded Incentive-Based Compensation as soon as possible without unreasonable economic hardship to the Executive Officer, depending on the facts and circumstances; provided that any such deferred payment plan shall be narrowly tailored to the Erroneously Awarded Incentive-Based Compensation being recovered so as not to constitute a personal loan to the Executive Officer that is prohibited by Section 13(k) of the Exchange Act.
5.3 This Recoupment Policy does not preclude the Company from taking any other action to enforce an Executive Officer’s obligations to the Company or limit any other remedies that the Company may have available to it and any other actions that the Company may take, including termination of employment, institution of civil proceedings, or reporting of any misconduct to appropriate government authorities.
PART 6
PROHIBITION ON INDEMNIFICATION
Prohibition on Indemnification
6.1 The Company shall not be permitted to indemnify or insure any Executive Officer against (i) the loss of any Erroneously Awarded Compensation that is repaid, returned or recovered pursuant to the terms of this Policy, or (ii) any claims relating to the Company’s enforcement of its rights under this Recoupment Policy. Further, the Company shall not enter into any agreement that exempts any Incentive-based Compensation that is granted, paid or awarded to an Executive Officer from the application of this Recoupment Policy or that waives the Company’s right to recovery of any Erroneously Awarded Compensation, and this Recoupment Policy shall supersede any such agreement (whether entered into before, on or after the Effective Date of this Recoupment Policy).
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Insurance
6.2 The Company will not purchase or pay or reimburse any Executive Officer for any insurance policy to cover losses incurred by any Executive Officer under this Recoupment Policy.
PART 7
AUTHORITY OF THE HUMAN RESOURCES COMMITTEE
Engagement of Professional Advisors
7.1 In addition to any authority provided under its mandate, the Human Resources Committee will have the authority to engage and retain independent legal counsel, independent accounting advisors and any outside professional advisor that it determines necessary to carry out its duties, at the expense of the Company, without the Board’s approval and at any time, and has the authority to determine any such advisor’s fees and other retention terms.
Oversight
7.2 In the event that the Company is required to recover any Erroneously Awarded Incentive- Based Compensation under this Recoupment Policy, such recovery efforts will be undertaken with the supervision of the office of the General Counsel under oversight of the Human Resources Committee, provided that Human Resources Committee will directly supervise such efforts in the event of that the General Counsel is an Executive Officer who is subject to recovery.
Revision Log
Revision # | BRIEF DESCRIPTION OF CHANGE | Revision Date | ||||||
2 | Published as CG1CP034 under Manage Legal & Compliance | 8-Nov-2014 | ||||||
3 | Moved to Manage People Processes as PP1GLBL1000; content updated. | 14-Dec-2023 | ||||||
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Exhibit 99.1
METHANEX CORPORATION
ANNUAL INFORMATION FORM
www.methanex.com
March 7, 2025
| TABLE OF CONTENTS | Page | ||||
Trinidad and Tobago | |||||
APPENDIX "A" | |||||
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REFERENCE INFORMATION
In this Annual Information Form ("AIF"), a reference to the "Company" refers to Methanex Corporation and a reference to "Methanex," "we," "us," "our" and similar words refers to the Company and its subsidiaries or any one of them as the context requires, as well as their respective interests in joint ventures and partnerships.
We use the United States dollar as our reporting currency. Accordingly, unless otherwise indicated, all dollar amounts in this AIF are stated in United States dollars.
In this AIF, unless the context otherwise indicates, all references to "methanol" are to chemical-grade methanol. Methanol’s chemical formula is CH3OH and it is also known as methyl alcohol.
In this AIF, we incorporate by reference our 2024 Management’s Discussion and Analysis ("2024 MD&A"), which contains information required to be included in this AIF. The 2024 MD&A is publicly accessible and is filed on the Canadian Securities Administrators’ SEDAR website at www.sedarplus.ca and on the U.S. Securities and Exchange Commission’s EDGAR website at www.sec.gov.
The approximate conversion of measurement used in this AIF is as follows:
1 tonne of methanol = 332.6 US gallons of methanol
Some of the historical price data and supply and demand statistics for methanol and certain other industry data contained in this AIF are derived by the Company from industry consultants or from recognized industry reports regularly published by independent consulting and data compilation organizations in the methanol industry, including Chemical Market Analytics by OPIS, a Dow Jones company, Tecnon OrbiChem Ltd., Argus, ICIS, S&P Global and Methanol Market Services Asia, an Energy Aspects (EA) company. Industry consultants and industry publications generally state that the information provided has been obtained from sources believed to be reliable. We have not independently verified any of the data from third-party sources nor have we ascertained the underlying economic assumptions relied upon in these reports.
Responsible Care® is a registered trademark of the Chemistry Industry Association of Canada and is used under license by us.
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CAUTION REGARDING FORWARD-LOOKING STATEMENTS
This document contains forward-looking statements with respect to us and our industry. These statements relate to future events or our future performance. All statements other than statements of historical fact are forward-looking statements. Statements that include the words "believes," "expects," "may," "will," "should," "potential," "estimates," "anticipates," "aim," "goal," "targets," "plan," "predict" or other comparable terminology and similar statements of a future or forward-looking nature identify forward-looking statements.
More particularly and without limitation, any statements regarding the following are forward-looking statements:
•anticipated closing date of the acquisition of OCI Global's methanol business ("OCI Acquisition") and the expected benefits of the OCI Acquisition, including benefits related to expected synergies and commodity diversification,
•anticipated synergies and Methanex's ability to achieve such synergies following closing of the OCI Acquisition,
•whether the OCI Acquisition will include OCI Global's 50% share of the Natgasoline plant,
•expected demand for methanol, including demand for methanol for energy uses, and its derivatives,
•expected new methanol supply or restart of idled capacity and timing for startup of the same,
•expected increase in methanol production of assets to be acquired as part of the OCI Acquisition,
•expected shutdowns (either temporary or permanent) or restarts of existing methanol supply (including our own facilities), including, without limitation, the timing and length of planned maintenance outages,
•expected methanol and energy prices,
•expected levels of methanol purchases from traders or other third parties,
•expected levels, timing and availability of economically priced natural gas supply to each of our plants,
•capital committed by third parties towards future natural gas exploration and development in the vicinity of our plants,
•our expected capital expenditures and anticipated timing and rate of return on such capital expenditures,
•anticipated operating rates of our plants,
•expected operating costs, including natural gas feedstock costs and logistics costs,
•expected tax rates or resolutions to tax disputes,
•expected cash flows, cash balances, earnings capability, debt levels, debt reduction and deleveraging plans, and share price,
•availability of committed credit facilities and other financing,
•our ability to meet covenants associated with our long-term debt obligations,
•our shareholder distribution strategy and anticipated distributions to shareholders,
•commercial viability and timing of, or our ability to execute future projects, plant restarts, capacity expansions, plant relocations, or other business initiatives or opportunities,
•our financial strength and ability to meet future financial commitments,
•expected global or regional economic activity (including industrial production levels) and gross domestic product growth,
•expected outcomes of litigation or other disputes, claims and assessments, and
•expected actions of governments, governmental agencies, gas suppliers, courts, tribunals or other third parties.
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We believe that we have a reasonable basis for making such forward-looking statements. The forward-looking statements in this document are based on our experience, our perception of trends, current conditions and expected future developments as well as other factors. Certain material factors or assumptions were applied in drawing the conclusions or making the forecasts or projections that are included in these forward-looking statements, including, without limitation, future expectations and assumptions concerning the following:
•future expectations and assumptions concerning the receipt of all regulatory approvals required to complete the OCI Acquisition,
•Methanex's ability to realize the expected strategic, financial and other benefits of the OCI Acquisition in the timeframe anticipated or at all,
•our ability to procure natural gas feedstock on commercially acceptable terms,
•operating rates of our facilities,
•receipt or issuance of third-party consents or approvals or governmental approvals related to rights to purchase natural gas,
•the establishment of new fuel standards,
•operating costs, including natural gas feedstock and logistics costs, capital costs, tax rates, cash flows, foreign exchange rates and interest rates,
•the availability of committed credit facilities and other financing,
•our ability to sustain the designed operating rates of the Geismar 3 plant,
•global and regional economic activity (including industrial production levels) and gross domestic product growth,
•absence of a material negative impact from major natural disasters,
•absence of a material negative impact from changes in laws or regulations,
•absence of a material negative impact from political instability in the countries in which we operate, and
•enforcement of contractual arrangements and ability to perform contractual obligations by customers, natural gas and other suppliers and other third parties.
However, forward-looking statements, by their nature, involve risks and uncertainties that could cause actual results to differ materially from those contemplated by the forward-looking statements. The risks and uncertainties primarily include those attendant with producing and marketing methanol and successfully carrying out major capital expenditure projects in various jurisdictions, including, without limitation:
•failure to complete the OCI Acquisition in accordance with the material terms of the OCI Acquisition agreement or at all,
•failure to obtain any of the approvals required for the OCI Acquisition,
•failure to acquire OCI Global's 50% joint venture interest in Natgasoline,
•failure to close the OCI Acquisition credit facility,
•unforeseen difficulties in integrating the business operations or assets purchased pursuant to the OCI Acquisition into our business and operations,
•failure to realize the expected strategic, financial and other benefits of the OCI Acquisition in the timeframe anticipated or at all,
•unexpected costs or liabilities associated with the OCI Acquisition,
•increased litigation or negative public perception as a result of the OCI Acquisition,
•increased indebtedness of Methanex,
•conditions in the methanol and other industries, including fluctuations in the supply, demand and price for methanol and its derivatives, including demand for methanol for energy uses,
•the price of natural gas, coal, oil and oil derivatives,
•our ability to obtain natural gas feedstock on commercially acceptable terms to underpin current operations and future production growth opportunities,
5
•the ability to carry out corporate initiatives and strategies,
•actions of competitors, suppliers and financial institutions,
•conditions within the natural gas delivery systems that may prevent delivery of our natural gas supply requirements,
•competing demand for natural gas, especially with respect to any domestic needs for gas and electricity,
•actions of governments and governmental authorities, including, without limitation, the implementation of
policies or other measures that could impact the supply of or demand for methanol or its derivatives,
•changes in laws or regulations,
•import or export restrictions, anti-dumping measures, increases in duties, taxes and government royalties and other actions by governments that may adversely affect our operations or existing contractual arrangements,
•worldwide economic conditions, and
•other risks described in our 2024 MD&A.
Having in mind these and other factors, investors and other readers are cautioned not to place undue reliance on forward-looking statements. They are not a substitute for the exercise of one’s own due diligence and judgment. The outcomes implied by forward-looking statements may not occur and we do not undertake to update forward-looking statements except as required by applicable securities laws.
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THE COMPANY
Methanex Corporation was incorporated under the laws of Alberta on March 11, 1968, and was continued under the Canada Business Corporations Act on March 5, 1992. Its registered and head office is located at 1800 Waterfront Centre, 200 Burrard Street, Vancouver, British Columbia, V6C 3M1 (telephone: 604-661-2600).
The following chart includes the Company’s principal operating subsidiaries as of December 31, 2024, and, for each subsidiary, its place of organization and the Company’s percentage of voting interests beneficially owned or over which the Company exercises control or direction. The chart also shows our principal production facilities and their locations.
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BUSINESS OF THE COMPANY
Methanol is a clear liquid commodity chemical that is produced from natural gas and is also produced from coal, particularly in China. Traditional chemical demand, which represents approximately 50% of global methanol demand, is used to produce traditional chemical derivatives, including formaldehyde, acetic acid and a variety of other chemicals that form the basis of a wide variety of industrial and consumer products. Demand for energy-related applications, which represents over 30% of global methanol demand, includes several applications including methyl tertiary-butyl ether ("MTBE"), fuel applications (including vehicle fuel, marine fuel and other thermal applications), di-methyl ether ("DME") and biodiesel. Demand into methanol-to-olefins ("MTO") represents approximately 20% of global methanol demand. MTO plants produce light olefins which have wide applications in packaging, textiles, plastic parts and automotive components.
We are the world’s largest producer and supplier of methanol and serve customers in Asia Pacific, North America, Europe and South America. Our total annual operating capacity, including Methanex's interests in jointly owned plants, is currently 10.6 million tonnes and is located in the United States, New Zealand, Trinidad and Tobago, Chile, Egypt, and Canada. In addition to the methanol produced at our sites, we purchase methanol produced by others under methanol offtake contracts and on the spot market. This gives us flexibility in managing our supply chain while continuing to meet customer needs and support our marketing efforts. We have marketing rights for 100% of the production from the jointly-owned plant in Egypt, which provides us with an additional 0.6 million tonnes per year of methanol offtake supply when the plant is operating at full capacity. We also had marketing rights for 100% of the production from the jointly-owned Atlas plant in Trinidad and Tobago, which provided us with an additional 0.7 million tonnes per year of methanol offtake supply when the plant was operating at full capacity.
Refer to the Production section on page 15 for more information regarding production at our plants.
DEVELOPMENT OF THE BUSINESS AND CORPORATE STRATEGY
On September 8, 2024, Methanex announced that it entered into a definitive agreement to acquire OCI Global’s (“OCI”) international methanol business for approximately $2.05 billion ("OCI Acquisition"). The transaction includes a methanol facility with an annual production capacity of 910,000 metric tonnes ("MT") of methanol and 340,000 MT of ammonia and a 50 percent interest in a second methanol facility operated by the joint venture Natgasoline LLC (“Natgasoline”) which has an annual capacity of 1.7 million MT of methanol of which Methanex’s share will be 850,000 MT. The transaction also includes a low-carbon methanol production and marketing business and a currently idled methanol facility in the Netherlands.
Under the definitive agreement with OCI, the approximate $2.05 billion purchase price will consist of $1.18 billion in cash, the issuance of 9.9 million common shares of Methanex valued at $450 million (based on a $45 per share price) and the assumption of approximately $450 million in debt and leases. Closing of the transaction is expected in the second quarter of 2025 and is subject to receipt of certain regulatory approvals and other closing conditions including TSX approval for the issuance of Methanex shares to OCI.
There is currently a legal proceeding between OCI and its Natgasoline joint venture partner over certain shareholder rights. The obligation of Methanex to purchase OCI’s 50% stake in Natgasoline is subject to the resolution of this legal proceeding. If it is not settled within a certain period, Methanex has the option to carve out the purchase of the Natgasoline joint venture and close only on the remainder of the transaction.
Three-Year History
2022
On January 26, 2022, in reporting its fourth quarter 2021 results, the Company announced the restart of its Chile IV plant in early October 2021.
On February 1, 2022, the Company and Mitsui O.S.K. Lines, Ltd. ("MOL") announced the completion of the previously announced strategic partnership involving the Company’s Waterfront Shipping subsidiary, with MOL acquiring a 40 percent minority interest for $145 million.
On April 27, 2022, the Company announced that its Board of Directors approved an amendment to its existing normal course issuer bid originally announced on September 16, 2021, which increased the number of common shares that could be purchased under the bid from 3,810,464 to 6,094,171, representing 10% of the public float at the time of the original announcement.
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On September 15, 2022, the Company announced that its Board of Directors approved a normal course issuer bid to commence on September 26, 2022, pursuant to which the Company may purchase up to 3,506,405 common shares, representing 5% of the public float at the time of the announcement, subject to approval by the Toronto Stock Exchange.
On September 15, 2022, the Board of Directors of the Company announced that John Floren will retire as President and CEO and from the Board as of December 31, 2022, and that, following a comprehensive multi-year succession process, the Board appointed Rich Sumner as President and Chief Executive Officer and member of the Board of Directors, effective January 1, 2023.
On September 21, 2022, the Company announced that the Toronto Stock Exchange approved the Company’s previously announced normal course issuer bid, pursuant to which the Company may purchase for cancellation up to 3,506,405 common shares, representing 5% of the 70,128,109 common shares issued and outstanding as of September 15, 2022.
On December 13, 2022, the Company announced the following appointments to its executive leadership team:
–Dean Richardson, Vice President, Corporate Finance at the time of the announcement, was appointed as Senior Vice President, Finance and Chief Financial Officer as of February 1, 2023. Ian Cameron retired from his role as Senior Vice President, Finance and Chief Financial Officer.
–Kevin Maloney, Vice President, Corporate Development at the time of the announcement, was appointed Senior Vice President, Corporate Development as of January 1, 2023. Vanessa James stepped down from her role as Senior Vice President, Corporate Development and Sustainability.
–Gustavo Parra, Vice President, Manufacturing Strategy and Planning at the time of the announcement, was appointed Senior Vice President, Manufacturing as of January 1, 2023. Kevin Henderson retired as Senior Vice President, Manufacturing.
–Karine Delbarre, Vice President, North America Marketing & Logistics at the time of the announcement, was appointed Senior Vice President, Global Marketing & Logistics as of January 1, 2023, filling the vacancy left by Rich Sumner following his appointment as President and CEO.
–Mark Allard, Vice President of North America Manufacturing at the time of the announcement, was appointed Senior Vice President, Low Carbon Solutions as of January 1, 2023. The newly formed role will be focused on capitalizing on the demand and supply opportunities for low-carbon methanol.
–Kevin Price, General Counsel & Corporate Secretary at the time of the announcement, was appointed as Senior Vice President, General Counsel & Corporate Secretary as of January 1, 2023.
2023
On October 13, 2023, the Company announced that it had signed a two-year natural gas supply agreement with the National Gas Company of Trinidad and Tobago ("NGC") for its Titan methanol plant, which is currently idled, to restart operations in September 2024. Simultaneously, the Company announced its intention to idle its Atlas methanol plant in September 2024, when its legacy 20-year natural gas supply agreement expires.
On October 25, 2023, the Company announced the restart of its Chile I plant in September with increased gas availability from Argentina and an increase in 2023 production guidance for Chile from 0.8-0.9 million tonnes to 0.9-1.0 million tonnes.
On November 22, 2023, the Company announced that its 1.26 million tonne Egypt methanol production facility was impacted by an unplanned outage in mid-October as a result of a mechanical failure in the synthesis gas compressor. The unit was removed from service for repairs on an expedited schedule. Production was expected to resume towards the end of the first quarter of 2024.
2024
On February 20, 2024, the Company announced that commercial production of its new 1.8 million tonne methanol plant, Geismar 3, in Geismar, Louisiana had been delayed due to complications that occurred in the autothermal reformer during the late stages of the initial start-up process thereby delaying commercial production up to the end of the third quarter of 2024.
On July 17, 2024, the Company announced that it had entered into an agreement to invest in a Preliminary Front-End Engineering and Design study for carbon capture, utilization and sequestration deployment at its Medicine Hat, Alberta facility.
On July 30, 2024, the Company announced that the repairs to the Geismar 3 plant’s autothermal reformer were complete and that first methanol was successfully produced in late July.
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On August 12, 2024, the Company announced that it had entered into short-term commercial arrangements to provide its contracted natural gas into the New Zealand electricity market and, as a result, idled its manufacturing operations in New Zealand until the end of October 2024.
On September 8, 2024, the Company announced that it had entered into a definitive agreement to acquire OCI’s international methanol business for $2.05 billion.
On October 29, 2024, the Company announced the successful syndication of acquisition financing to support the OCI Acquisition including (i) up to $650 million in Term Loan A commitments which can be drawn upon closing of the OCI Acquisition, and (ii) $600 million in revolving credit facility commitments.
On November 6, 2024, the Company announced the extension of gas contracts with Chilean gas producer, Empresa Nacional del Petróleo, and Argentinian gas producer, YPF S.A., until 2030 and 2027 respectively, on similar economic terms as the previous agreements. These two gas contracts underpin approximately 55% of the site's gas requirements.
On November 19, 2024, the Company announced that its wholly-owned subsidiary, Methanex US Operations Inc., will issue $600 million in aggregate principal amounts of 6.25% senior unsecured notes due 2032 in a private offering, with a portion of the net proceeds to be used to support the OCI Acquisition. The notes are guaranteed on a senior basis by the Company and are subject to a special mandatory redemption if the OCI Acquisition is not completed as further described in the terms of the notes.
Our Strategy
Our primary objective is to create value through our leadership in the global production, marketing and delivery of methanol to customers. To achieve this objective we have a simple, clearly defined strategy: leadership, low cost and operational excellence. We pride ourselves in being a leader in Responsible Care (an operating ethic and set of principles for sustainability developed by the Chemistry Industry Association of Canada and recognized by the United Nations) and having a strategic focus on managing risks and proactive plans relating to personnel health and safety, environmental protection, community involvement, social responsibility, sustainability, security and emergency preparedness. Our brand differentiator "The Power of Agility®" defines our culture of flexibility, responsiveness and creativity that allows us to capitalize on opportunities quickly as they arise, and swiftly respond to customer needs.
Leadership
Leadership is a key element of our strategy. We are focused on creating value through our position as the leading producer and supplier in the global methanol industry, improving our ability to safely and cost-effectively deliver methanol to customers and supporting both traditional and energy-related global methanol demand growth.
We are the leading producer and supplier of methanol to customers in Asia Pacific, North America, Europe and South America. Our 2024 sales volume of 10.5 million tonnes of methanol represented approximately 11% of global methanol demand. This scale allows us the flexibility to meet customer needs globally. Our leadership position has also enabled us to play an important role in the methanol industry, which includes publishing Methanex reference prices that are used in each region as the basis of pricing for our customer contracts.
The geographically diverse locations of our production sites and our shipping fleet allow us to deliver methanol cost-effectively to customers globally. We continue to invest in global distribution and supply infrastructure, which includes the world's largest methanol ocean tanker fleet and terminal capacity in all major international ports, enabling us to enhance value to customers by providing reliable and secure supply.
Another key component of our global leadership strategy is our ability to supplement methanol production with methanol purchased from third parties to give us flexibility in our supply chain to meet customer commitments. We purchase methanol through a combination of methanol offtake contracts and spot purchases. We manage the cost of purchased methanol by taking advantage of our global supply chain infrastructure, which allows us to purchase methanol in the most cost-effective region while still maintaining overall security of supply.
We have storage capacity and offices in strategic global locations that allows us to cost-effectively manage supply to customers and ensure customer service and industry positioning.
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Low Cost
A low cost structure is an important competitive advantage in a commodity industry and is a key element of our strategy. Our approach to major business decisions is guided by a drive to improve our cost structure and create value for shareholders. The most significant components of total costs are natural gas for feedstock and distribution costs associated with delivering methanol to customers.
We manage our natural gas costs in two ways: through gas contracts linked to methanol price and through fixed price contracts. Our production facilities outside North America are largely underpinned by natural gas purchase agreements where the natural gas price is linked to methanol prices. This pricing relationship enables these facilities to be competitive throughout the methanol price cycle. In North America, we have fixed price natural gas supply contracts and financial hedges in place targeting minimum operating rate requirements of approximately 70% in the near term. We purchase our remaining North American gas requirements through the spot market.
Our production facilities are well located to supply global methanol markets and we take a long-term approach to contracting shipping capacity to meet customer needs. Nonetheless, the cost to distribute methanol from production locations to customers is a significant component of total operating costs. These include costs for ocean shipping, in-market storage facilities and in-market distribution. We focus on identifying initiatives to reduce these costs, including optimizing the use of our shipping fleet, third-party backhaul arrangements and taking advantage of prevailing conditions in the shipping market by varying the type and term of ocean vessel contracts. We also look for opportunities to leverage our global asset position by entering into geographic product exchanges with other methanol producers to reduce distribution and transportation costs.
Operational Excellence
We maintain a focus on operational excellence in all aspects of our business. This includes excellence in manufacturing and supply chain processes, marketing and sales, Responsible Care and financial management.
To differentiate ourselves from competitors, we strive to be the best operator and the preferred supplier to customers. We believe that reliability of supply is critical to the success of our customers’ businesses and our goal is to deliver methanol safely, reliably and cost-effectively. Our commitment to Responsible Care drives our adherence to the highest principles of health, safety, environmental stewardship, and social responsibility. We believe this commitment helps us achieve an excellent overall environmental and safety record and aligns our community involvement and social investments with our core values.
Product stewardship is a vital component of a Responsible Care culture and guides our actions through the complete life cycle of our product. We aim for the highest safety standards to minimize risk to employees, customers and suppliers as well as to the environment and the communities in which we do business. We promote the proper use and safe handling of methanol at all times through a variety of internal and external health, safety and environmental initiatives, and we work with industry colleagues to improve safety standards. We readily share technical and safety expertise with key stakeholders (including customers, end-users, suppliers, and logistics providers) through direct communication and active participation in local and international industry associations, seminars and conferences and online education initiatives.
In 2024, our strategy of operational excellence in financial management supported the completion of the Geismar 3 project. We also announced the OCI Acquisition for approximately $2.05 billion, subject to regulatory approval and other closing conditions. While managing both current and future capital needs we also returned cash to shareholders through the regular dividend. As at December 31, 2024, we remain in a strong liquidity position with $892 million in cash and $500 million of undrawn back-up liquidity through our revolving credit facility. In the fourth quarter of 2024, we completed the financing plan for the OCI Acquisition including renewing and increasing the undrawn credit facility, syndicating a $650 million Term Loan A and issuing $600 million in unsecured notes. The OCI Acquisition financing has been structured to allow the flexible repayment of the term loan commitment to support our capital allocation priority to reduce debt. During the fourth quarter, we also repaid $300 million in unsecured notes that were due in December 2024 with cash generated from operations. We actively manage our liquidity and capital structure in light of changes to economic conditions, the underlying risks inherent in our operations and the capital requirements of our business.
Sustainability
We have embedded sustainability into our long-term strategy alongside our commitment to Responsible Care. We prioritize material sustainability topics, which are those environmental, social or governance topics that can significantly impact our business success and are of interest to our key stakeholders. The materiality assessment that we conducted in 2023 included external stakeholder outreach and confirmed greenhouse gas ("GHG") emissions, transition to a low-carbon economy, employee and contractor safety and process safety as our most material sustainability topics. We completed a double materiality
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assessment at the end of 2024 to prepare for the European Corporate Sustainability Reporting Directive (CSRD). Our most material sustainability topics are unchanged. We are also monitoring the EU Omnibus proposal, which was published on February 26, 2025 and will adjust our reporting approach as appropriate.
Our executive leadership team has overall responsibility for ensuring our material sustainability topics are being effectively evaluated and managed. These include climate-related risks and opportunities associated with our GHG emissions and the transition to a low-carbon economy. The Executive Leadership Team incorporates these matters into our strategic and business planning activities to support the long-term sustainability of our business.
To improve decision making and evaluate organizational risks and opportunities under different plausible futures, we started incorporating scenario planning into our strategy development process. As part of our strategic planning in 2024, we used a dynamic general equilibrium energy model to analyze the potential implications to energy markets (including methanol) of several scenarios that differed on the pace of the energy transition.
We believe that having a diverse team, equitable people practices and an inclusive workplace leads to a better culture, better decisions and a better company. Our vision is to have an inclusive culture where diversity is valued, differences are embraced and everyone has the opportunity to contribute, develop and advance. The Global Equity, Diversity, and Inclusion Council, made up of senior leaders from around the globe, supports the development and execution of our vision and its integration into the business. In 2024, we made significant strides towards achieving our vision, including the development of a new guide to inclusive and equitable recruitment to support the hiring process. We also established three new Employee Resource Groups, which create a safe environment for team members who share an interest in a specific dimension of diversity to connect and raise awareness.
In March 2025, we issued our 2024 Sustainability Report, aligned with the Sustainability Accounting Standards Board (SASB) and the Task-Force on Climate-related Financial Disclosures (TCFD).The Report is also a transitional report as we shift towards CSRD and European Sustainability Reporting Standards requirements for 2025. The 2024 Sustainability Report is available at https://www.methanex.com/sustainability.
METHANOL INDUSTRY INFORMATION
Demand Factors
Based on the diversity of end products in which methanol is used, demand for methanol is driven by a number of factors, including: the strength of global and regional economies, industrial production levels, energy prices, pricing of end products, downstream capacity and government regulations and policies.
We estimate that global methanol demand increased to approximately 97 million tonnes in 2024 driven primarily by growth in traditional chemical and energy applications and stable demand from the methanol to olefins (MTO) sector.
Traditional Chemical Derivative Demand
Traditional chemical demand, which represents approximately 50% of global methanol demand, is used to produce traditional chemical derivatives, including formaldehyde, acetic acid and a variety of other chemicals that form the basis of a wide variety of industrial and consumer products. Over the long term, we believe that traditional chemical demand is influenced by the strength of global and regional economies and industrial production levels. The use of methanol derivatives such as formaldehyde and acetic acid in the building industry means that building and construction cycles and the level of wood products production, housing starts and consumer spending are important factors in determining demand for such derivatives. Demand is also affected by automobile production, durable goods production, industrial investment and environmental and health trends, as well as new product development. Historically, chemical derivative demand for methanol has been relatively insensitive to changes in methanol prices. We believe this demand inelasticity is because there are limited, if any, cost-effective substitutes for methanol-based chemical derivative products and because methanol costs in most cases account for only a small portion of the value of many of the end products.
Formaldehyde Demand
In 2024, methanol demand to produce formaldehyde represented approximately 25% of global methanol demand. The largest use for formaldehyde is as a component of urea-formaldehyde and phenol-formaldehyde resins, which are used as wood adhesives for plywood, particleboard, oriented strand board, medium-density fibreboard and other reconstituted or engineered wood products. There is also demand for formaldehyde as a raw material for engineering plastics and in the manufacture of a variety of other products, including elastomers, paints, building products, foams, polyurethane, and automotive products.
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Acetic Acid Demand
In 2024, methanol used to produce acetic acid represented approximately 10% of global methanol demand. Acetic acid is a chemical intermediate used principally in the production of vinyl acetate monomer, acetic anhydride, purified terephthalic acid and acetate solvents, which are used in a wide variety of products, including adhesives, paper, paints, plastics, resins, solvents, pharmaceuticals, and textiles.
Other Chemical Derivative Demand
In 2024, the remaining chemical derivative demand for methanol represented approximately 15% of global methanol and is used in the manufacture of methylamines, methyl methacrylate and a diverse range of other chemical products that are ultimately used to make products such as adhesives, coatings, plastics, film, textiles, paints, solvents, paint removers, polyester resins and fibres, explosives, herbicides, pesticides, poultry feed additives and a variety of health and pharmaceutical products. Other end uses include silicone products, aerosol products, de-icing fluid, windshield washer fluid for automobiles and antifreeze for pipeline dehydration.
Energy Demand
Demand for energy-related applications, which represents over 30% of global methanol demand, includes a number of applications including methyl tertiary-butyl ether ("MTBE"), fuel applications (including vehicle fuel, marine fuel and a fuel for industrial boilers and kilns), di-methyl ether and biodiesel. We believe that demand for energy-related applications will be influenced by energy prices, pricing of end products, and government policies that are playing an increasing role in encouraging new applications for methanol due to its emissions benefits as a fuel. Ongoing regulatory changes as part of the global energy transition along with other factors have led to a growing interest in methanol as a fuel due to its clean-burning attributes and potential to reduce greenhouse gas emissions if made from a renewable feedstock.
Methyl tertiary-butyl (MTBE) Demand
MTBE is used primarily as an oxygenate blended in gasoline to contribute octane and reduce the amount of harmful exhaust emissions from motor vehicles. MTBE is an efficient and cost-competitive gasoline component and, as such, is increasingly used in developing countries targeting gasoline pool extension and clean air benefits at a cost lower than that of alternatives. Asia represents the majority of global MTBE demand, with China being a significant market. China is the world’s largest automotive market and has publicly stated its desire to reduce exhaust emissions. In the U.S., MTBE production for export markets continues to increase as a result of a plant that started up in 2023 and achieved higher operating rates in 2024. By the end of 2024, approximately 12 million tonnes of methanol, or 12% of global demand, was consumed for the production of MTBE.
Methanol Demand for Fuel Applications
Methanol can be used as a marine fuel, vehicle fuel and as a fuel for industrial boilers, kilns and for cooking stoves.
There is growing interest in methanol as a marine fuel given its environmental benefits, wide availability, cost competitiveness and ease of use. When made from renewable sources, methanol can be carbon neutral on a life-cycle basis, providing a future-proof pathway to meet the decarbonization goals of the shipping industry. The potential demand outlook for methanol as marine fuel continues to grow with orders for dual-fueled vessels and retrofits. The current vessels operating coupled with the order book for new builds and retrofits represents over 350 dual-fueled ships on the water by 2030. Actual methanol consumption from marine applications will depend on regulations, relative economics versus other fuels, and other factors.
Methanol is also being used as a vehicle fuel in China. Methanol can be blended with gasoline in low quantities and used in existing vehicles and can be used in high-proportion blends such as M85 in flex-fuel vehicles or M100 in dedicated methanol-fueled vehicles. There is significant interest in high-level methanol fuel blends for M100 taxis and trucks (able to run on 100% methanol fuel) in China. There are approximately 25,000 taxis and methanol hybrid passenger cars and 5,000 heavy-duty trucks in China, running on M100 fuel, representing approximately one million tonnes of annual methanol demand. Other countries are in the assessment or near-commercial stage for using methanol as a vehicle fuel.
In China, stricter air quality emissions regulations in several provinces are leading to a phase-out of coal-fueled commercial boilers, kilns, and cooking stoves in favour of cleaner fuels, creating a growing market for methanol as an alternative fuel. We estimate that this demand segment represents approximately seven million tonnes of methanol demand. We continue to support the development of operational and safety standards to support the commercialization of methanol as a thermal fuel for industrial boilers, kilns and cooking stoves.
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Methanol is also used in the production of di-methyl ether (DME) and biodiesel. DME is a clean-burning fuel that can be stored and transported like LPG. It is used for household cooking, heating, and a clean-burning substitute for diesel fuel in transportation. Biodiesel is a renewable biofuel and its primary use is in transportation. In 2024, global methanol demand for use in DME and biodiesel was estimated at over seven million tonnes, or over 7% of global demand.
In 2024, global methanol demand for use in all fuel applications mentioned above was estimated at approximately 19 million tonnes, or over 20%.
Methanol-to-Olefins (MTO) Demand
Demand for MTO applications represents approximately 20% of global methanol demand. The future operating rates and methanol consumption of MTO producers will depend on a number of factors, including pricing for their various final products, the degree of downstream integration of these units with other products, the availability of methanol supply, the impact of olefin industry feedstock costs, including naphtha, on relative competitiveness and plant maintenance schedules.
Light olefins (ethylene and propylene) are the basic building blocks used to make many everyday products that have wide application in packaging, textiles, plastic parts and containers, and automotive components. Olefins can be produced from various feedstocks, including naphtha, liquefied petroleum gas, ethane and methanol. In 2024, over 17 million tonnes of methanol, or over 15% of global demand, in the merchant market was consumed by MTO plants in China (excluding demand from upstream-integrated coal-to-olefins plants). We estimate the current MTO capacity for merchant methanol to be approximately 20 million tonnes per annum excluding the integrated coal-to-methanol (CTO) facilities.
Supply Factors
Methanol industry supply is impacted by the cost of production, methanol industry operating rates and methanol industry capacity changes.
Methanol is produced from natural gas and is also produced from coal, particularly in China. The cost of production is influenced by the availability and cost of raw feedstock materials, freight costs, other operating and maintenance costs and government policies.
The industry has historically operated below stated capacity on a consistent basis, even in periods of high methanol prices, primarily due to shutdowns for planned or unplanned maintenance and feedstock shortages and/or uneconomical feedstock costs. Methanol industry supply can increase through improving operating rates of existing methanol plants.
Methanol industry capacity can increase through the construction of new methanol plants, by restarting idle methanol plants, or by expanding or debottlenecking existing plants to increase their operating capacity. There is typically a span of four to six years to plan and construct a new world-scale methanol plant.
Typical of most commodity chemicals, periods of sustained high methanol prices encourage producers to operate at maximum rates and encourage the construction of new plants and expansion projects, leading to the possibility of oversupply in the market. However, historically, many of the announced capacity additions have not been constructed for a variety of reasons. The construction of world-scale methanol facilities requires significant capital over a long lead time, a location with access to significant natural gas or coal feedstock with appropriate pricing, and an ability to market and deliver methanol cost-effectively and reliably to customers.
Operating rates continue to be uncertain and challenged due to the impact of trade sanctions, plant technical issues, and structural and seasonal natural gas constraints. The methanol industry ran at similar rates in 2024 compared to 2023. In 2024, there were approximately 1.5 million tonnes of production capacity additions in China. In North America, our new 1.8 million tonne Geismar 3 facility completed its commercial performance tests and is now operating at full rates. With the idling of Atlas and the restart of Titan in September 2024 overall production in Trinidad is lower by approximately 1 million tonnes annually. In Malaysia, we understand that a 1.8 million tonne plant started up in early 2025. We expect limited capacity additions in the next five years. In Iran, projects under development are showing slow progress due to technical and financing challenges from sanctions and the operating rates of existing methanol plants are constrained by gas availability due to depleting gas fields. If sanctions impacting Iran and/or other methanol producing countries are eased or removed, this could lead to an increase in methanol supply. China has planned capacity additions which we expect will be somewhat offset by the closure of some inefficient older plants. New capacity built in China is expected to be consumed domestically as China requires methanol imports to meet growing demand.
Operating rates continue to be uncertain and challenged due to the impact of trade sanctions, plant technical issues, and structural and seasonal natural gas constraints. The methanol industry ran at similar rates in 2024 compared to 2023. In 2024, there were approximately 1.5 million tonnes of production capacity additions in China. In North America, our new 1.8 million tonne Geismar 3 facility completed its commercial performance tests and is now operating at full rates. With the idling of Atlas and the restart of Titan in September 2024 overall production in Trinidad is lower by approximately 1 million tonnes annually. In Malaysia, we understand that a 1.8 million tonne plant started up in early 2025. We expect limited capacity additions in the next five years. In Iran, projects under development are showing slow progress due to technical and financing challenges from sanctions and the operating rates of existing methanol plants are constrained by gas availability due to depleting gas fields. If sanctions impacting Iran and/or other methanol producing countries are eased or removed, this could lead to an increase in methanol supply. China has planned capacity additions which we expect will be somewhat offset by the closure of some inefficient older plants. New capacity built in China is expected to be consumed domestically as China requires methanol imports to meet growing demand.
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Methanol Prices
The methanol business is a highly competitive commodity industry and future methanol prices will ultimately depend on the strength of global demand and methanol industry supply but can also be impacted by other factors such as global trade disputes and government sanctions. Methanol demand and industry supply are driven by several factors as described above. Methanol prices have historically been, and are expected to continue to be, characterized by cyclicality. We are not able to predict future methanol prices, which are driven by several factors that are beyond our control.
We publish regional non-discounted reference prices for each methanol sales region and these posted prices are reviewed based on industry fundamentals and market conditions and revised monthly in North America, Asia Pacific, and China and quarterly in Europe. Most of our customer contracts use published Methanex reference prices as a basis for pricing, and we offer discounts to customers based on various factors. The sales weighted average posted price less the sales weighted average discount generates our average realized price which drives our revenue.
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PRODUCTION
Production Process
The methanol manufacturing process used in our facilities typically involves heating natural gas, mixing it with steam and passing it over a nickel catalyst where the mixture is converted into carbon monoxide, carbon dioxide and hydrogen. This reformed gas (also known as synthesis gas or syngas) is then cooled, compressed and passed over a copper-zinc catalyst to produce crude methanol. Crude methanol consists of approximately 80% methanol and 20% water by weight. To produce chemical-grade methanol, crude methanol is distilled to remove water, higher alcohols and other impurities.
Operating Data and Other Information
We endeavour to operate our production facilities around the world in an optimal manner to lower our overall delivered cost of methanol.
Scheduled shutdowns of plants are necessary to change catalysts or perform maintenance activities that cannot otherwise be completed with the plant operating (a process commonly known as a turnaround). These shutdowns typically take between 30 and 45 days. Catalysts generally need to be changed every three to six years depending on technology. Careful planning and scheduling is required to ensure that maintenance and repairs can be carried out during turnarounds. In addition, both scheduled and unscheduled shutdowns may occur between turnarounds. We prepare a long-term turnaround schedule that is updated annually for all of our production facilities.
The following table details the annual operating capacity and actual production at our facilities in 2024 and 2023:
Annual Operating Capacity(1) | 2024 Production | 2023 Production | |||||||||
| (000 tonnes/year) | (000 tonnes) | (000 tonnes) | |||||||||
| USA (Geismar) | 4,000 | 2,529 | 2,142 | ||||||||
Trinidad and Tobago (Methanex interest) (2) | 1,960 | 956 | 1,074 | ||||||||
New Zealand (3) | 1,720 | 670 | 1,381 | ||||||||
| Chile | 1,700 | 1,180 | 993 | ||||||||
| Egypt (50% interest) | 630 | 460 | 504 | ||||||||
| Canada (Medicine Hat) | 600 | 563 | 548 | ||||||||
| 10,610 | 6,358 | 6,642 | |||||||||
(1)The annual operating capacity of our production facilities may be higher or lower than original nameplate capacity as, over time, these figures have been adjusted to reflect ongoing operating efficiencies at these facilities. Actual production for a facility in any given year may be higher or lower than operating capacity due to a number of factors, including natural gas availability, feedstock composition, the age of the facility's catalyst, turnarounds and access to CO2 from external suppliers for certain facilities. We review and update the operating capacity of our production facilities on a regular basis based on historical performance.
(2)The operating capacity of Trinidad is made up of the Titan (100% interest) and Atlas (63.1% interest) plants. The Atlas plant is currently idle. (refer to the Natural Gas Supply – Trinidad and Tobago section below).
(3)The operating capacity of New Zealand is made up of the two Motunui facilities, one of which is idle.(refer to the Natural Gas Supply – New Zealand section below).
Refer to the Production Summary section of our 2024 MD&A for more information.
MARKETING
We sell methanol to customers globally through an extensive marketing and distribution system with marketing offices in North America (Dallas and Vancouver), Europe (Brussels), Asia Pacific (Hong Kong, Shanghai, Tokyo, Seoul and Beijing), South America (Santiago) and the Middle East (Dubai). Most of our customers are large global or regional petrochemical manufacturers or distributors.
We believe our ability to sell methanol from geographically dispersed production sites enhances our ability to serve major chemical and petrochemical producers as customers for whom reliability of supply and quality of service are important.
In addition to selling methanol that we produce at our own facilities, we also sell methanol that we purchase from other suppliers through methanol purchase agreements and on the spot market. This provides us with flexibility in our supply chain and allows us to reliably meet customer commitments.
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DISTRIBUTION AND LOGISTICS
All of our methanol production facilities are located adjacent to deepwater ports, except for Medicine Hat which mainly services the regional market via rail and truck. Methanol is transported from our coastal plants by pipeline to these ports for shipping. We currently own or manage a fleet of approximately 30 ocean-going vessels to ship this methanol. We lease or own in-region storage and terminal facilities in North America, Europe, South America and Asia Pacific. We also use barge, rail, pipelines and, to a lesser extent, truck transport in our delivery system.
To retain optimal flexibility in managing our shipping fleet, we have entered into short-term and long-term time charter agreements covering vessels with a range of capacities. We also ship methanol under contracts of affreightment and through spot arrangements. We use larger vessels as key elements in our supply chain to move product from our production facilities to storage facilities located in major ports and for direct delivery to some customers. We also use smaller vessels capable of entering into restricted ports to deliver directly to other customers.
The cost to distribute methanol to customers represents a significant component of our operating costs. These include costs for ocean shipping, storage and distribution. We focus on identifying initiatives to reduce costs, including optimizing the use of our shipping fleet, third-party backhaul arrangements and taking advantage of prevailing conditions in the shipping market by varying the type and term of ocean vessel contracts. We also look for opportunities to leverage our global asset position by entering into geographic product exchanges with other methanol producers to reduce distribution and transportation costs. We are continuously investigating opportunities to further improve the efficiency and cost-effectiveness of distributing methanol from our production facilities to customers.
Our production site in Trinidad and Tobago is ideally located to supply customers globally. Our plants in New Zealand primarily supply customers in the Asia Pacific region, but can also supply European, North American and South American markets when required. Our production site in Chile can supply all global regions due to its geographic location. Our Egypt plant primarily services the domestic Egypt market and our European markets but can also supply the Asia Pacific region. Our Medicine Hat plant serves our customer base in North America and the Geismar plants can serve customers across North America, Europe and the Asia Pacific region.
NATURAL GAS SUPPLY
General
Natural gas is the principal feedstock for producing methanol and it accounts for a significant portion of our operating costs. Accordingly, our results from operations depend in large part on the availability and security of supply and the price of natural gas. If, for any reason, we are unable to obtain sufficient natural gas for any of our plants on commercially acceptable terms or we experience interruptions in the supply of contracted natural gas, we could be forced to curtail production or shut down such plants, which could have an adverse effect on our results of operations and financial condition.
United States
With our new 1.8 million tonne Geismar 3 facility reaching commercial production in 2024, we now have three plants in Geismar, Louisiana with an annual operating capacity of 4.0 million tonnes.
We utilize a combination of fixed price financial hedges and fixed price physical gas supply agreements to manage natural gas price risk for our Geismar facilities. In the United States, we have fixed price gas supply contracts and hedges in place targeting minimum operating rate requirements of approximately 70% in the near-term, declining over time. The balance of our gas requirements are purchased at spot prices.
Trinidad and Tobago
Natural gas for our Titan plant is supplied by the National Gas Company of Trinidad and Tobago Limited ("NGC"), pursuant to a two-year take-or-pay contract that commenced in September 2024. The Titan plant successfully restarted operations in September 2024, having previously been idled in the first quarter of 2020. The natural gas sale agreement for Titan is a take-or-pay contract with the NGC, which purchases the natural gas from upstream gas producers. The contract has a U.S. dollar base and variable price components, where the variable portion is adjusted by a formula linked to methanol prices above a certain level.
The legacy natural gas agreement for our Atlas methanol production facility in Trinidad and Tobago, with our share of total production capacity being 1.1 million tonnes per year, expired in September 2024, after which the plant was idled.
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New Zealand
We have two plants located at Motunui in New Zealand with a total operating capacity of 1.7 million tonnes of methanol per year. In September 2024, we restructured our operations in New Zealand to support a one-plant operation, and idled one of the Motunui plants. A third plant located at nearby Waitara Valley was idled indefinitely in the first quarter of 2021. The plants were idled due to a lack of available gas supply.
We have agreements with various natural gas suppliers with terms that range in length up to 2029. All gas supply agreements in New Zealand are take-or-pay agreements and include U.S. dollar base and variable price components where the variable price component is adjusted by a formula linked to methanol prices above a certain level. We believe this pricing relationship enables New Zealand methanol production to be competitive at all points in the methanol price cycle. Certain contracts require the supplier to deliver a minimum amount of natural gas with additional volume dependent on the success of exploring and developing the related natural gas field. Supplier upstream development activities have not delivered the expected gas production results and have resulted in reduced gas quantities delivered under our contracts.
Chile
We have two long-term natural gas supply agreements for our two plants in Chile with each of Empresa Nacional del Petróleo ("ENAP") and YPF S.A. ("YPF"). As of 2024, gas agreements and gas export permits from Argentina provide for sufficient gas to allow for a two-plant operation in Chile during the southern hemisphere summer months. Both of these long-term supply agreements are subject to deliver-or-pay and take-or-pay provisions. In 2024, both plants operated at full capacity for seven months during the southern hemisphere summer, and one plant operated at close to minimum capacity production levels for the remaining five months of the year.
Our primary Chilean natural gas supplier, ENAP, has made significant investments over the past several years in the development of natural gas from unconventional reservoirs, which has resulted in stable gas deliveries from ENAP to our facilities. In August 2024, Methanex extended its gas supply agreement with ENAP until 2030. In August 2024 we extended our gas supply agreement with YPF securing gas until the end of 2027.
In addition, in 2024, we received natural gas from Argentina from four different natural gas suppliers pursuant to firm supply agreements from January through April and from September through December. Each of the four supply agreements were subject to deliver-or-pay and take-or-pay provisions. We have similar firm contracts for 2025 in place.
The price paid for natural gas for our Chilean facilities from our Chilean and Argentine suppliers is a U.S. dollar base price plus a variable price component that is adjusted by a formula linked to methanol prices above a certain level.
Egypt
We have a 25-year, take-or-pay natural gas supply agreement expiring in 2035 for the 1.3 million tonne per year methanol plant in Egypt in which we have a 50% equity interest. The price paid for gas is based on a U.S. dollar base price plus a variable price component that is adjusted by a formula linked to methanol prices above a certain level. Under the contract, the gas supplier is obligated to supply, and we are obliged to take or pay for, a specified annual quantity of natural gas. In addition, the natural gas supply agreement has a mechanism whereby we are partially compensated when gas delivery shortfalls in excess of a certain threshold occur. Natural gas is supplied to this facility from the same gas delivery grid infrastructure that supplies other industrial users in Egypt, as well as the general Egyptian population.
Canada
We have entered into fixed price contracts to supply 80-90% of our natural gas requirements for our Medicine Hat facility through 2031. The balance of our gas requirements is purchased under contracts at spot prices.
FOREIGN OPERATIONS
We have substantial operations and investments outside of North America, and as such we are affected by foreign political developments and federal, provincial, state and other local laws and regulations. We are subject to risks inherent in foreign operations, including loss of revenue, property and equipment as a result of expropriation; import or export restrictions; anti-dumping measures; nationalization, war, civil unrest, insurrection, acts of terrorism and other political risks; increases in duties, taxes and governmental royalties; renegotiation of contracts with governmental entities; as well as changes in laws or policies or other actions by governments that may adversely affect our operations. We are also subject to potential trade risks associated with geopolitical disputes between countries in which we operate.
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We derive a substantial portion of our revenue from production and sales by subsidiaries outside of Canada, and the payment of dividends or the making of other cash payments or advances by these subsidiaries to us may be subject to restrictions or exchange controls on the transfer of funds in or out of the respective countries or result in the imposition of taxes on such payments or advances. We have organized our foreign operations in part based on certain assumptions about various tax laws (including capital gains, withholding taxes and transfer pricing), foreign currency exchange and capital repatriation laws and other relevant laws of a variety of foreign jurisdictions. While we believe that such assumptions are reasonable, we cannot provide assurance that foreign taxation or other authorities will reach the same conclusion. Further, if such foreign jurisdictions were to change or modify such laws, we could suffer adverse tax and financial consequences.
Our wholly owned subsidiary, Methanex Chile SpA ("Methanex Chile"), owns two methanol plants on our Chilean production site. Chilean foreign investment regulations provide certain benefits and guarantees to companies that enter into a foreign investment contract ("DL 600 Contract") with Chile. Methanex Chile has entered into DL 600 Contracts, substantially identical in all matters material for Methanex Chile, for both plants. Under the DL 600 Contracts, Methanex Chile is authorized to remit from Chile, in United States dollars or any other freely convertible currency, all or part of its profits and its equity. The DL 600 Contracts provide that they cannot be amended or terminated except by written agreement.
RESPONSIBLE CARE & SUSTAINABILITY
As a member of the Chemistry Industry Association of Canada ("CIAC"), the American Chemistry Council ("ACC"), Asociación Gremial de Industriales Quimicos de Chile, Responsible Care New Zealand, European Chemical Industry Council, China Association of International Chemical Manufacturers, Japan Chemical Industry Association and Gulf Petrochemicals and Chemicals Association, we are committed to the Responsible Care® Ethic and Principles for Sustainability.
Responsible Care, a sustainability initiative recognized by the United Nations, is the umbrella under which we manage our business in relation to health, safety, the environment, community involvement, social responsibility, sustainability, security and emergency preparedness at each of our facilities and locations.
Accordingly, we have established policies, systems and procedures to promote and encourage the responsible development, manufacture, transportation, storage, handling, distribution and use of methanol and ultimate disposal of hazardous waste and residual chemical products so as to do no harm to human health and well-being, the environment and the communities in which we operate while striving to improve the environment and people’s lives.
Methanex’s Responsible Care and Social Responsibility (RC and SR) related policies and programs are based on CIAC’s RC Ethic and Principles for Sustainability and the CIAC RC Codes of Practice. Some of the countries where we operate have different standards than those applied in North America. Our policy is to adopt the more stringent of either Responsible Care practices or local regulatory or association requirements at each of our facilities.
Sound corporate governance is the foundation of our long-term success and the sustainability of our operations. Our corporate governance policies ensure that we have strong management and clear direction for all of Methanex’s business affairs. The application of Responsible Care begins with our Board of Directors, which has appointed a Responsible Care Committee, and extends throughout our organization.
The Board’s Responsible Care Committee provides oversight of the RC and SR program performance and related matters at the policy level. The Responsible Care Committee considers RC ethics, sustainability, safety (personal and process), health, environment, crisis management and communications, physical security, product stewardship, quality assurance management, and social responsibility. The executive leadership team has overall responsibility for establishing Methanex’s RC policies and programs, and ensuring that they align with the Board’s requirements and the Company’s business strategy. These global programs are directed and managed by the Vice President, Responsible Care who leads Methanex’s global Responsible Care function.
Methanex evaluates the performance of its RC and SR management system through internal and third-party external audit and assessment programs. The internal program includes ongoing in-region self-audits as well as global audits conducted by Methanex subject matter experts. Third-party verification of the performance of Methanex’s RC/SR program occurs through the CIAC RC verification process or the ACC RC 14001 certification process. The most recent CIAC RC re-verification was successfully completed in 2022.
Our overarching RC Ethic & Principles for Sustainability Purpose and Values statement sets out the Company’s commitment to RC and sustainability. We also have an established Health, Safety, Security, Environment, Quality Policy that includes the requirement that we operate our facilities in a manner that protects the safety and health of all employees, contractors, customers and the general public. It requires that we have systems in place to monitor and comply with all local safety, health
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and environmental regulations as well as internal standards, periodically audit performance and compliance, measure performance against key performance indicators, report and investigate incidents with the potential to cause harm to people or the environment and demonstrate continual improvement.
We have also adopted a number of risk assessment tools that are formally applied as part of our normal business processes to identify and mitigate current and future health and occupational safety, environmental and process safety-related risks. When incidents do occur, we have a formal incident investigation process to determine root causes and corrective actions to allow for effective mitigation as well as application of lessons learned throughout our organization.
As a natural extension of our RC ethic, we align our employee engagement and communications, community involvement and social investment strategies with our core values and corporate strategy. In alignment with our Stakeholder Relations Policy, the Company is committed to being accountable and responsive to our stakeholders. We proactively respond to any community concerns about the manufacture, storage, handling, transportation and disposal of our products and promptly provide information concerning any potential health or environmental hazard to the appropriate authorities, employees and all stakeholders. Furthermore, the Company is committed to positively contributing to and having an open, honest and proactive relationship with the communities where we have a significant presence; to having effective processes to identify and respond to community concerns; and to informing the community of risks associated with our operations.
One of the ways the Company maintains the highest standards of product care is by sharing methanol safe handling knowledge and best practices with key stakeholders involved in the methanol value chain including customers, distributors, logistics providers, emergency responders, industry associations and regulators.
We believe that Responsible Care helps us achieve safe and reliable operations, which in turn results in strong financial performance, effective and innovative minimization of environmental impacts and improved quality of life.
ENVIRONMENTAL MATTERS
The countries in which we operate and international and jurisdictional waters in which our vessels operate have laws, regulations, treaties and conventions in force to which we are subject, governing the environment and the management of natural resources as well as the handling, storage, transportation and disposal of hazardous or waste materials. We are also subject to laws and regulations governing emissions and the import, export, use, discharge, storage, disposal and transportation of toxic substances. The products we use and produce are subject to regulation under various health, safety and environmental laws. Non-compliance with these laws and regulations may give rise to compliance orders, fines, injunctions, civil liability and criminal sanctions.
Laws and regulations with respect to protecting the environment have become more stringent over time and may, in certain circumstances, impose absolute liability rendering a person liable for environmental damage without regard to negligence or fault on the part of such person. Such laws and regulations may also expose us to liability for the conduct of, or conditions caused by others or for our own acts even if we complied with applicable laws at the time such acts were performed. To date, environmental laws and regulations have not had a significant adverse effect on our capital expenditures, earnings or competitive position. However, operating petrochemical manufacturing plants and distributing methanol exposes us to risks in connection with compliance with such laws and we cannot provide assurance that we will not incur significant costs or liabilities in the future.
GHG Legislation
We generate GHG emissions, primarily as carbon dioxide ("CO2"), directly and indirectly through the production, distribution and use of methanol. GHG emissions are a byproduct of the development and extraction of hydrocarbons, including natural gas used as a feedstock in methanol production, as well as the methanol production process. GHG emissions are also generated when fuel is consumed during the global transport of methanol. The GHG Protocol Corporate Standard classifies a company’s GHG emissions into three ‘scopes’. Scope 1 emissions are direct emissions from owned or controlled sources. Scope 2 emissions are indirect emissions from the generation of purchased energy. Scope 3 emissions are all indirect emissions (not included in Scope 2) that occur in the value chain, including both upstream and downstream emissions.
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We monitor and manage our GHG emissions intensity for Scope 1 and Scope 2 emissions, defined as the equivalent quantity of CO2 released per unit of production or transported tonne, relating to both methanol equity production and our owned marine operations. The amount of GHG emissions generated by the methanol production process is highly dependent on a number of factors including the design of the methanol plant, plant reliability and availability of natural gas. Similarly, the distance of trade routes, volume of transported cargo, as well as ship technology and operating efficiency, influence the emissions intensity of our marine operations. Accordingly, GHG emissions may vary from year to year depending on the mix of production assets and vessels and their respective operations.
Under the Paris Agreement within the United Nations Framework Convention on Climate Change, many of the countries we operate in have agreed to put forth substantial efforts and commitments to reduce GHG emissions that they are implementing through GHG regulations that include carbon prices. We are currently subject to GHG regulations in New Zealand, Canada and Chile, while our production in the United States, Trinidad and Tobago, and Egypt is currently not subject to such regulations. These regulations result in additional costs to produce methanol. Many of our competitors produce methanol in countries with no imposed GHG regulations or carbon taxes and as such, further increases in regulations or carbon taxes in the countries in which we operate may negatively impact our competitive position within the methanol industry. In addition, as of January 2024, Waterfront Shipping is subject to the EU’s Emissions Trading System (ETS) for fifty percent of emissions from voyages where the point of origin or the point of destination is within the EU and 100 percent of emissions that occur for voyages between two EU ports and when ships are within EU ports. In 2025, Waterfront Shipping will need to purchase and surrender 70 percent of EU ETS credits for shipping emissions within the EU and 100 percent in 2026.
There are ongoing reviews and potential changes to government GHG regulations in countries where we have operations or conduct business, including potential carbon border adjustment mechanisms that could impact the efficient management of our global supply chain.
We cannot provide assurance that changes in existing or the introduction of new GHG regulations, carbon taxes, or other initiatives related to climate change in jurisdictions where we have operations or conduct business will not have an adverse impact on our results of operations and financial condition.
INSURANCE
The majority of our revenues are derived from the sale of methanol produced at our plants. Our business is subject to the normal hazards of methanol production operations that could result in damage to our plants. Under certain conditions, prolonged shutdowns of plants due to unforeseen equipment breakdowns, interruptions in the supply of natural gas, oxygen, or utilities, power failures, loss of port facilities or any other event, including any event of force majeure, could adversely affect our revenues and operating income. We maintain operational insurance, including business interruption, subject to certain deductibles, that we consider to be adequate under the circumstances. However, there can be no assurance that we will not incur losses beyond the limits or outside the coverage of such insurance. From time to time, various types of insurance for companies in the chemical and petrochemical industries have not been available on commercially acceptable terms or, in some cases, have been unavailable. There can be no assurance that in the future we will be able to maintain existing coverage, or that premiums will not increase substantially.
COMPETITION
Methanex is the largest producer and supplier of methanol, with approximately 11% of the global market demand in 2024, and is the only global supplier with a significant presence in Asia Pacific, Europe, North America and South America. Methanex has established itself as a clear methanol industry leader. Similar to other global commodities, the methanol industry is highly competitive. A supplier’s ability to withstand price competition and volatile market conditions will depend on several factors, with the most important being its position on the industry cost curve. This in turn depends on the relative cost and availability of natural gas or coal feedstock, and the efficiency of production facilities and distribution systems. Our methanol assets are competitively positioned on the industry cost curve. We manage our natural gas costs in two ways: through gas contracts linked to methanol price and through fixed price contracts. Our production facilities outside North America are largely underpinned by natural gas purchase agreements where the natural gas price is linked to methanol prices. This pricing relationship enables these facilities to be competitive throughout the methanol price cycle. In North America, we have fixed price natural gas supply contracts and financial hedges in place targeting minimum operating rate requirements of approximately 70% in the near term. Some of our competitors are not dependent on a single product for revenues, and some have greater financial resources. However, given our ability to service our customers globally, the reliability and cost-effectiveness of our distribution system and the enhanced service we provide customers, we believe we are well positioned to compete.
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EMPLOYEES
As at December 31, 2024, we had 1,415 employees.
RISK FACTORS
The risks relating to our business are described under the heading Risk Factors and Risk Management in our 2024 MD&A, and are incorporated in this document by reference. Any of those risks, as well as risks and uncertainties currently not known to us, could adversely affect our business, financial condition, results of operations or the market price of our securities.
DIVIDENDS
Dividends are payable to the holders of common shares of the Company ("Common Shares") if, as and when declared by our Board of Directors and in such amounts as the Board of Directors may, from time to time, determine. The Company’s current dividend policy is designed to return cash to shareholders while allowing the Company to retain financial flexibility appropriate for the historically cyclical nature of the methanol industry. The following table sets forth the amount of quarterly cash dividends paid by the Company on its Common Shares in 2022, 2023 and 2024:
| Record Date | Payment Date | Dividend per Share | ||||||
| December 17, 2024 | December 31, 2024 | $0.185 | ||||||
| September 16, 2024 | September 30, 2024 | $0.185 | ||||||
| June 14, 2024 | June 28, 2024 | $0.185 | ||||||
| March 14, 2024 | March 28, 2024 | $0.185 | ||||||
| December 15, 2023 | December 29, 2023 | $0.185 | ||||||
| September 16, 2023 | September 30, 2023 | $0.185 | ||||||
| June 16, 2023 | June 30, 2023 | $0.185 | ||||||
| March 17, 2023 | March 31, 2023 | $0.175 | ||||||
| December 17, 2022 | December 31, 2022 | $0.175 | ||||||
| September 16, 2022 | September 30, 2022 | $0.175 | ||||||
| June 16, 2022 | June 30, 2022 | $0.145 | ||||||
| March 17, 2022 | March 31, 2022 | $0.125 | ||||||
CAPITAL STRUCTURE
We are authorized to issue an unlimited number of Common Shares without nominal or par value and 25,000,000 preferred shares without nominal or par value ("Preferred Shares").
Holders of Common Shares are entitled to receive notice of and attend all annual and special meetings of shareholders and to one vote in respect of each Common Share held; receive dividends if, as and when declared by our Board of Directors; and participate in any distribution of the assets of the Company in the event of liquidation, dissolution or winding up.
Preferred Shares may be issued in one or more series and the Board of Directors may fix the designation, rights, restrictions, conditions and limitations attached to the Preferred Shares of each such series. Currently, there are no Preferred Shares outstanding.
Our bylaws provide that at any meeting of our shareholders a quorum shall be two persons present in person, or represented by proxy, holding Common Shares representing not less than 25% of the votes entitled to be cast at the meeting. Nasdaq Global Select Market listing standards require a quorum for shareholder meetings to be not less than 33-1/3% of a company’s outstanding voting shares. As a foreign private issuer and because our quorum requirements are consistent with practices in Canada, we are exempt from the quorum requirement under the Nasdaq Listing Rules.
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RATINGS
The following information relating to Methanex's credit ratings is provided as it relates to Methanex's financing costs, liquidity and operations. Credit ratings affect Methanex's cost and ability to obtain short-term and long-term financing and to engage in certain business activities on a cost-effective basis. A negative change in Methanex's current rating score and/or rating outlook could adversely affect Methanex's future cost of financing and its access to sources of liquidity and capital. In addition, changes in credit ratings may affect Methanex's ability to, and the associated costs of (i) entering into ordinary course derivative or hedging transactions, and (ii) entering into and maintaining ordinary course contracts with customers and suppliers on acceptable terms.
The following table sets forth the ratings assigned to Methanex and certain of its subsidiaries by S&P Global Ratings ("S&P"), Moody’s Investors Service, Inc. ("Moody’s") and Fitch Ratings, Inc. ("Fitch").
Entity | Debt Rated/Outlook | S&P(1) | Moody’s(2) | Fitch(3) | ||||||||||
Methanex Corporation | Issuer Rating | BB | n/a(2) | BB+ | ||||||||||
Senior Unsecured Notes | BB | Ba1 | BB+ | |||||||||||
| Ratings Outlook | Stable | Under Review (4) | Stable | |||||||||||
| Last Reviewed | September 9, 2024 | September 13, 2024 | November 19, 2024 | |||||||||||
Methanex US Operations Inc.(5) | Issuer Rating | n/a(6) | n/a(2) | BB+ | ||||||||||
| Senior Unsecured Notes | BB | Ba2 | BB+ | |||||||||||
| Ratings Outlook | Stable | Stable | Stable | |||||||||||
| Last Reviewed | November 19, 2024 | November 19, 2024 | November 19, 2024 | |||||||||||
(1) S&P long-term debt ratings are on a rating scale that ranges from AAA to D, which represents the range from highest to lowest quality. According to the S&P rating system, issuers and debt securities rated BB are less vulnerable in the near term relative to other lower-rated obligations, however, they face major ongoing uncertainties in periods of adverse business, financial or economic conditions. The ratings from AA to CCC may be modified by the addition of a plus (+) or minus (-) sign to show relative standing within the major rating categories.
(2) Moody’s long-term debt ratings are on a rating scale that ranges from Aaa to C, which represents the range from highest to lowest quality. According to the Moody’s rating system, debt securities rated Ba are judged to have speculative elements and are subject to substantial credit risk. Moody’s applies numerical modifiers 1, 2 and 3 in each major rating category from Aa through Caa in its corporate bond rating system. The modifier 1 indicates that the issue ranks in the higher end of its major rating category, the modifier 2 indicates a mid-range ranking and the modifier 3 indicates that the issue ranks in the lower end of its major rating category. Moody's rates Methanex's debt securities and does not provide an Issuer Credit Rating.
(3) Fitch long-term debt ratings are on a rating scale that ranges from AAA to D, which represents the range from highest to lowest quality. According to the Fitch rating system, issuers and debt securities rated BB indicate an elevated vulnerability to default risk, particularly in the event of adverse changes in business or economic conditions over time; however, business or financial flexibility exists that supports the servicing of financial commitments. The ratings from AA to CCC may be modified by the addition of a plus (+) or minus (-) sign to show relative standing within the major rating categories.
(4) On September 13, 2024, Moody’s placed the Company’s credit rating on review for downgrade following its September 8, 2024 announcement that the Company entered into an agreement to acquire OCI Global's international methanol business. Please refer to Moody’s rating update published on September 13, 2024 for more detail.
(5) On November 19, 2024, Methanex issued new $600 million 2032 senior notes through its indirectly wholly-owned subsidiary, Methanex US Operations Inc., to partially fund the acquisition of OCI Global's international methanol business. S&P, Moody’s and Fitch published issuer- and/or issue-level credit rating opinions for Methanex US Operations Inc.
(6) S&P assigned an issue-level rating for the new $600 million 2032 senior notes but did not publish an issuer rating for Methanex US Operations Inc.
The rating agencies regularly evaluate Methanex, and their ratings of Methanex are based on a number of factors, including Methanex’s financial strength and factors not entirely within Methanex’s control, including conditions affecting the methanol industry generally and the wider state of the economy.
The foregoing ratings should not be construed as a recommendation to buy, sell or hold any securities, as such ratings do not comment as to market price or suitability for a particular investor. There is no assurance that any rating will remain in effect for any given period of time or that any rating will not be revised or withdrawn entirely by a rating agency in the future if, in its judgment, circumstances so warrant. If any such rating is so revised or withdrawn, we are under no obligation to update this AIF.
During the last two years, Methanex has paid each of the rating agencies its customary fees in connection with the provision of the above ratings.
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MARKET FOR SECURITIES
Our Common Shares are listed on the Toronto Stock Exchange in Canada (trading symbol: MX) and on the Nasdaq Global Select Market in the U.S. (trading symbol: MEOH). The following table sets out the market price ranges and trading volumes of our Common Shares on the Toronto Stock Exchange as well as on other Canadian and US equity marketplaces, including exchanges and alternative trading systems, for each month of our most recently completed financial year (January 1, 2024, through December 31, 2024).
2024 Trading Volumes(1) | ||||||||||||||||||||
| Trading Symbol: MX | Trading Symbol: MEOH | Total Volume | ||||||||||||||||||
| The Toronto Stock Exchange | Other Canadian Trading | Nasdaq Global Select Market and Other US Trading | ||||||||||||||||||
| Month | High (CDN$) | Low (CDN$) | Volume | Volume | Volume | |||||||||||||||
| January | 63.47 | 57.82 | 1,487,517 | 916,444 | 4,178,767 | 6,582,728 | ||||||||||||||
| February | 63.81 | 56.23 | 2,496,144 | 1,684,661 | 7,708,420 | 11,889,225 | ||||||||||||||
| March | 61.89 | 56.00 | 1,610,240 | 1,053,579 | 4,809,339 | 7,473,158 | ||||||||||||||
| April | 69.85 | 60.23 | 2,826,081 | 1,609,064 | 8,942,246 | 13,377,391 | ||||||||||||||
| May | 74.25 | 64.99 | 1,944,710 | 1,090,619 | 5,626,912 | 8,662,241 | ||||||||||||||
| June | 73.15 | 65.02 | 1,995,271 | 958,996 | 3,549,159 | 6,503,426 | ||||||||||||||
| July | 73.18 | 63.90 | 1,877,393 | 1,098,275 | 4,711,603 | 7,687,271 | ||||||||||||||
| August | 67.29 | 55.80 | 2,251,468 | 1,286,220 | 7,566,137 | 11,103,825 | ||||||||||||||
| September | 62.48 | 49.21 | 3,468,948 | 2,793,648 | 8,796,455 | 15,059,051 | ||||||||||||||
| October | 61.83 | 54.01 | 2,668,407 | 1,459,761 | 6,774,296 | 10,902,464 | ||||||||||||||
| November | 66.12 | 53.93 | 2,527,081 | 1,485,711 | 6,562,157 | 10,574,949 | ||||||||||||||
| December | 72.00 | 64.24 | 2,747,643 | 1,737,635 | 7,395,522 | 11,880,800 | ||||||||||||||
(1) Source: Bloomberg
DIRECTORS AND EXECUTIVE OFFICERS
As at December 31, 2024, the directors and executive officers of the Company owned, controlled or directed, directly or indirectly, 346,007 Common Shares, representing approximately 0.5% of the outstanding Common Shares as at December 31, 2024.
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The following tables set forth the names and places of residence of the current directors and executive officers of the Company, the offices held by them in the Company, their current principal occupations, their principal occupations during the last five years and, in the case of the directors, the month and year in which they became directors:
| Name and Municipality of Residence | Office | Principal Occupations and Positions During the Last Five Years | Director Since(17) | ||||||||
| ARNELL, DOUG West Vancouver British Columbia Canada | Director and Chair of the Board | Chief Executive Officer of Cedar LNG LLC(5) since June 2021 and President and Chief Executive Officer of Helm Energy Advisors Inc.(6) since March 2015. | October 2016 | ||||||||
BERTRAM, JIM(2)(3) Calgary, Alberta Canada | Director | Corporate Director. | October 2018 | ||||||||
DOBSON, PAUL(1)(3) Naples, Florida USA | Director | Chief Financial Officer of EVgo Inc.(7) since October 2024. Prior to that Senior Vice President and Chief Financial Officer of Ballard Power Systems(8) from March 2021 to September 2024. Prior thereto Acting President and Chief Executive Officer of Hydro One Limited(9) from July 2018 to May 2019. | April 2019 | ||||||||
HOWE, MAUREEN(1)(2) Vancouver, British Columbia Canada | Director | Corporate Director. | June 2018 | ||||||||
KOSTELNIK, ROBERT(3)(4) Fulshear, Texas USA | Director | Corporate Director. Principal of GlenRock Recovery Partners, LLC(10) since February 2012. | September 2008 | ||||||||
O'DONOGHUE, LESLIE(1)(3) Calgary, Alberta Canada | Director | Corporate Director. Executive Vice President and Adviser to the Chief Executive Officer of Nutrien Ltd.(11) from June 2019 to December 2019. | April 2020 | ||||||||
PERREAULT, ROGER(1)(4) Six Mile, South Carolina USA | Director | Corporate Director. President and CEO of UGI Corporation(12) from 2021 to 2023; prior thereto Executive Vice President, Global LPG of UGI Corporation from 2018 to 2021. | April 2024 | ||||||||
RODGERS, KEVIN(2)(3) London UK | Director | Corporate Director. | July 2019 | ||||||||
SAMPSON, JOHN(3)(4) Midland, Michigan USA | Director | Senior Vice President, Operations, Manufacturing and Engineering of Dow Inc.(13) since 2020; prior thereto Executive Vice President, Business Operations of Olin Corporation(14) from 2019 to 2020. | October 2023 | ||||||||
| SUMNER, RICH North Vancouver British Columbia Canada | Director, President and Chief Executive Officer | President and Chief Executive Officer of the Company since January 2023. Prior thereto Senior Vice President, Global Marketing and Logistics of the Company since October 2021; prior thereto Regional President, Marketing and Logistics, Asia Pacific of the Company since February 2019. | January 2023 | ||||||||
WALKER, MARGARET(1)(4) Austin, Texas USA | Director | Corporate Director. Owner of MLRW Group, LLC(15) since 2011. | April 2015 | ||||||||
WARMBOLD, BENITA(1)(2) Toronto, Ontario Canada | Director | Corporate Director. | February 2016 | ||||||||
YANG, XIAOPING(2)(4) Henderson, Nevada USA | Director | Corporate Director. President and Chair of BP China(16) from November 2016 to September 2020. | January 2022 | ||||||||
(1)Member of the Audit, Finance and Risk Committee.
(2)Member of the Corporate Governance Committee.
(3)Member of the Human Resources Committee.
(4)Member of the Responsible Care Committee.
(5)Cedar LNG LLC is developing an LNG export terminal in Northwestern British Columbia.
(6)Helm Energy Advisors, Inc. is a private company which provides advisory services to the global energy sector.
(7)EVgo Inc. installs and operates public, fast-charging electric vehicle infrastructure.
(8)Ballard Power Systems is a global provider of innovative clean energy and fuel cell solutions.
(9)Hydro One Limited is a major transmission and distribution provider in Ontario, Canada.
(10)GlenRock Recovery Partners, LLC is a company that facilitates the sale of non-fungible hydrocarbons in the United States.
(11)Nutrien Ltd. is a Canadian fertilizer company, and is the world's largest provider of crop inputs, services and solutions.
(12)UGI Corporation is a distributor and marketer of energy products and services in the United States and Europe.
(13)Dow Inc. is a producer and supplier of raw materials for products in a wide variety of industries.
(14)Olin Corporation is a global manufacturer and distributor of chemical products.
(15)MLRW Group Inc. is a consulting firm focusing on working with companies to improve capital investment outcomes and to improve overall safety performance.
(16)BP is a multinational energy company.
(17)The directors of the Company are elected each year at the Annual General Meeting of the Company and hold office until the close of the next Annual General Meeting or until their successors are elected or appointed.
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| Name and Municipality of Residence | Office | Principal Occupations and Positions During the Last Five Years | ||||||
| ALLARD, MARK West Vancouver, British Columbia Canada | Senior Vice President, Low Carbon Solutions | Senior Vice President, Low Carbon Solutions of the Company since January 2023; prior thereto Vice President, North America of the Company since January 2019. | ||||||
| BOYD, BRAD West Vancouver, British Columbia Canada | Senior Vice President, Corporate Resources | Senior Vice President, Corporate Resources of the Company since January 2018. | ||||||
DELBARRE, KARINE Dallas, Texas USA | Senior Vice President, Global Marketing and Logistics | Senior Vice President, Global Marketing and Logistics of the Company since January 2023; prior thereto Vice President, Marketing and Logistics, North America of the Company since February 2019. | ||||||
| MALONEY, Kevin West Vancouver, British Columbia Canada | Senior Vice President, Corporate Development | Senior Vice President, Corporate Development of the Company since January 2023; prior thereto Vice President, Corporate Development of the Company since April 2018. | ||||||
PARRA, GUSTAVO Santiago, Chile | Senior Vice President, Manufacturing | Senior Vice President, Manufacturing of the Company since January 2023; prior thereto Vice President, Manufacturing Strategy and Planning of the Company since September 2019. | ||||||
| PRICE, KEVIN Vancouver, British Columbia Canada | Senior Vice President, General Counsel & Corporate Secretary | Senior Vice President, General Counsel and Corporate Secretary of the Company since January 2023; prior thereto General Counsel and Corporate Secretary of the Company since March 2016. | ||||||
| RICHARDSON, DEAN Vancouver, British Columbia Canada | Senior Vice President, Finance and Chief Financial Officer | Senior Vice President, Finance and Chief Financial Officer of the Company since February 2023; prior thereto Vice President, Corporate Finance of the Company since January 2022; prior thereto Managing Director, New Zealand of the Company since April 2018. | ||||||
INTEREST OF MANAGEMENT AND OTHERS IN MATERIAL TRANSACTIONS
Since the start of our most recently completed financial year, and for the three most recently completed financial years, no director or executive officer of the Company, and no person or company that beneficially owns, controls or directs, directly or indirectly, more than 10% of the Company’s voting securities, or any associate or affiliate of such persons, has had any material interest in any transaction involving the Company.
EXPERTS
Our Independent Registered Public Accounting Firm is KPMG LLP (“KPMG”), who prepared the Report of the Independent Registered Public Accounting Firm dated March 7, 2025 with respect to the Company’s consolidated financial statements as at December 31, 2024 and 2023, and for the years ended December 31, 2024 and 2023, and the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024. KPMG has confirmed that they are independent with respect to the Company 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 the Company under all relevant U.S. professional and regulatory standards.
LEGAL PROCEEDINGS
The Board of Inland Revenue of Trinidad and Tobago ("the "BIR") has audited and issued assessments against our 63.1% owned joint venture, Atlas, in respect of the 2005 to 2017 financial years. All subsequent tax years remain open to assessment. The assessments relate to the pricing arrangements of certain long-term fixed-price sales contracts with affiliates that commenced in 2005 and continued with affiliates through 2014 and with an unrelated third party through 2019. The long-term fixed-price sales contracts with affiliates were established as part of the formation of Atlas and management believes these were reflective of market considerations at that time.
During the periods under assessment and continuing through 2014, approximately 50% of Atlas-produced methanol was sold under these fixed-price contracts. From late 2014 through 2019 fixed-prices sales to an unrelated third party represented approximately 10% of Atlas-produced methanol. Atlas had partial relief from corporation income tax until late July 2014.
The Company believes it is impractical to disclose a reasonable estimate of the potential contingent liability due to the wide range of assumptions and interpretations implicit in the assessments.
The Company has lodged objections to the assessments. No deposits have been required to lodge objections. Although there can be no assurance that these tax assessments will not have a material adverse impact, based on the merits of the case and advice from legal counsel, we believe our position should be sustained, that Atlas has filed its tax returns and paid applicable taxes in compliance with Trinidadian tax law, and as such has not accrued for any amounts relating to these assessments. Contingencies
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inherently involve the exercise of significant judgment, and as such the outcomes of these assessments and the financial impact to the Company could be material.
During 2024, the Trinidad tax court issued a ruling in the Company's favour. At present, the BIR is reviewing whether to proceed with an appeal and should it decide to proceed, the Company will continue to defend its position. We anticipate the resolution of this matter through the court systems may be lengthy and, at this time, cannot predict a date as to when we expect this matter to be ultimately resolved.
AUDIT COMMITTEE INFORMATION
The Audit Committee Charter
The Audit, Finance and Risk Committee (the "Audit Committee") is appointed by the Board to assist the Board in fulfilling its oversight responsibility relating to: the integrity of the Company’s financial statements; the financial reporting process; the systems of accounting and financial controls; the professional qualifications and independence of the Company's external auditors; the performance of the internal and external auditors; risk management processes; financing plans; and compliance by the Company with ethics policies and legal and regulatory requirements.
The Audit Committee’s mandate sets out its responsibilities and duties. A copy of the Committee’s mandate is attached here as Appendix "A".
Composition of the Audit Committee
The Audit Committee is comprised of five directors: Benita Warmbold (Chair), Paul Dobson, Maureen Howe, Leslie O'Donoghue, Roger Perreault and Margaret Walker. Each Audit Committee member is "independent" and "financially literate" as determined in accordance with Canadian National Instrument 52-110 - Audit Committees, and is also "independent" as determined under each of Rule 10A-3 under the United States Securities Exchange Act of 1934, as amended (the "Exchange Act"), and Nasdaq Listing Rule 5605(a). Ms. Warmbold is currently designated as the "audit committee financial expert" (as that term is defined in paragraph (8)(b) of General Instruction B to Form 40-F under the Exchange Act). The U.S. Securities and Exchange Commission has indicated that the designation of a director as an audit committee financial expert does not make such director an "expert" for any other purpose, impose any duties, obligations or liability on such director that are greater than those imposed on members of the Audit Committee and Board who do not carry this designation or affect the duties, obligations or liability of any other member of the Audit Committee or the Board.
Relevant Education and Experience
The following is a brief summary of the education and experience 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, including any education or experience that has provided the member with an understanding of the accounting principles we use to prepare our annual and interim financial statements.
Ms. Benita Warmbold
Ms. Warmbold is a corporate director and former Senior Managing Director and Chief Financial Officer of the Canada Pension Plan Investment Board ("CPPIB"). CPPIB is a professional investment management organization responsible for investing funds on behalf of the Canada Pension Plan. Over her nine years at CPPIB, Ms. Warmbold was responsible for finance, risk, tax, internal audit, legal, technology, data and investment operations. Prior to joining CPPIB, Ms. Warmbold held leadership positions with Northwater Capital Management Inc., Canada Development Investment Corporation and KPMG LLP.
Ms. Warmbold holds a bachelor of commerce (honours) degree from Queen’s University, is a chartered professional accountant and is a Fellow of the Institute of Chartered Accountants of Ontario. She is also a Fellow of the Institute of Corporate Directors and has been granted their ICD.D .
Ms. Warmbold serves on the board of the Bank of Nova Scotia and chairs their Audit and Conduct Review Committee and is a designated financial expert. She is also a director of AtkinsRéalis and is a former Chair of their Audit and Risk Committee.
Ms. Warmbold has served on the Audit Committee since February 2016 and has been Chair of the Audit Committee since April 2018.
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Mr. Paul Dobson
Mr. Dobson has been Chief Financial Officer of EVgo Inc. since October 2024. EVgo installs and operates public, fast-charging electric vehicle infrastructure. Prior to that he was Senior Vice President, Chief Financial Officer of Ballard Power Systems ("Ballard") from March 2021 to September 2024. Ballard is a global provider of innovative clean energy and fuel cell solutions. From July 2018 to May 2019 Mr. Dobson was Acting President and Chief Executive Officer of Hydro One Limited, a major transmission and distribution provider in Ontario, Canada, and prior to that was Chief Financial Officer of Hydro One Limited from March 2018. Mr. Dobson also served as Chief Financial Officer of Direct Energy Ltd. in Houston, Texas, and held senior leadership positions in finance across the Centrica Group, the parent company of Direct Energy.
Mr. Dobson holds a bachelor of arts in management accounting (honours) from the University of Waterloo as well as an MBA from the University of Western Ontario. He is a chartered professional accountant and a certified management accountant.
Mr. Dobson has served on the Audit Committee since April 2019.
Ms. Maureen Howe
Ms. Howe is a corporate director. From 1996 to 2008 she was Managing Director of RBC Capital Markets specializing in the area of energy infrastructure, which included power generation, transmission and distribution, oil and gas transmission and distribution, gas processing and alternative energy. Prior to joining RBC Capital Markets, Ms. Howe held finance positions in the utility industry, investment banking and portfolio management.
Ms. Howe holds a bachelor of commerce (honours) from the University of Manitoba and a Ph.D. in Finance from the University of British Columbia.
Ms. Howe is a director and Audit Committee chair of both Pembina Pipeline Corporation and Freehold Royalties Ltd.
Ms. Howe has served on the Audit Committee since June 2018.
Ms. Leslie O'Donoghue
Ms. O'Donoghue is a corporate director. She was Executive Vice President and Advisor to the Chief Executive Officer of Nutrien Ltd. ("Nutrien") from June 2019 until her retirement in December 2019. Nutrien is a Canadian fertilizer company and is the world's largest provider of crop inputs, services and solutions. Ms. O'Donoghue was the Executive Vice President, Chief Strategy and Business Development Officer of Nutrien from January 2018 to June 2019, and prior to this she was Executive Vice President, Corporate Development and Strategy and Chief Risk Officer of Agrium Inc. (Nutrien's predecessor company) from 2012 to 2017.
Through Ms. O’Donoghue’s experience at Nutrien and from serving on other audit committees, she has gained an understanding of accounting and financial reporting, including internal controls and procedures for financial reporting.
Ms. O'Donoghue holds a bachelor of arts (economics) degree from the University of Calgary and a LLB, from Queen's University.
Ms. O'Donoghue is a director of Pembina Pipeline Corporation and serves on their Audit Committee.
Ms. O'Donoghue has served on the Audit Committee since April 2021.
Mr. Roger Perreault
Mr. Perreault is a corporate director. He served most recently at UGI Corporation from 2015 to 2023. He was President & CEO from 2021 to 2023, Executive Vice President, Global LPG from 2018 to 2021 and President, UGI International from 2015 to 2018. UGI Corporation is a distributor and marketer of energy products and services in the United States and Europe. Prior to this, Mr. Perreault held a variety of senior management positions in international and North American natural gas and industrial gases industries.
Through Mr. Perreault’s experience as President and Chief Executive Officer of UGI Corporation, he has an understanding of accounting and financial reporting, including internal controls and procedures for financial reporting.
Mr. Perreault holds a bachelor of science in Chemical Engineering from Toronto Metropolitan University (formerly known as Ryerson University) in Toronto, Ontario and a Graduate Diploma of Management (Applied) from McGill University in
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Montreal. He also completed the International Development Program at INSEAD and graduated from the Advanced Management Program at INSEAD in Fontainebleau, France in 2014.
Mr. Perreault has served on the Audit Committee since April 2024.
Ms. Margaret Walker
Ms. Walker has been the owner of MLRW Group, LLC since January 2011. MLRW Group, LLC is a consulting firm focusing on working with companies to improve capital investment outcomes and to improve overall safety performance. From 2004 until her retirement in December 2010, Ms. Walker was Vice President of Engineering & Technology for The Dow Chemical Company (“Dow Chemical”). Prior to this, Ms. Walker held other senior positions with Dow Chemical including Senior Leader in Manufacturing & Engineering and Business Director of Contract Manufacturing. Dow Chemical provides chemical, plastic and agricultural products and services.
Through Ms.Walker’s experiences at Dow Chemical and from serving on other audit committees, she has gained an understanding of risk, internal audit, accounting and finance reporting, including financing of large capital projects. In addition she has a CERT Certificate in Cybersecurity Oversight.
Ms. Walker holds a bachelor of chemical engineering from Texas Tech University, located in Lubbock, Texas. In 2018 she became a Board Leadership Fellow of the National Association of Corporate Directors ("NACD") and in 2021 became NACD Directorship Certified.
Ms. Walker also serves on the board of ioneer Ltd.
Ms. Walker has served on the Audit Committee since April 2024.
Pre-Approval Policies and Procedures
The Audit Committee annually reviews and approves the terms and scope of the external auditors’ engagement. The Audit Committee oversees the Audit and Non-Audit Pre-Approval Policy, which sets forth the procedures and the conditions by which permissible non-audit services proposed to be performed by KPMG LLP are pre-approved in order to mitigate the risk of non-audit services impacting the auditor’s independence. The Audit Committee has delegated to the Chair of the Audit Committee pre-approval authority for any services not previously approved by the Audit Committee. All such services approved by the Chair of the Audit Committee are subsequently reviewed by the Audit Committee.
All non-audit service engagements, regardless of the cost estimate, must be coordinated and approved by the Chief Financial Officer of the Company to further ensure that adherence to this policy is monitored.
Audit and Non-Audit Fees Billed by the Independent Auditors
KPMG LLP’s global fees relating to the years ended December 31, 2024 and December 31, 2023 are as follows:
| US$000s | 2024 | 2023 | ||||||
| Audit Fees | 2,979 | 2,415 | ||||||
| Audit-Related Fees | 155 | 160 | ||||||
| Tax Fees | 203 | 165 | ||||||
| All Other Fees | — | — | ||||||
| Total | 3,337 | 2,740 | ||||||
Each fee category is described below.
Audit Fees
Audit fees for professional services rendered by the external auditors for the audit of the Company’s consolidated financial statements; statutory audits of the financial statements of the Company’s subsidiaries; quarterly reviews of the Company’s financial statements; consultations as to the accounting or disclosure treatment of transactions reflected in the financial statements; and services associated with registration statements, prospectuses, periodic reports and other documents filed with securities regulators.
Audit fees for professional services rendered by the external auditors for the audit of the Company’s consolidated financial statements were in respect of an "integrated audit" performed by KPMG LLP globally. The integrated audit encompasses an
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opinion on the fairness of presentation of the Company’s financial statements as well as an opinion on the effectiveness of the Company’s internal controls over financial reporting.
Audit-Related Fees
Audit-related fees for professional services rendered by the auditors for financial audits of employee benefit plans; procedures and audit or attest services not required by statute or regulation; and consultations related to the accounting or disclosure treatment of other transactions.
Tax Fees
Tax fees for professional services rendered for tax compliance, including the review of tax returns; assistance in completing routine tax schedules and calculations; review of transfer pricing and indirect tax items.
Other Fees
There were no other fees in 2024 and 2023.
TRANSFER AGENT AND REGISTRAR
Our principal transfer agent for our Common Shares is TSX Trust Company at its offices in Vancouver, British Columbia. Our co-transfer agent in the United States for our Common Shares is Equiniti Trust Company, LLC at its offices in New Jersey.
MATERIAL CONTRACTS
Other than those contracts entered into during the normal course of business, the only material contracts that were entered into before December 31, 2024 and after January 1, 2002, that are still in effect, and which are required to be filed with Canadian securities regulatory authorities pursuant to applicable securities laws, are (i) the second 2024 amended and restated credit agreement dated for reference October 29, 2024, among the Company and Methanex US Operations Inc., as borrowers, Royal Bank of Canada, as agent bank, and the financial institutions party thereto as lenders (the “Credit Agreement”), (ii) the equity purchase agreement dated as of September 8, 2024 entered into among, inter alia, the Company and OCI N.V. relating to the purchase of OCI’s international methanol business (the “OCI Purchase Agreement”) and (iii) the indenture dated as of November 22, 2024, among the Company, as parent guarantor, Methanex US Operations Inc. and the Bank of New York Mellon, as trustee, as supplemented by the first supplemental indenture dated as of November 22, 2024 (collectively, the Indenture"). The Credit Agreement and the Indenture are described above in “Three-Year History – 2024” and the OCI Purchase Agreement is described above in “Development of the Business and Corporate Strategy”.
CONTROLS AND PROCEDURES
Our disclosure controls and procedures are described under the heading Controls and Procedures in our 2024 MD&A and are incorporated in this AIF by reference.
CODE OF ETHICS
We have a written code of ethics that applies to our directors, officers and employees, including our principal executive officer, principal financial officer and principal accounting officer. A copy of our code, entitled "Code of Business Conduct" can be found on our website at www.methanex.com or upon request from the Corporate Secretary at the address below under the heading Additional Information.
ADDITIONAL INFORMATION
Additional information relating to the Company, including directors’ and officers’ remuneration and indebtedness, principal holders of the Company’s securities and securities authorized for issuance under equity compensation plans, is contained in our Information Circular dated March 6, 2025, relating to our Annual General Meeting that will be held on May 1, 2025.
Additional financial information about the Company is provided in the Company’s financial statements for the year ended December 31, 2024, and in our 2024 MD&A.
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Copies of the documents referred to above are available on the Canadian Securities Administrators’ SEDAR+ website at www.sedarplus.ca and may also be obtained upon request from:
Methanex Corporation
Kevin Price
Senior Vice President, General Counsel and Corporate Secretary
1800 Waterfront Centre
200 Burrard Street
Vancouver, British Columbia V6C 3M1
Telephone: 604 661 2600
Facsimile: 604 661 2602
Additional information relating to the Company may be found on the Canadian Securities Administrators’ SEDAR+ website at www.sedarplus.ca, on the United States Securities and Exchange Commission’s EDGAR website at www.sec.gov and on our website at www.methanex.com.
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APPENDIX "A"
METHANEX CORPORATION
AUDIT, FINANCE AND RISK COMMITTEE MANDATE
A committee of the directors to be known as the “Audit, Finance and Risk Committee” (hereinafter referred to as the “Committee”) is hereby established.
A.PURPOSE
The Committee is appointed by the Board of Directors (the “Board”) to assist the Board in fulfilling its oversight responsibility relating to: the integrity of the Corporation’s financial statements; the financial reporting process; the systems of accounting and financial controls; the professional qualifications and independence of the Corporation’s external auditor; the performance of the external and internal auditors; risk management processes; financing plans; and compliance by the Corporation with ethics policies and legal and regulatory requirements.
The Committee’s role is one of oversight. It is the responsibility of the Corporation’s management to plan audits and to prepare consolidated financial statements in accordance with applicable generally accepted accounting principles (“GAAP”), and it is the responsibility of the Corporation’s external auditor to audit these financial statements. Therefore, each member of the Committee, in exercising their business judgment, shall be entitled to rely on the integrity of those persons and organizations within and outside the Corporation from whom they receive information and on the accuracy of the financial and other information provided to the Committee by such persons or organizations. The Committee does not provide any expert or other special assurances as to the Corporation’s financial statements or any expert or professional certification as to the work of the Corporation’s external auditor.
B. STRUCTURE
1. The Committee shall be composed of a minimum of three directors.
2. The members of the Committee shall be appointed or reappointed at the organizational meeting of the Board concurrent with each Annual General Meeting of the shareholders of the Corporation. Each member of the Committee shall continue to be a Committee member until a successor is appointed, unless they resign or are removed by the Board or cease to be a director of the Corporation. Where a vacancy occurs at any time in the membership of the Committee, it may be filled by the Board and shall be filled by the Board if the membership of the Committee is less than three directors as a result of the vacancy.
3. Each member of the Committee shall meet the independence and financial literacy requirements of the Corporation’s Corporate Governance Principles and the applicable rules and regulations of the stock exchanges on which the Corporation is listed, the U.S. Securities and Exchange Commission (the “SEC”) and the Canadian Securities Administrators (collectively, the “Applicable Rules”), and at least one member of the Committee shall qualify as an “audit committee financial expert” in accordance with the rules of the SEC.
4. The Board shall appoint a Chair from among the Committee members and the Chair shall set the agendas for Committee meetings. If the Chair of the Committee is not present at any meeting of the Committee, the Chair of the meeting shall be chosen by the Committee from among the members present. The Chair presiding at any meeting of the Committee has a deciding vote in the case of deadlock. The Committee shall also appoint a Secretary who need not be a director.
C. MEETINGS
1.The Committee shall meet at least quarterly. The time and place of Committee meetings and the procedure at such meetings shall be determined from time to time by Committee members, provided that:
a.a quorum for meetings shall be a majority of the members of the Committee, present in person or by tele- or video-conference that permits all persons participating in the meeting to communicate with each other;
b.notice of the time and place of every meeting shall be given in writing, by electronic transmission or otherwise, to each member of the Committee and the external auditor of the Corporation at least 24 hours prior to the time fixed for such meeting, provided, however, that a member may in any manner waive notice of a meeting, and attendance of a member at the 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;
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c.the Committee shall, at least annually, meet with the Chief Financial Officer without other members of management present;
d.each regular meeting of the Committee shall conclude with a session without any members of management present;
e.the external auditor shall be entitled to attend each meeting at the Corporation’s expense;
f.a meeting of the Committee may be called by the Secretary of the Committee on the direction of the Chair or any other member of the Committee, the Chief Executive Officer of the Corporation or the external auditor; and
g.notwithstanding the provisions of this paragraph, the Committee has the right to request any officer or employee of the Corporation or the Corporation’s outside counsel or external auditor to be present or not present at any part of the Committee meeting.
2. The Committee shall report to the Board following each meeting with respect to its activities and such recommendations as the Committee deems appropriate. The report may take the form of an oral report by the Chair or any other member of the Committee designated by the Committee to make such report.
3. The Committee shall maintain minutes or other records of its meetings and activities.
D. RESPONSIBILITIES AND DUTIES
The following functions shall be the common recurring responsibilities of the Committee. The Committee may carry out additional functions as may be appropriate in light of changing business, legislative and other conditions. The Committee shall also carry out any other responsibilities delegated to it by the Board from time to time.
The Committee, in carrying out its duties and discharging its oversight role, shall have the sole authority to retain independent legal, accounting or other experts as it determines necessary, including the authority to set and pay the fees payable to such experts at the Corporation’s expense. The Board shall be kept apprised of both the selection of the experts and the experts’ findings through the Committee’s regular reports to the Board.
Financial Statements and Disclosure
1. Review and discuss with management and the external auditor, and recommend to the Board for approval prior to public disclosure, the Corporation’s Annual Report, Annual Information Form, audited Consolidated Financial Statements and related Management’s Discussion and Analysis, Management Information Circular and any reports on adequacy of internal controls.
2. Review and discuss with management, and recommend to the Board for approval prior to public disclosure, prospectuses and other offering documents.
3. Review and discuss with management and the external auditor, and approve prior to public disclosure, the Corporation’s interim reports, including the unaudited Condensed Consolidated Interim Financial Statements and related Management’s Discussion and Analysis.
4. Review and discuss with management and the external auditor, and approve prior to public disclosure, press releases on quarterly and year-end financial results and any other disclosure documents not identified above that are required to be filed with regulators and contain significant financial information respecting the Corporation.
5. Review and discuss with management and the external auditor significant accounting policies and critical accounting estimates that would have a significant effect on the Corporation’s financial statements, and any changes to such policies. This review shall include a discussion with management and the external auditor concerning:
a.any areas of management judgment and estimates that may have a significant effect on the financial statements;
b.the appropriateness, acceptability and quality of the Corporation’s accounting policies; and
c.any material written communication between the external auditor and management.
6. Discuss with management the use of ‘‘pro forma’’ or ‘‘non-GAAP information’’ in the Corporation’s disclosure documents.
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7. Discuss with management and the external auditor the effect of regulatory and accounting initiatives as well as the use of off-balance sheet arrangements on the Corporation’s financial statements.
8. Discuss with the Corporation’s General Counsel (and with external legal counsel if necessary) and other members of management, as applicable, any litigation, claim or other contingency (including tax assessments) that could have a material effect on the financial position or operating results of the Corporation, and the manner in which these matters have been disclosed in the financial statements.
Financing Plans
1. Review and discuss with management the financing plans and objectives of the Corporation.
Risk Management and Internal Controls
1. Review and discuss with management at least annually:
a.the Corporation’s risk management framework, including the Corporation’s processes and controls to identify, monitor, evaluate and manage enterprise-wide risks and the Corporation's policies and practices relating to enterprise risk management. The Committee shall recommend to the Board for approval any changes considered advisable to such policies and practices;
b.the Corporation’s financial and taxation risks, shipping risk and IT-related risks (including cybersecurity and data privacy) and steps management has taken to monitor, evaluate and manage such risks; and
c.the insurance coverage maintained by the Corporation.
2. Review such other risk management matters from time to time as the Committee may consider appropriate or the Board may specifically direct.
3. Review, at least quarterly, the results of management’s evaluation of the adequacy and effectiveness of internal controls within the Corporation in connection with the certifications signed by the CEO and CFO. Management’s evaluation shall include a review of:
a.policies and procedures to ensure completeness and accuracy of information disclosed in the quarterly and annual reports, prevent earnings management and detect material financial statement misstatements due to fraud and error; and
b.internal control recommendations of the external auditor and arising from the results of the internal audit procedures, including any special steps taken to address material control deficiencies and any fraud, whether or not material, that involves management or other employees who have a significant role in the Corporation’s internal controls.
External Auditors
1. Review the selection, evaluation, reappointment or, where appropriate, replacement of the external auditor and recommend to the Board the nomination and remuneration of the external auditor to be appointed by the Corporation’s shareholders.
2. Resolve any disagreements between management and the external auditor regarding financial reporting.
3. Receive reports directly from, and communicate directly with, the external auditor.
4. Review a formal written statement obtained at least annually from the external auditor describing:
a.the external auditor’s internal quality control procedures;
b.any material issues raised by the most recent internal quality control review, peer review of the external auditor or any investigation by governmental or professional authorities within the preceding five years respecting one or more independent audits of the Corporation carried out by the external auditor;
c.any steps taken to deal with any such issues; and
d.all relationships between the external auditor and the Corporation.
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As part of such review, the Committee shall discuss with the external auditor whether the external auditor’s quality controls are adequate and whether any of the disclosed relationships or non-audit services may impact the objectivity and independence of the external auditor based on the independence requirements of the Applicable Rules. The Committee shall also conduct a comprehensive review of the external auditor at least every five years.
5. Review the external audit plan and enquire as to the extent the planned audit scope can be relied upon to detect weaknesses in internal control or fraud or other illegal acts. Any significant recommendations made by the external auditor for strengthening internal controls shall be reviewed.
6. Monitor the rotation of senior audit personnel who have primary responsibility for the audit work, as required by law.
7. Review and approve, in advance, the scope and related fees for all auditing services and non-audit services permitted by regulation that are to be provided by the external auditor in accordance with the Corporation’s Audit and Non-Audit Services Pre-Approval Standard, which is to be annually reviewed and approved by the Committee.
8. Review the establishment of policies relating to the Corporation’s hiring of present and former employees of the external auditor, if such individuals have participated in the audit of the Corporation, as required by law.
9. Prior to filing the Corporation’s Condensed Consolidated Interim Financial Statements and the Consolidated Financial Statements, receive a report from the external auditor on the results of their review or audit.
10. Meet with (a) the external auditor without management present and discuss any issues related to performance of the audit work, any restrictions and any significant disagreement with management and (b) separately with management to discuss the same matters as those discussed with the external auditor.
Internal Audit
1. Review the scope of responsibilities of the Corporation’s Internal Audit function, including its reporting relationships, activities, organizational structure and resources and whether there are any unjustified or inappropriate restrictions or limitations on the functioning of Internal Audit.
2. Discuss the appointment and performance of the head of the Corporation’s Internal Audit function.
3. Review and approve the annual Internal Audit Plan and objectives.
4. Review the responses and actions taken by management to address any control weaknesses or deficiencies identified in internal audit reports issued to management.
5. Meet, without management present, with the Corporation’s Internal Auditor and/or representatives of any external firm that executed the annual Internal Audit Plan. The Committee shall also meet, without management and the external auditor present, with the Corporation’s Internal Auditor to discuss any matters that the Committee or the Internal Auditor believes should be discussed privately.
Ethics and Compliance
1. Review annually the Corporation’s compliance with the Code of Business Conduct and make recommendations to the Board regarding any requests by directors or officers for waivers of the Code of Business Conduct.
2. Review the processes and procedures established by the Corporation for the receipt, retention and treatment of complaints regarding accounting, internal accounting controls or auditing matters or non-compliance with the Code of Business Conduct, including procedures for the confidential, anonymous submission of such complaints from employees.
3. Discuss with management and the external auditor any correspondence with regulators or governmental agencies and any published reports that raise material issues regarding the Corporation’s compliance policies or that could have a material effect on the Corporation’s financial statements.
4. Review annually the Corporation’s Corporate Disclosure Policy and recommend to the Board for approval any changes thereto.
5. Review and approve all related party transactions between the Corporation (or any of its subsidiaries) and its officers or directors (or any affiliates of such officers or directors), other than those disclosed in the Corporation’s financial statements.
35
E. ANNUAL PERFORMANCE EVALUATION
1. The Committee shall review and evaluate, at least annually, the performance of the Committee and its members, including the compliance of the Committee with its mandate.
2. The Committee shall annually review and assess the adequacy of its mandate and recommend to the Board for approval any improvements to the mandate that the Committee considers necessary or desirable.
36
Management’s Discussion and Analysis
Exhibit 99.2
Index
6 | Overview of the Business | 36 | Critical Accounting Estimates | ||||||||
8 | Our Strategy | 39 | Adoption of New Accounting Standards | ||||||||
10 | Financial Highlights | 39 | Anticipated Changes to International Financial Reporting Standards | ||||||||
11 | Production Summary | 39 | Non-GAAP Measures | ||||||||
12 | How We Analyze Our Business | 41 | Quarterly Financial Data (Unaudited) | ||||||||
13 | Financial Results | 41 | Selected Annual Information | ||||||||
19 | Liquidity and Capital Resources | 42 | Controls and Procedures | ||||||||
25 | Risk Factors and Risk Management | 43 | Forward-Looking Statements | ||||||||
This Management’s Discussion and Analysis ("MD&A") is dated March 7, 2025, and should be read in conjunction with our consolidated financial statements and the accompanying notes for the year ended December 31, 2024. Except where otherwise noted, the financial information presented in this MD&A is prepared in accordance with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board (the "IASB"). We use the United States dollar as our reporting currency and, except where otherwise noted, all currency amounts are stated in United States dollars. In this MD&A, a reference to the "Company" refers to Methanex Corporation and a reference to "Methanex," "we," "our" and "us" refers to the Company and its subsidiaries or any one of them as the context requires, as well as their respective interests in joint ventures and partnerships.
Throughout this document we use non-GAAP measures and ratios that do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Refer to the Non-GAAP Measures section on page 39 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.
Some of the historical price data and supply and demand statistics for methanol and certain other industry data contained in this MD&A are derived by the Company from industry consultants or from recognized industry reports regularly published by independent consulting and data compilation organizations in the methanol industry, including Chemical Market Analytics by OPIS, a Dow Jones company, Tecnon OrbiChem Ltd., Argus, ICIS, S&P Global and Methanol Market Services Asia, an Energy Aspects (EA) company. Industry consultants and industry publications generally state that the information provided has been obtained from sources believed to be reliable. We have not independently verified any of the data from third-party sources nor have we ascertained the underlying economic assumptions relied upon in these reports.
As at March 6, 2025 we had 67,395,212 common shares issued and outstanding and stock options exercisable for 1,123,150 additional common shares.
Additional information relating to Methanex, including our Annual Information Form, is available on our website at www.methanex.com, the Canadian Securities Administrators’ SEDAR+ website at www.sedarplus.ca and on the United States Securities and Exchange Commission’s EDGAR website at www.sec.gov.
OVERVIEW OF THE BUSINESS
Methanol is a clear liquid commodity chemical that is produced from natural gas and is also produced from coal, particularly in China. Traditional chemical demand, which represents approximately 50% of global methanol demand, is used to produce traditional chemical derivatives, including formaldehyde, acetic acid and a variety of other chemicals that form the basis of a wide variety of industrial and consumer products. Demand for energy-related applications, which represents over 30% of global methanol demand, includes several applications including methyl tertiary-butyl ether ("MTBE"), fuel applications (including vehicle fuel, marine fuel and other thermal applications), di-methyl ether and biodiesel. Demand into methanol-to-olefins ("MTO") represents approximately 20% of global methanol demand. MTO plants produce light olefins which have wide applications in packaging, textiles, plastic parts and automotive components.
We are the world’s largest producer and supplier of methanol and serve customers in Asia Pacific, North America, Europe and South America. Our total annual operating capacity, including Methanex's interests in jointly owned plants, is currently 10.6 million tonnes and is located in the United States, New Zealand, Trinidad and Tobago, Chile, Egypt, and Canada. In addition to the methanol produced at our sites, we purchase methanol produced by others under methanol offtake contracts and on the spot market. This gives us flexibility in managing our supply chain while continuing to meet customer needs and support our marketing efforts. We have marketing rights for 100% of the production from the jointly-owned plant in Egypt, which provides us with an additional 0.6 million
tonnes per year of methanol offtake supply when the plant is operating at full capacity. We also had marketing rights for 100% of the production from the jointly-owned Atlas plant in Trinidad and Tobago, which provided us with an additional 0.7 million tonnes per year of methanol offtake supply when the plant was operating at full capacity.
Refer to the Production Summary section on page 11 for more information.
Acquisition of OCI Global's Methanol Business
On September 8, 2024, Methanex announced that it entered into a definitive agreement to acquire OCI Global’s (“OCI”) international methanol business for approximately $2.05 billion ("OCI Acquisition"). The transaction includes a methanol facility with an annual production capacity of 910,000 metric tonnes ("MT") of methanol and 340,000 MT of ammonia and a 50 percent interest in a second methanol facility operated by the joint venture Natgasoline LLC (“Natgasoline”) which has an annual capacity of 1.7 million MT of methanol of which Methanex’s share will be 850,000 MT. The transaction also includes a low-carbon methanol production and marketing business and a currently idled methanol facility in the Netherlands.
Under the definitive agreement with OCI, the approximate $2.05 billion purchase price will consist of $1.18 billion in cash, the issuance of 9.9 million common shares of Methanex valued at $450 million (based on a $45 per share price) and the assumption of approximately $450 million in debt and leases. Closing of the transaction is expected in the second quarter of 2025 and is subject to receipt of certain regulatory approvals and other closing conditions including TSX approval for the issuance of Methanex shares to OCI.
There is currently a legal proceeding between OCI and its Natgasoline joint venture partner over certain shareholder rights. The obligation of Methanex to purchase OCI’s 50% stake in Natgasoline is subject to the resolution of this legal proceeding. If it is not settled within a certain period, Methanex has the option to carve out the purchase of the Natgasoline joint venture and close only on the remainder of the transaction.
2024 Industry Overview & Outlook
Methanol is a global commodity and our earnings are significantly affected by fluctuations in the price of methanol, which is directly impacted by changes in methanol supply and demand. Based on the diversity of end products in which methanol is used, demand for methanol is driven by a number of factors, including: the strength of global and regional economies, industrial production levels, energy prices, pricing of end products, downstream capacity and government regulations and policies. Methanol industry supply is impacted by the cost of production, methanol industry operating rates and methanol industry capacity changes.
Demand
We estimate that global methanol demand increased to approximately 97 million tonnes in 2024 driven primarily by growth in traditional chemical and energy applications and stable demand from the methanol to olefins (MTO) sector.
Over the long term, we believe that traditional chemical demand is influenced by the strength of global and regional economies and industrial production levels. We believe that demand for energy-related applications will be influenced by energy prices, pricing of end products, and government policies that are playing an increasing role in encouraging new applications for methanol due to its emissions benefits as a fuel. The future operating rates and methanol consumption of MTO producers will depend on a number of factors, including pricing for their various final products, the degree of downstream integration of these units with other products, the availability of methanol supply, the impact of olefin industry feedstock costs, including naphtha, on relative competitiveness and plant maintenance schedules.
Ongoing regulatory changes as part of the global energy transition along with other factors have led to a growing interest in methanol as a fuel due to its clean-burning attributes and potential to reduce greenhouse gas emissions if made from a renewable feedstock.
There is growing interest in methanol as a marine fuel given its environmental benefits, wide availability, cost competitiveness and ease of use. When made from renewable sources, methanol can be carbon neutral on a life-cycle basis, providing a future-proof pathway to meet the decarbonization goals of the shipping industry. The potential demand outlook for methanol as marine fuel continues to grow with orders for dual-fueled vessels and retrofits. The current vessels operating coupled with the order book for new builds and retrofits represents over 350 dual-fueled ships on the water by 2030. Actual methanol consumption from marine applications will depend on regulations, relative economics versus other fuels, and other factors.
Methanol is also being used as a vehicle fuel in China. Methanol can be blended with gasoline in low quantities and used in existing vehicles and can be used in high-proportion blends such as M85 in flex-fuel vehicles or M100 in dedicated methanol-fueled vehicles. There is significant interest in high-level methanol fuel blends for M100 taxis and trucks (able to run on 100% methanol fuel) in China. There are approximately 25,000 taxis and methanol hybrid passenger cars and 5,000 heavy-duty trucks in China, running on M100 fuel, representing approximately one million tonnes of annual methanol demand. Other countries are in the assessment or near-commercial stage for using methanol as a vehicle fuel.
In China, stricter air quality emissions regulations in several provinces are leading to a phase-out of coal-fueled commercial boilers, kilns, and cooking stoves in favour of cleaner fuels, creating a growing market for methanol as an alternative fuel. We estimate that
this demand segment represents approximately seven million tonnes of methanol demand. We continue to support the development of operational and safety standards to support the commercialization of methanol as a thermal fuel for industrial boilers, kilns and cooking stoves.
Supply
Methanol is produced from natural gas and is also produced from coal, particularly in China. The cost of production is influenced by the availability and cost of raw feedstock materials, freight costs, other operating and maintenance costs and government policies.
Operating rates continue to be uncertain and challenged due to the impact of trade sanctions, plant technical issues, and structural and seasonal natural gas constraints. The methanol industry ran at similar rates in 2024 compared to 2023. In 2024, there were approximately 1.5 million tonnes of production capacity additions in China. In North America, our new 1.8 million tonne Geismar 3 facility completed its commercial performance tests and is now operating at full rates. With the idling of Atlas and the restart of Titan in September 2024 overall production in Trinidad is lower by approximately 1 million tonnes annually. In Malaysia, we understand that a 1.8 million tonne plant started up in early 2025. We expect limited capacity additions in the next five years. In Iran, projects under development are showing slow progress due to technical and financing challenges from sanctions and the operating rates of existing methanol plants are constrained by gas availability due to depleting gas fields. If sanctions impacting Iran and/or other methanol producing countries are eased or removed, this could lead to an increase in methanol supply. China has planned capacity additions which we expect will be somewhat offset by the closure of some inefficient older plants. New capacity built in China is expected to be consumed domestically as China requires methanol imports to meet growing demand.
Price
The methanol business is a highly competitive commodity industry and future methanol prices will ultimately depend on the strength of global demand and methanol industry supply. Methanol demand and industry supply are driven by several factors as described above. Methanol prices have historically been, and are expected to continue to be, characterized by cyclicality.
Methanex’s average realized price in 2024 was $355 per tonne compared to $333 per tonne in 2023.
OUR STRATEGY
Our primary objective is to create value through our leadership in the global production, marketing and delivery of methanol to customers. To achieve this objective we have a simple, clearly defined strategy: leadership, low cost and operational excellence. We pride ourselves in being a leader in Responsible Care (an operating ethic and set of principles for sustainability developed by the Chemistry Industry Association of Canada and recognized by the United Nations) and having a strategic focus on managing risks and proactive plans relating to personnel health and safety, environmental protection, community involvement, social responsibility, sustainability, security and emergency preparedness. Our brand differentiator "The Power of Agility®" defines our culture of flexibility, responsiveness and creativity that allows us to capitalize on opportunities quickly as they arise, and swiftly respond to customer needs.
Leadership
Leadership is a key element of our strategy. We are focused on creating value through our position as the leading producer and supplier in the global methanol industry, improving our ability to safely and cost-effectively deliver methanol to customers and supporting both traditional and energy-related global methanol demand growth.
We are the leading producer and supplier of methanol to customers in Asia Pacific, North America, Europe and South America. Our 2024 sales volume of 10.5 million tonnes of methanol represented approximately 11% of global methanol demand. This scale allows us the flexibility to meet customer needs globally. Our leadership position has also enabled us to play an important role in the methanol industry, which includes publishing Methanex reference prices that are used in each region as the basis of pricing for our customer contracts.
The geographically diverse locations of our production sites and our shipping fleet allow us to deliver methanol cost-effectively to customers globally. We continue to invest in global distribution and supply infrastructure, which includes the world's largest methanol ocean tanker fleet and terminal capacity in all major international ports, enabling us to enhance value to customers by providing reliable and secure supply.
Another key component of our global leadership strategy is our ability to supplement methanol production with methanol purchased from third parties to give us flexibility in our supply chain to meet customer commitments. We purchase methanol through a combination of methanol offtake contracts and spot purchases. We manage the cost of purchased methanol by taking advantage of our global supply chain infrastructure, which allows us to purchase methanol in the most cost-effective region while still maintaining overall security of supply.
We have storage capacity and offices in strategic global locations that allows us to cost-effectively manage supply to customers and ensure customer service and industry positioning.
Low Cost
A low cost structure is an important competitive advantage in a commodity industry and is a key element of our strategy. Our approach to major business decisions is guided by a drive to improve our cost structure and create value for shareholders. The most significant components of total costs are natural gas for feedstock and distribution costs associated with delivering methanol to customers.
We manage our natural gas costs in two ways: through gas contracts linked to methanol price and through fixed price contracts. Our production facilities outside North America are largely underpinned by natural gas purchase agreements where the natural gas price is linked to methanol prices. This pricing relationship enables these facilities to be competitive throughout the methanol price cycle. In North America, we have fixed price natural gas supply contracts and financial hedges in place targeting minimum operating rate requirements of approximately 70% in the near term. We purchase our remaining North American gas requirements through the spot market.
Our production facilities are well located to supply global methanol markets and we take a long-term approach to contracting shipping capacity to meet customer needs. Nonetheless, the cost to distribute methanol from production locations to customers is a significant component of total operating costs. These include costs for ocean shipping, in-market storage facilities and in-market distribution. We focus on identifying initiatives to reduce these costs, including optimizing the use of our shipping fleet, third-party backhaul arrangements and taking advantage of prevailing conditions in the shipping market by varying the type and term of ocean vessel contracts. We also look for opportunities to leverage our global asset position by entering into geographic product exchanges with other methanol producers to reduce distribution and transportation costs.
Operational Excellence
We maintain a focus on operational excellence in all aspects of our business. This includes excellence in manufacturing and supply chain processes, marketing and sales, Responsible Care and financial management.
To differentiate ourselves from competitors, we strive to be the best operator and the preferred supplier to customers. We believe that reliability of supply is critical to the success of our customers’ businesses and our goal is to deliver methanol safely, reliably and cost-effectively. Our commitment to Responsible Care drives our adherence to the highest principles of health, safety, environmental stewardship, and social responsibility. We believe this commitment helps us achieve an excellent overall environmental and safety record and aligns our community involvement and social investments with our core values.
Product stewardship is a vital component of a Responsible Care culture and guides our actions through the complete life cycle of our product. We aim for the highest safety standards to minimize risk to employees, customers and suppliers as well as to the environment and the communities in which we do business. We promote the proper use and safe handling of methanol at all times through a variety of internal and external health, safety and environmental initiatives, and we work with industry colleagues to improve safety standards. We readily share technical and safety expertise with key stakeholders (including customers, end-users, suppliers, and logistics providers) through direct communication and active participation in local and international industry associations, seminars and conferences and online education initiatives.
In 2024, our strategy of operational excellence in financial management supported the completion of the Geismar 3 project. We also announced the OCI Acquisition for approximately $2.05 billion, subject to regulatory approval and other closing conditions. While managing both current and future capital needs we also returned cash to shareholders through the regular dividend. As at December 31, 2024, we remain in a strong liquidity position with $892 million in cash and $500 million of undrawn back-up liquidity through our revolving credit facility. In the fourth quarter of 2024, we completed the financing plan for the OCI Acquisition including renewing and increasing the undrawn credit facility, syndicating a $650 million Term Loan A and issuing $600 million in unsecured notes. The OCI Acquisition financing has been structured to allow the flexible repayment of the term loan commitment to support our capital allocation priority to reduce debt. During the fourth quarter, we also repaid $300 million in unsecured notes that were due in December 2024 with cash generated from operations. We actively manage our liquidity and capital structure in light of changes to economic conditions, the underlying risks inherent in our operations and the capital requirements of our business.
Sustainability
We have embedded sustainability into our long-term strategy alongside our commitment to Responsible Care. We prioritize material sustainability topics, which are those environmental, social or governance topics that can significantly impact our business success and are of interest to our key stakeholders. The materiality assessment that we conducted in 2023 included external stakeholder outreach and confirmed greenhouse gas ("GHG") emissions, transition to a low-carbon economy, employee and contractor safety and process safety as our most material sustainability topics. We completed a double materiality assessment at the end of 2024 to prepare for the European Corporate Sustainability Reporting Directive (CSRD). Our most material sustainability topics are unchanged. We are
also monitoring the EU Omnibus proposal, which was published on February 26, 2025 and will adjust our reporting approach as appropriate.
Our executive leadership team has overall responsibility for ensuring our material sustainability topics are being effectively evaluated and managed. These include climate-related risks and opportunities associated with our GHG emissions and the transition to a low-carbon economy. The Executive Leadership Team incorporates these matters into our strategic and business planning activities to support the long-term sustainability of our business.
To improve decision making and evaluate organizational risks and opportunities under different plausible futures, we started incorporating scenario planning into our strategy development process. As part of our strategic planning in 2024, we used a dynamic general equilibrium energy model to analyze the potential implications to energy markets (including methanol) of several scenarios that differed on the pace of the energy transition.
We believe that having a diverse team, equitable people practices and an inclusive workplace leads to a better culture, better decisions and a better company. Our vision is to have an inclusive culture where diversity is valued, differences are embraced and everyone has the opportunity to contribute, develop and advance. The Global Equity, Diversity, and Inclusion Council, made up of senior leaders from around the globe, supports the development and execution of our vision and its integration into the business. In 2024, we made significant strides towards achieving our vision, including the development of a new guide to inclusive and equitable recruitment to support the hiring process. We also established three new Employee Resource Groups, which create a safe environment for team members who share an interest in a specific dimension of diversity to connect and raise awareness.
In March 2025, we issued our 2024 Sustainability Report, aligned with the Sustainability Accounting Standards Board (SASB) and the Task-Force on Climate-related Financial Disclosures (TCFD).The Report is also a transitional report as we shift towards CSRD and European Sustainability Reporting Standards requirements for 2025. The 2024 Sustainability Report is available at https://www.methanex.com/sustainability.
FINANCIAL HIGHLIGHTS
($ Millions, except as noted) | 2024 | 2023 | ||||||
Production (thousands of tonnes) (attributable to Methanex shareholders) | 6,358 | 6,642 | ||||||
Sales volume (thousands of tonnes) | ||||||||
Methanex-produced methanol | 6,094 | 6,455 | ||||||
Purchased methanol | 3,471 | 3,527 | ||||||
Commission sales | 904 | 1,187 | ||||||
Total sales volume 1 | 10,469 | 11,169 | ||||||
Methanex average non-discounted posted price ($ per tonne) 2 | 508 | 434 | ||||||
Average realized price ($ per tonne) 3 4 | 355 | 333 | ||||||
Revenue | 3,720 | 3,723 | ||||||
Net income (attributable to Methanex shareholders) | 164 | 174 | ||||||
Adjusted net income 4 | 252 | 153 | ||||||
Adjusted EBITDA 4 | 764 | 622 | ||||||
Cash flows from operating activities | 737 | 660 | ||||||
Basic net income per common share ($ per share) | 2.43 | 2.57 | ||||||
Diluted net income per common share ($ per share) | 2.39 | 2.57 | ||||||
Adjusted net income per common share ($ per share) 4 | 3.72 | 2.25 | ||||||
Common share information (millions of shares) | ||||||||
Weighted average number of common shares | 67 | 68 | ||||||
Diluted weighted average number of common shares | 68 | 68 | ||||||
Number of common shares outstanding, end of year | 67 | 67 | ||||||
1 Methanex-produced methanol represents our equity share of volume produced at our facilities and excludes volume marketed on behalf of partners related to 36.9% of the Atlas facility and 50% of the Egypt facility that we do not own.
2 Methanex average non-discounted posted price represents the average of our non-discounted posted prices in North America, Europe, China and Asia Pacific weighted by sales volume. Current and historical pricing information is available at www.methanex.com.
3 The Company has used Average realized price ("ARP") throughout this document. ARP is calculated as revenue divided by the total sales volume. It is used by management to assess the realized price per unit of methanol sold, and is relevant in a cyclical commodity environment where revenue can fluctuate widely in response to market prices.
4 The Company has used the terms Adjusted net income, Adjusted net income per common share, and Adjusted EBITDA throughout this document. These items are non-GAAP measures and ratios that do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Refer to the Non-GAAP Measures section on page 39 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.
PRODUCTION SUMMARY
The following table details the annual operating capacity and actual production at our facilities in 2024 and 2023:
(Thousands of tonnes) | Annual operating capacity 1 | 2024 Production | 2023 Production | ||||||||
USA (Geismar) 2 | 4,000 | 2,529 | 2,142 | ||||||||
Trinidad (Methanex interest) 3 | 1,960 | 956 | 1,074 | ||||||||
New Zealand 4 | 1,720 | 670 | 1,381 | ||||||||
Chile | 1,700 | 1,180 | 993 | ||||||||
Egypt (50% interest) | 630 | 460 | 504 | ||||||||
Canada (Medicine Hat) | 600 | 563 | 548 | ||||||||
| 10,610 | 6,358 | 6,642 | |||||||||
1 The annual operating capacity of our production facilities may be higher or lower than original nameplate capacity as, over time, these figures have been adjusted to reflect ongoing operating efficiencies at these facilities. Actual production for a facility in any given year may be higher or lower than operating capacity due to a number of factors, including natural gas availability, feedstock composition, the age of the facility's catalyst, turnarounds and access to CO2 from external suppliers for certain facilities. We review and update the operating capacity of our production facilities on a regular basis based on historical performance.
2 G3 completed its commercial performance tests in October 2024.
3 The operating capacity of Trinidad is made up of the Titan (100% interest) and Atlas (63.1% interest) plants. The Atlas plant is currently idle. (Refer to the Trinidad and Tobago section below.)
4 The operating capacity of New Zealand is made up of the two Motunui facilities, one of which is idle.(Refer to the New Zealand section below.)
United States
Our Geismar plants in Louisiana produced 2.5 million tonnes of methanol in 2024, compared with 2.1 million in 2023. Production at the Geismar site was higher in 2024 as a result of production from the start-up of the Geismar 3 plant. The plant produced first methanol at the end of July and successfully completed its commercial performance tests in early October. Subsequent to first methanol production, a number of shutdowns of Geismar 3 were taken to calibrate and inspect newly commissioned equipment to ensure reliability of plant operations. Refer to the Risk Factors and Risk Management – United States section on page 29 for more information.
Trinidad and Tobago
We operate our fully-owned Titan facility and the Atlas facility, in which we have a 63.1% economic interest and had marketing rights for 100% of the production. Together, the two facilities represent 2.0 million tonnes of Methanex share of annual operating capacity. We produced 1.0 million tonnes of methanol (Methanex share) in 2024, compared with 1.1 million tonnes in 2023. Production in Trinidad was lower in 2024 due to the Atlas plant (Methanex 63.1% or 1,085,000 tonnes per year capacity) being idled in September, as its legacy 20-year natural gas supply agreement expired. Concurrent with the idling of the Atlas plant, the Titan plant (875,000 tonnes per year capacity) was restarted upon commencement of a two year natural gas supply agreement with the National Gas Company of Trinidad and Tobago (NGC). Refer to the Risk Factors and Risk Management – Trinidad and Tobago section on page 29 for more information.
New Zealand
In New Zealand, we produced 0.7 million tonnes of methanol in 2024 compared with 1.4 million tonnes in 2023. Production for 2024 was lower than 2023 due to the temporary idling of operations from August to the end of October as we entered into short-term commercial arrangements to provide contracted natural gas into the New Zealand electricity market at favourable economic terms as the country's overall energy balances were strained. Additionally, based on the medium-term gas outlook from our gas suppliers for the next few years, the decision was made to indefinitely idle one of the two Motunui plants.
Based on the current outlook from our gas suppliers, we estimate production for 2025 to be between 0.5 - 0.7 million tonnes. Future production will be dependent on gas availability and any on-selling of gas into the electricity market to support New Zealand's energy needs. We are continuing discussions with our gas suppliers to ensure our contractual entitlements, which are in place until 2029, are being respected as well as engaging with our gas suppliers and government agencies in supporting efforts to improve energy balances in the country. Refer to the Risk Factors and Risk Management – New Zealand section on page 29 for more information.
Chile
The Chile facilities produced 1.2 million tonnes of methanol in 2024 compared with 1.0 million tonnes in 2023. Production in Chile was higher in 2024 due to higher gas availability from Argentina. Both plants are expected to run at full rates from the end of September 2024 through April 2025, the southern hemisphere summer months. We estimate production for 2025 will be between 1.3 - 1.4 million tonnes. This production is supported by gas contracts in place with Chilean and Argentinean gas producers until 2030 and 2027, respectively, which underpin approximately 55% of the site's gas requirements year round. We continue to expect seasonality in production but are seeing positive developments making gas available for longer periods. Refer to the Risk Factors and Risk Management – Chile section on page 30 for more information.
Egypt
We operate the 1.3 million tonne per year methanol facility in Egypt, in which we have a 50% economic interest and marketing rights for 100% of the production. We produced 0.9 million tonnes of methanol (Methanex share of 0.5 million) in Egypt in 2024 compared to 1.0 million tonnes (Methanex share of 0.5 million) in 2023. While both years were similarly impacted by an unplanned outage caused by a mechanical failure in the synthesis gas compressor lasting from October 2023 through February 2024, we had lower levels of production from Egypt in 2024 due to fluctuating operating rates based on gas availability. In Egypt, industrial plants were impacted by gas curtailments due to increased seasonal demand for power generation due to elevated temperatures coupled with lower domestic supply. We are monitoring the gas market closely and expect to experience some curtailments in 2025, particularly in the summer months, depending on gas supply and demand dynamics. Refer to the Risk Factors and Risk Management – Egypt section on page 30 for more information.
Canada
Medicine Hat produced 0.6 million tonnes of methanol in 2024 compared with 0.5 million tonnes in 2023. Refer to the Risk Factors and Risk Management – Canada section on page 30 for more information.
HOW WE ANALYZE OUR BUSINESS
Our operations consist of a single operating segment: the production and sale of methanol. We review our financial results by analyzing changes in the components of Adjusted EBITDA, mark-to-market impact of share-based compensation, depreciation and amortization, finance costs, finance income and other, and income taxes.
The Company has used the terms Adjusted net income, Adjusted net income per common share, and Adjusted EBITDA throughout this document. These items are non-GAAP measures and ratios that do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Refer to the Non-GAAP Measures section on page 39 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.
In addition to the methanol that we produce at our facilities, we also purchase and resell methanol produced by others and we sell methanol on a commission basis. We analyze the results of all methanol sales together, excluding commission sales volume. The key drivers of changes in Adjusted EBITDA are average realized price, cash costs and sales volume, which are defined and calculated as follows:
| PRICE | The change in Adjusted EBITDA as a result of changes in average realized price is calculated as the difference from period to period in the selling price of methanol multiplied by the current period total methanol sales volume, excluding commission sales volume. | ||||
| CASH COSTS | The change in Adjusted EBITDA as a result of changes in cash costs is calculated as the difference from period to period in cash costs per tonne multiplied by the current period total methanol sales volume, excluding commission sales volume in the current period. The cash costs per tonne is the weighted average of the cash cost per tonne of Methanex-produced methanol and the cash cost per tonne of purchased methanol. The cash cost per tonne of Methanex-produced methanol includes absorbed fixed cash costs per tonne and variable cash costs per tonne. The cash cost per tonne of purchased methanol consists principally of the cost of methanol itself. In addition, the change in Adjusted EBITDA as a result of changes in cash costs includes the changes from period to period in unabsorbed fixed production costs, consolidated selling, general and administrative expenses and fixed storage and handling costs. | ||||
| SALES VOLUME | The change in Adjusted EBITDA as a result of changes in sales volume is calculated as the difference from period to period in total methanol sales volume, excluding commission sales volume, multiplied by the margin per tonne for the prior period. The margin per tonne for the prior period is the weighted average margin per tonne of Methanex-produced methanol and margin per tonne of purchased methanol. The margin per tonne for Methanex-produced methanol is calculated as the selling price per tonne of methanol less absorbed fixed cash costs per tonne and variable cash costs per tonne. The margin per tonne for purchased methanol is calculated as the selling price per tonne of methanol less the cost of purchased methanol per tonne. | ||||
We own 63.1% of the Atlas methanol facility and, up to the expiry of its legacy 20-year natural gas supply agreement and the idling of the plant, we marketed the remaining 36.9% of its production through a commission offtake agreement, both of which we recognize as revenue on a gross basis. A contractual agreement between us and our partners establishes joint control over Atlas. As a result, we account for this investment using the equity method of accounting, which results in 63.1% of the net assets and net earnings of Atlas being presented separately in the consolidated statements of financial position and consolidated statements of income, respectively. For the purpose of analyzing our business, Adjusted EBITDA, Adjusted net income and Adjusted net income per common share include an amount representing our 63.1% equity share in Atlas. Our analysis of depreciation and amortization, finance costs, finance income and other, and income taxes is consistent with the presentation of our consolidated statements of income and excludes amounts related to Atlas.
We own 50% of the Egypt methanol facility and market the remaining 50% of its production through a commission offtake agreement. We own 60% of Waterfront Shipping, which provides service to Methanex for the ocean freight component of our distribution and logistics costs. We consolidate both Egypt and Waterfront Shipping, which results in 100% of the financial results being included in our financial statements. Non-controlling interests are included in the Company’s consolidated financial statements and represent the non-controlling shareholders’ interests in the Egypt methanol facility and Waterfront Shipping. For the purpose of analyzing our business, Adjusted EBITDA, Adjusted net income and Adjusted net income per common share exclude the amounts associated with non-controlling interests.
FINANCIAL RESULTS
For the year ended December 31, 2024, we reported a net income attributable to Methanex shareholders of $164 million ($2.39 net income per common share on a diluted basis), compared with a net income attributable to Methanex shareholders of $174 million ($2.57 net income per common share on a diluted basis) for the year ended December 31, 2023. Net income attributable to Methanex shareholders for the year ended December 31, 2024 is lower compared to the year ended December 31, 2023, primarily due to the impact of the non-recurring asset impairment expense in relation to our New Zealand cash generating unit ("New Zealand CGU") discussed in the Critical Accounting Estimates section and elsewhere in this MD&A. This was partially offset by a higher average realized price, the New Zealand gas sale net proceeds and the Egypt insurance proceeds recorded in 2024.
For the year ended December 31, 2024, we reported Adjusted EBITDA of $764 million and Adjusted net income of $252 million ($3.72 Adjusted net income per common share), compared with Adjusted EBITDA of $622 million and Adjusted net income of $153 million ($2.25 Adjusted net income per common share) for the year ended December 31, 2023.
We calculate Adjusted EBITDA and Adjusted net income by including amounts related to our equity share of the Atlas facility (63.1% interest) and by excluding the non-controlling interests' share, the mark-to-market impact of share-based compensation as a result of changes in our share price, the impact of the Egypt and New Zealand gas contract revaluations included in finance income and other and the impact of certain items associated with specific identified events. For 2024, the impact of the asset impairment charge was excluded from Adjusted EBITDA and Adjusted net income due to the non-recurring nature of the expense and to better reflect the operating performance of the Company's business. For 2023, the settlement of a historical dispute under an existing gas contract was excluded from Adjusted EBITDA and Adjusted net income due to the one-time nature of the settlement and to better reflect the operating performance of the Company's business.
A reconciliation from net income attributable to Methanex shareholders to Adjusted net income and the calculation of Adjusted diluted net income per common share is as follows:
($ Millions, except number of shares and per share amounts) | 2024 | 2023 | ||||||
Net income attributable to Methanex shareholders | $ | 164 | $ | 174 | ||||
Mark-to-market impact of share-based compensation, net of tax | 2 | 13 | ||||||
Impact of Egypt and New Zealand gas contract revaluation, net of tax | (4) | (3) | ||||||
Asset impairment charge, net of tax | 90 | — | ||||||
Impact on earnings of associate of gas contract settlement, net of tax | — | (31) | ||||||
Adjusted net income | $ | 252 | $ | 153 | ||||
Diluted weighted average shares outstanding (millions) | 68 | 68 | ||||||
Adjusted net income per common share | $ | 3.72 | $ | 2.25 | ||||
A summary of our consolidated statements of income for 2024 and 2023 is as follows:
($ Millions) | 2024 | 2023 | ||||||
Consolidated statements of income: | ||||||||
Revenue | $ | 3,720 | $ | 3,723 | ||||
Cost of sales and operating expenses | (3,009) | (3,068) | ||||||
| New Zealand gas sale net proceeds | 103 | — | ||||||
Egypt insurance recovery | 59 | — | ||||||
Mark-to-market impact of share-based compensation | 2 | 16 | ||||||
| Adjusted EBITDA attributable to associate | 82 | 135 | ||||||
Amounts excluded from Adjusted EBITDA attributable to non-controlling interests | (193) | (184) | ||||||
| Adjusted EBITDA | 764 | 622 | ||||||
Mark-to-market impact of share-based compensation | (2) | (16) | ||||||
Depreciation and amortization | (386) | (392) | ||||||
| Gas contract settlement, net of tax | — | 31 | ||||||
Finance costs | (133) | (117) | ||||||
Finance income and other | 12 | 40 | ||||||
Income tax expense | (30) | (1) | ||||||
| Asset impairment charge | (125) | — | ||||||
Earnings of associate adjustment 1 | (43) | (67) | ||||||
Non-controlling interests adjustment 1 | 107 | 74 | ||||||
Net income attributable to Methanex shareholders | $ | 164 | $ | 174 | ||||
Net income | $ | 250 | $ | 284 | ||||
1 These adjustments represent depreciation and amortization, finance costs, finance income and other and income taxes associated with our 63.1% interest in the Atlas methanol facility and the non-controlling interests.
Revenue
There are many factors that impact our global and regional revenue. The methanol business is a global commodity industry affected by supply and demand fundamentals. Based on the diversity of end products in which methanol is used, demand for methanol is driven by a number of factors, including: strength of global and regional economies, industrial production levels, energy prices, pricing of end products and government regulations and policies. Revenue was $3.7 billion in 2024 compared to $3.7 billion in 2023. The comparable revenue reflects a higher average realized price, offset by lower sales volume in 2024 compared to 2023.
We publish regional non-discounted reference prices for each methanol sales region and these posted prices are reviewed and revised monthly or quarterly based on industry fundamentals and market conditions. Most of our customer contracts use published Methanex reference prices as a basis for pricing, and we offer discounts to customers based on various factors. Our average non-discounted published reference price in 2024 was $508 per tonne compared with $434 per tonne in 2023. Our average realized price in 2024 was $355 per tonne compared to $333 per tonne in 2023.
Distribution of Revenue
The geographic distribution of revenue by customer location for 2024 was comparable to 2023. Details are as follows:
($ Millions, except where noted) | 2024 | 2023 | ||||||||||||||||||||||||
China | $ | 828 | 22% | $ | 1,043 | 28% | ||||||||||||||||||||
Europe | 842 | 23% | 722 | 19% | ||||||||||||||||||||||
United States | 502 | 13% | 575 | 15% | ||||||||||||||||||||||
South America | 479 | 13% | 429 | 12% | ||||||||||||||||||||||
South Korea | 483 | 13% | 392 | 11% | ||||||||||||||||||||||
| Other Asia | 402 | 11% | 387 | 10% | ||||||||||||||||||||||
Canada | 184 | 5% | 175 | 5% | ||||||||||||||||||||||
| $ | 3,720 | 100% | $ | 3,723 | 100% | |||||||||||||||||||||
Adjusted EBITDA (Attributable to Methanex Shareholders)
2024 Adjusted EBITDA was $764 million compared with 2023 Adjusted EBITDA of $622 million, an increase of $142 million. The key drivers of change in our Adjusted EBITDA are average realized price, sales volume and cash costs as described below (refer to the How We Analyze Our Business section on page 12 for more information).
($ Millions) | 2024 vs. 2023 | ||||
Average realized price | $ | 206 | |||
Sales volume | (31) | ||||
| Geismar 3 delay costs | (22) | ||||
| New Zealand gas sale proceeds, net of gas and fixed costs during idle period | 91 | ||||
Total cash costs | (102) | ||||
Increase in Adjusted EBITDA | $ | 142 | |||
Average Realized Price
Our average realized price for the year ended December 31, 2024, was $355 per tonne compared to $333 per tonne for 2023, and this increased Adjusted EBITDA by $206 million (refer to the Financial Results – Revenue section on page 14 for more information).
Sales Volume
Methanol sales volume, excluding commission sales volume, for the year ended December 31, 2024, decreased to 9.6 million tonnes from 10.0 million tonnes in 2023, and this decreased Adjusted EBITDA by $31 million. Including commission sales volume from the Atlas and Egypt facilities, our total methanol sales volume was 10.5 million tonnes in 2024 compared with 11.2 million tonnes in 2023. Sales volume may vary year to year depending on customer requirements and inventory levels as well as the available commission sales volume.
Geismar 3 Delay Costs
The operating costs related to the delay in start-up of our Geismar 3 project include organizational build-up, take-or-pay obligations on utilities contracts as well as additional recognition of gas hedges. The total delay costs for the year ended December 31, 2024 compared to the same period in 2023 were $22 million higher, primarily due to over-hedged gas costs of $16 million which was identified when a portion of our existing natural gas hedges exceeded the expected Geismar site production requirements. This over-hedged gas cost was recorded in early 2024 and covered the entire period of the delay.
New Zealand Gas Sale Proceeds, Net of Gas and Fixed Costs
In 2024 we entered short-term commercial arrangements to provide available natural gas into the New Zealand electricity market as the country’s overall energy balances were very strained. The total net proceeds less fixed costs for the year ended December 31, 2024 were $91 million. There are no equivalent transactions in 2023. This does not include the impact of lost margin on the sale of methanol that was not produced in the period and additional supply chain costs incurred.
Total Cash Costs
The primary drivers of change in our total cash costs are changes in the cost of Methanex-produced methanol and changes in the cost of methanol we purchase from others ("purchased methanol"). We supplement our production with methanol produced by others through methanol offtake contracts and purchases on the spot market to meet customer needs and support our marketing efforts globally.
We apply the first-in, first-out method of accounting for inventories and it generally takes between 30 and 60 days to sell the methanol we produce or purchase. Accordingly, the changes in Adjusted EBITDA as a result of changes in Methanex-produced and purchased methanol costs primarily depend on changes in methanol pricing and the timing of inventory flows.
In a rising price environment, our margins at a given price are higher than in a stable price environment as a result of methanol purchases and production versus sales. Generally, the opposite applies when methanol prices are decreasing.
The changes in Adjusted EBITDA due to changes in total cash costs for 2024 compared with 2023 were due to the following:
($ Millions) | 2024 vs. 2023 | ||||
Methanex-produced methanol costs | $ | 1 | |||
Proportion of Methanex-produced methanol sales | (7) | ||||
Purchased methanol costs | (39) | ||||
Logistics costs | (39) | ||||
Egypt insurance recovery | 30 | ||||
Other, net | (48) | ||||
Increase in Adjusted EBITDA due to changes in total cash costs | $ | (102) | |||
Methanex-Produced Methanol Costs
Natural gas is the primary feedstock at our methanol facilities and is the most significant component of Methanex-produced methanol costs. Through 2024, we purchased natural gas for more than half of our production under natural gas purchase agreements where the unique terms of each contract include a base price and a variable price component linked to methanol price to reduce our commodity price risk exposure. The variable price component of each gas contract is adjusted by a formula linked to methanol sales prices above a certain level. We also purchase natural gas in North America and are exposed to natural gas spot price fluctuations for the unhedged portion of our gas needs in the region. Methanex-produced methanol costs were lower in 2024 compared with 2023 by $1 million, primarily due to the impact of changes in realized methanol prices on the variable portion of our natural gas cost, changes in spot gas prices which impact the unhedged portion of our North American operations, timing of inventory flows and changes in the mix of production sold from inventory. For additional information regarding our natural gas supply agreements, refer to the Liquidity and Capital Resources – Summary of Contractual Obligations and Commercial Commitments section on page 22.
Proportion of Methanex-Produced Methanol Sales
The cost of purchased methanol is directly linked to the selling price for methanol at the time of purchase and the cost of purchased methanol is generally higher than the cost of Methanex-produced methanol. Accordingly, an increase in the proportion of Methanex-produced methanol sales results in a decrease in our overall cost structure for a given period, while a decrease in the proportion of Methanex-produced methanol will increase our cost structure. The proportion of Methanex-produced methanol sales decreased in 2024 due to lower production and this increased costs and decreased Adjusted EBITDA by $7 million for 2024 compared with 2023.
Purchased Methanol Costs
A key element of our corporate strategy is global leadership and, as such, we have built a leading market position in each of the regions where methanol is sold. We supplement our production with purchased methanol through methanol offtake contracts and on the spot market to meet customer needs and support our marketing efforts within each region. In structuring purchase agreements, we look for opportunities that provide synergies with our existing supply chain that allow us to purchase methanol in the most cost-effective region. The cost of purchased methanol consists principally of the cost of the methanol itself, which is directly related to the price of methanol at the time of purchase. Higher methanol prices in 2024 and the timing of inventory flows and purchases increased the cost of purchased methanol per tonne and this decreased Adjusted EBITDA by $39 million compared with 2023.
Logistics Costs
Our investment in global distribution and supply infrastructure includes a dedicated fleet of ocean-going vessels. We utilize these vessels to enhance value to customers by providing reliable and secure methanol supply. Additionally we carry third-party backhaul cargoes, when available, to optimize supply chain costs overall. Logistics costs can vary from period to period primarily depending on the levels of production from each of our production facilities, the resulting impact on our supply chain, and variability in bunker fuel costs. Higher logistics costs in 2024 decreased Adjusted EBITDA by $39 million compared to 2023. Logistics costs increased in 2024 compared to 2023 primarily due to the mix of production from various plants, unplanned outages including at our Egypt facility, the impact on ocean freight of longer supply routes and a lower contribution from backhaul ocean freight journeys earned from third parties.
Egypt Insurance Recovery
We experienced an outage at the Egypt plant from October 2023 to February 2024. The insurance recovery of $30 million (Methanex share) was recognized in 2024 which partially offsets repair costs charged to earnings and lost margins incurred in the fourth quarter of 2023 and first quarter of 2024.
Other, Net
Other, net relates to unabsorbed fixed costs, selling, general and administrative expenses and other operational items. For the year ended December 31, 2024 compared with the same period in 2023, other costs were higher by $48 million mainly due to higher unabsorbed costs in 2024 compared to 2023 and higher costs relating to the OCI Acquisition . Additionally, the decision to indefinitely idle one of the plants in New Zealand led to restructuring costs of $4 million in 2024, for which there is no equivalent transaction in 2023.
Mark-to-Market Impact of Share-Based Compensation
We grant share-based awards as an element of compensation. Share-based awards granted include stock options, share appreciation rights, tandem share appreciation rights, deferred share units, restricted share units and performance share units. For all share-based awards, share-based compensation is recognized over the related vesting period for the proportion of the service that has been rendered at each reporting date. Share-based compensation includes an amount related to the grant date value and a mark-to-market impact as a result of subsequent changes in the fair value of the share-based awards primarily driven by the Company’s share price. The grant date value amount is included in Adjusted EBITDA and Adjusted net income. The mark-to-market impact of share-based compensation as a result of changes in our share price is excluded from Adjusted EBITDA and Adjusted net income and is analyzed separately.
($ Millions, except share price) | 2024 | 2023 | ||||||
Methanex Corporation share price 1 | $ | 49.94 | $ | 47.36 | ||||
Grant date fair value expense included in Adjusted EBITDA and Adjusted net income | 21 | 19 | ||||||
Mark-to-market impact 2 | 2 | 16 | ||||||
Total share-based compensation expense, before tax | $ | 23 | $ | 35 | ||||
1 U.S. dollar share price of Methanex Corporation as quoted on the Nasdaq Global Select Market on the last trading day of the respective period.
2 For the periods presented, the mark-to-market impact on share-based compensation is primarily due to changes in the Methanex Corporation share price.
For stock options, the cost is measured based on an estimate of the fair value at the grant date using the Black-Scholes option pricing model, and this grant date fair value is recognized as compensation expense over the related vesting period with no subsequent re-measurement to fair value.
Share appreciation rights ("SARs") are non-dilutive units that grant the holder the right to receive a cash payment upon exercise for the difference between the market price of the Company’s common shares and the exercise price that is determined at the grant date. Tandem share appreciation rights ("TSARs") give the holder the choice between exercising a regular stock option or a SAR. The fair value of SARs and TSARs are re-measured each quarter using the Black-Scholes option pricing model, which considers the market value of the Company’s common shares on the last trading day of each quarter.
Deferred, restricted and performance share units are grants of notional common shares that are redeemable for cash based on the market value of the Company’s common shares and are non-dilutive to shareholders. Performance share units granted annually reflect a long-term incentive plan where units are redeemable for cash based on the market value of the Company's common shares and are non-dilutive to shareholders. Units vest over three years and include two performance factors: (i) relative total shareholder return of Methanex shares versus a specific market index, and (ii) the three-year average return on capital employed. The relative total shareholder performance factor is measured by the Company at the grant date and each reporting date using a Monte-Carlo simulation model to determine fair value. The three-year average return on capital employed performance factor reflects the actual return on capital employed for historical periods and management's best estimate for forecast periods to determine the expected number of units to vest.
For deferred, restricted and performance share units, the cost of the service received as consideration is initially measured based on the market value of the Company’s common shares at the date of grant. The grant date fair value is recognized as compensation expense over the vesting period with a corresponding increase in liabilities. Deferred, restricted and performance share units are re-measured at each reporting date based on the market value of the Company’s common shares with changes in fair value recognized as compensation expense for the proportion of the service that has been rendered at that date.
The price of the Company’s common shares as quoted on the Nasdaq Global Select Market Composite increased from $47.36 per share at December 31, 2023, to $49.94 per share at December 31, 2024. As a result of the increase in the share price and the resulting impact on the fair value of the outstanding units, we recorded a $2 million mark-to-market expense related to share-based compensation during 2024.
Depreciation and Amortization
Depreciation and amortization was $386 million for the year ended December 31, 2024, and is comparable to the $392 million for the year ended December, 31 2023.
Finance Costs
($ Millions) | 2024 | 2023 | ||||||
Finance costs before capitalized interest | $ | 184 | $ | 172 | ||||
Less capitalized interest | (51) | (55) | ||||||
Finance costs | $ | 133 | $ | 117 | ||||
Finance costs are primarily comprised of interest on borrowings and lease obligations and were $133 million for the year ended December 31, 2024, compared to $117 million for the year ended December 31, 2023. Finance costs are higher primarily due to financing fees incurred on a bridge facility entered into in October 2024 to support the OCI Acquisition and additional interest on the new debt issued (see note 8 of our 2024 consolidated financial statements for more information). Capitalized interest relates to interest costs capitalized for the Geismar 3 project. Capitalized interest was lower compared to the year ended December 31, 2023 as Geismar 3 completed its commercial performance tests in October 2024, whereupon interest ceased to be capitalized. Refer to the Liquidity and Capital Resources section of page 19 for more information.
Finance Income and Other
($ Millions) | 2024 | 2023 | ||||||
| Finance income and other before gas supply contract mark-to-market impact | $ | 9 | $ | 31 | ||||
| New Zealand gas contract mark-to-market impact | 9 | — | ||||||
| Egypt gas supply contract mark-to-market impact | (6) | 9 | ||||||
| Finance income and other expenses | $ | 12 | $ | 40 | ||||
Finance income and other were $12 million for the year ended December 31, 2024, compared to $40 million for the year ended December 31, 2023. Finance income and other were lower during the year ended December 31, 2024 compared to the same period in 2023 primarily due to the impact of changes in foreign exchange rates, changes in interest income earned on cash balances, and the mark-to-market impact on the New Zealand and Egypt gas supply contracts.
Income Taxes
A summary of our income taxes for 2024 compared with 2023 is as follows:
($ Millions, except where noted) | 2024 | 2023 | ||||||||||||
| Per consolidated statement of income | Adjusted 1 2 | Per consolidated statement of income | Adjusted 1 2 | |||||||||||
Net income before income tax | $ | 280 | $ | 325 | $ | 286 | $ | 199 | ||||||
Income tax expense | (30) | (73) | (2) | (46) | ||||||||||
Net income after income tax | $ | 250 | $ | 252 | $ | 284 | $ | 153 | ||||||
Effective tax rate | 11% | 22% | 1% | 23% | ||||||||||
1 Adjusted effective tax rate is a non-GAAP ratio and is calculated as adjusted income tax expense or recovery, divided by adjusted net income before tax.
2 Adjusted net income before income tax and Adjusted income tax (expense) recovery are non-GAAP measures. Adjusted effective tax rate is a non-GAAP ratio. These do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Management uses these to assess the effective tax rate. These measures and ratios are useful as they are a better measure of our underlying tax rate across the jurisdictions in which we operate. See Non-GAAP Measures on page 39 for more information.
We earn the majority of our income in the United States, New Zealand, Trinidad and Tobago, Chile, Egypt and Canada. Including applicable withholding taxes, the statutory tax rate applicable to Methanex in the United States is 22%, New Zealand is 28%, Trinidad and Tobago is 38%, Chile is 35%, Egypt is 32.5% and Canada is 24.5%. We accrue for taxes that will be incurred upon distributions from our subsidiaries when it is probable that the earnings will be repatriated. As the Atlas entity is accounted for using the equity method, any income taxes related to Atlas are included in earnings of associate and therefore excluded from total income taxes but included in the calculation of Adjusted net income.
The effective tax rate based on Adjusted net income was an expense of 22% for the year ended December 31, 2024, compared to 23% for the year ended December 31, 2023. Adjusted net income represents the amount that is attributable to Methanex shareholders and excludes the mark-to-market impact of share-based compensation and the impact of certain items associated with specific identified events. The effective tax rate differs from period to period depending on the source of earnings (losses) and the impact of foreign exchange fluctuations against the United States dollar on our tax balances. In periods with low income levels or losses, the distribution of income and loss between jurisdictions can result in income tax rates that are not indicative of the longer-term corporate tax rate. In addition, the effective tax rate is impacted by changes in tax legislation in the jurisdictions in which we operate.
The following table shows a reconciliation of Net income to Adjusted net income before tax, and of Income tax expense to Adjusted income tax expense:
($ Millions, except where noted) | 2024 | 2023 | ||||||
| Net income | $ | 250 | $ | 284 | ||||
| Adjusted for: | ||||||||
| Income tax expense | 30 | 1 | ||||||
| Earnings from associate | (38) | (99) | ||||||
| Share of associate's income before tax | 54 | 152 | ||||||
| Net income before tax of non-controlling interests | (93) | (103) | ||||||
| Mark-to-market impact of share-based compensation | 3 | 16 | ||||||
| Impact of Egypt gas contract revaluation | 3 | (5) | ||||||
| Impact of New Zealand gas contract revaluation | (9) | — | ||||||
| Asset impairment charge | 125 | — | ||||||
| Gas contract settlement | — | (47) | ||||||
| Adjusted net income before tax | $ | 325 | $ | 199 | ||||
| Income tax expense | $ | (30) | $ | (1) | ||||
| Adjusted for: | ||||||||
| Inclusion of our share of associate's adjusted tax expense | (15) | (37) | ||||||
| Removal of non-controlling interest's share of tax (recovery) expense | 6 | (7) | ||||||
| Tax (recovery) expense on mark-to-market impact of share-based compensation | — | (3) | ||||||
| Tax on impact of Egypt gas contract revaluation | (1) | 2 | ||||||
| Tax on impact of New Zealand gas contract revaluation | 2 | — | ||||||
| Tax on asset impairment charge | (35) | — | ||||||
| Adjusted income tax expense | $ | (73) | $ | (46) | ||||
For additional information regarding income taxes, refer to note 16 of our 2024 consolidated financial statements.
LIQUIDITY AND CAPITAL RESOURCES
A summary of our consolidated statements of cash flows is as follows:
($ Millions) | 2024 | 2023 | ||||||
Cash flows from/(used in) operating activities: | ||||||||
Cash flows from operating activities before changes in non-cash working capital | $ | 861 | $ | 719 | ||||
Changes in non-cash working capital related to operating activities | (124) | (59) | ||||||
| 737 | 660 | |||||||
Cash flows from/(used in) financing activities: | ||||||||
Payments for the repurchase of shares | — | (86) | ||||||
Dividend payments to Methanex Corporation shareholders | (50) | (49) | ||||||
Interest paid | (169) | (169) | ||||||
| Net proceeds on issue of long-term debt | 585 | — | ||||||
| Repayment of long-term debt and financing fees | (322) | (12) | ||||||
| Repayment of lease obligations | (141) | (118) | ||||||
| Distributions to non-controlling interests | (41) | (185) | ||||||
Proceeds on exercise of stock options and movements in restricted cash | 1 | (1) | ||||||
Changes in non-cash working capital relating to financing activities | (68) | 69 | ||||||
| (205) | (551) | |||||||
Cash flows from/(used in) investing activities: | ||||||||
Property, plant and equipment | (101) | (178) | ||||||
Geismar plant under construction | (73) | (270) | ||||||
| Proceeds of share capital reduction from associate | 13 | — | ||||||
| Loan repayment from associate | 76 | — | ||||||
Changes in non-cash working capital relating to investing activities | (15) | (60) | ||||||
| (100) | (509) | |||||||
Increase (decrease) in cash and cash equivalents | 432 | (400) | ||||||
Cash and cash equivalents, end of year | $ | 892 | $ | 458 | ||||
Cash Flow Highlights
Cash Flows from Operating Activities
Cash flows from operating activities for the year ended December 31, 2024 were $737 million compared with $660 million for the year ended December 31, 2023. The increase in cash flows from operating activities is primarily due to higher operational earnings, partially offset by working capital movements.
The following table provides a summary of these items for 2024 and 2023:
($ Millions) | 2024 | 2023 | ||||||
Net income | $ | 250 | $ | 284 | ||||
Deduct earnings of associate | (38) | (99) | ||||||
Add dividends received from associate | 32 | 112 | ||||||
Add (deduct) non-cash items: | ||||||||
Depreciation and amortization | 386 | 392 | ||||||
| Income tax expense | 30 | 1 | ||||||
Share-based compensation expense | 24 | 35 | ||||||
Finance costs | 133 | 117 | ||||||
| Mark-to-market impact of Level 3 derivatives | (3) | — | ||||||
| Asset impairment charge | 125 | — | ||||||
Interest received | 15 | 22 | ||||||
Income taxes paid | (53) | (82) | ||||||
Other | (40) | (63) | ||||||
Cash flows from operating activities before changes in non-cash working capital | 861 | 719 | ||||||
Changes in non-cash working capital: | ||||||||
Trade and other receivables | 62 | (33) | ||||||
Inventories | (12) | 16 | ||||||
Prepaid expenses | (3) | (19) | ||||||
Accounts payable and accrued liabilities | (171) | (23) | ||||||
| (124) | (59) | |||||||
Cash flows from operating activities | $ | 737 | $ | 660 | ||||
For a discussion of the changes in net income, depreciation and amortization, income tax expense, share-based compensation expense (recovery) and finance costs, refer to the Financial Results section on page 13.
Changes in non-cash working capital decreased cash flows from operating activities by $124 million for the year ended December 31, 2024, compared with a decrease of $59 million for the year ended December 31, 2023. Trade and other receivables decreased in 2024 and this increased cash flows from operating activities by $62 million, primarily due to timing of invoices and payments by customers by the end of 2024 compared to 2023. Inventories increased primarily due to the higher cost of production in the fourth quarter of 2024 compared to the fourth quarter of 2023 driven by the impact of higher methanol prices on our natural gas costs, which decreased cash flows from operating activities by $12 million. Accounts payable and accrued liabilities decreased in 2024 compared to 2023 due to lower purchased methanol activity due to the start-up of Geismar 3 and the cessation of operations at Atlas. This decreased cash flows from operating activities by $171 million.
Cash Flows from Financing Activities
In 2023, we repurchased 1,894,711 common shares under a normal course issuer bid for approximately $86 million, while no repurchases were made in 2024.
Total dividend payments in 2024 were $50 million compared with $49 million in 2023, reflecting a full year of quarterly dividends of $0.185 per share following an increase from $0.175 per share in April 2023.
Total interest payments in 2024 and in 2023 were $169 million. We repaid $300 million of unsecured notes due in December 2024 with cash flows generated from operations. We also completed the financing plan for the OCI Acquisition which included issuing $600 million of unsecured notes with net proceeds of $585 million. The Company has no debt maturities until December 2027, other than normal course obligations for principal repayments related to our other limited recourse debt facilities.
Distributions to non-controlling interests, including the 50% ownership of the Egypt entity and the 40% ownership of Waterfront Shipping not attributable to Methanex, were $41 million in 2024 compared to $185 million in 2023. The lower distributions to non-controlling interests for 2024 compared to 2023 were primarily due to higher return of capital to shareholders in 2023 and changes in earnings of Egypt and Waterfront Shipping.
Cash Flows from Investing Activities
During 2024, we incurred cash outflows on capital expenditures relating to our consolidated operations of $101 million (2023 - $178 million) primarily related to planned turnarounds in Geismar, Medicine Hat, and Chile, and the restart of Titan. The 2023 capital expenditures were primarily related to related to planned turnarounds in Geismar, New Zealand and Chile. In addition, we incurred cash outflows on capital expenditures of $73 million (2023 - $270 million) related to the construction of the Geismar 3 project.
Liquidity and Capitalization
We successfully met our objective in 2024 to repay rather than re-finance $300 million of unsecured notes due at the end of 2024 and our new OCI Acquisition financing has been structured to allow the flexible repayment of the term loan commitment to support our capital allocation priority to reduce debt.
The following table provides information on our liquidity and capitalization position as at December 31, 2024, and December 31, 2023:
($ Millions, except where noted) | 2024 | 2023 | ||||||
Liquidity: | ||||||||
Cash and cash equivalents | $ | 892 | $ | 458 | ||||
Undrawn credit facility | 500 | 300 | ||||||
Total liquidity 1 | $ | 1,392 | $ | 758 | ||||
Capitalization: | ||||||||
Unsecured notes, including current portion | 2,274 | 1,986 | ||||||
Other limited recourse debt facilities, including current portion | 141 | 156 | ||||||
Total debt | 2,415 | 2,142 | ||||||
Non-controlling interests | 288 | 242 | ||||||
Shareholders’ equity | 2,094 | 1,931 | ||||||
Total capitalization | $ | 4,797 | $ | 4,315 | ||||
Total debt to capitalization 2 | 50% | 50% | ||||||
Net debt to capitalization 3 | 39% | 44% | ||||||
1 Total liquidity consists of cash and cash equivalents, as well as any undrawn amounts from facilities. Total liquidity is a non-GAAP capital management measure, see Non-GAAP Measures on page 39 for more information.
2 Defined as total debt (including other limited recourse debt facilities) divided by total capitalization.
3 Net debt to capitalization is defined as total debt (including other limited recourse debt facilities) less cash and cash equivalents divided by total capitalization less cash and cash equivalents. Net debt to capitalization is a non-GAAP capital management measure. See Non-GAAP Measures on page 39 for more information.
We manage our liquidity and capital structure in light of changes to economic conditions, the underlying risks inherent in our operations and the capital requirements for the business. Total liquidity is useful because it illustrates the extent to which management has immediate access to cash for operational and construction purposes, and is indicative of our flexibility should uses for these facilities immediately arise. Net debt to capitalization is useful because it illustrates the relative risk of our financing structure to potential lenders and investors. The strategies we have employed in managing our liquidity and capital structure include the issue or repayment of general corporate debt, the issue of project debt, the payment of dividends and the repurchase of shares.
We are not subject to any statutory capital requirements and have no commitments to sell or otherwise issue common shares except pursuant to outstanding employee stock options and TSARs.
We operate in a highly competitive commodity industry and believe that it is appropriate to maintain a strong balance sheet and maintain financial flexibility. As at December 31, 2024, we had a cash balance of $892 million, including $16 million of cash related to Egypt and $26 million of cash related to Waterfront Shipping entities consolidated on a 100% basis. We invest our cash only in highly rated instruments that have maturities of three months or less to ensure preservation of capital and appropriate liquidity.
As at December 31, 2024, we have access to a $500 million committed revolving credit facility, which is with a syndicate of highly rated financial institutions. During the year, the maturity date of the previously established $300 million revolving credit facility was renewed to April 2028 and an additional $200 million tranche was added which expires in April 2026, increasing the total amount available under the revolving credit facility as at December 31, 2024 to $500 million. To support the OCI Acquisition, the Company renewed its $500 million revolving credit facility by increasing the existing $300 million tranche to $400 million with a new five-year tenor, and the renewal of the $200 million tranche with a new three-year tenor, both from the closing date of the OCI Acquisition. Additionally, a term loan commitment of $650 million was added to partially finance the OCI Acquisition. The increase to a total availability of $600 million under the revolving credit facility and availability of the $650 million term loan commitment are subject to the closing of the OCI Acquisition.
We have covenant and default provisions under our long-term debt obligations and we also have certain covenants that could restrict access to our credit facilities. The covenants governing the unsecured notes, which are specified in indentures governing the Company, apply to the Company and its subsidiaries, excluding the Egypt entity and the Atlas joint venture entity, and include restrictions on liens, sale and lease-back transactions, a merger or consolidation with another corporation or sale of all or substantially all of our assets. The indentures also contains customary default provisions. The significant covenants and default provisions under the credit facility include:
a) the obligation to maintain a minimum interest coverage ratio of EBITDA to net interest expense greater than or equal to 2:1 calculated on a four-quarter trailing basis and a funded debt to total capitalization ratio of less than or equal to 60%, both calculated in accordance with definitions in the credit agreement that include adjustments to limited recourse subsidiaries;
b) a default if payment is accelerated by a creditor on any indebtedness of $50 million or more of the Company and its subsidiaries, except for limited recourse subsidiaries; and
c) a default if a default occurs that permits a creditor to demand repayment on any other indebtedness of $50 million or more of the Company and its subsidiaries, except for limited recourse subsidiaries.
The credit facility is secured by certain assets of the Company, and also includes other customary covenants including restrictions on the incurrence of additional indebtedness.
Other limited recourse debt facilities relate to financing for certain of our ocean going vessels which we own through less than wholly-owned entities under the Company's control. The limited recourse debt facilities are described as limited recourse as they are secured only by the assets of the entity that carries the debt. Accordingly, the lenders to the limited recourse debt facilities have no recourse to the Company or its other subsidiaries.
Failure to comply with any of the covenants or default provisions of the long-term debt facilities described above could result in a default under the applicable credit agreement that would allow the lenders to not fund future loan requests, accelerate the due date of the principal and accrued interest on any outstanding loans or restrict the payment of cash or other distributions.
As at December 31, 2024, management believes the Company was in compliance with all covenants related to its long-term debt obligations.
Capital Projects
During the year, the Geismar 3 plant successfully completed its commercial performance tests. The capital costs totaling slightly less than $1.30 billion, excluding fixed costs related to the delay. The plant completed its commercial performance tests in October and the project is now complete.
Summary of Contractual Obligations and Commercial Commitments
A summary of the amount and estimated timing of cash flows related to our contractual obligations and minimum commercial commitments as at December 31, 2024, is as follows:
($ Millions) | 2025 | 2026-2027 | 2028-2029 | After 2029 | Total | |||||||||||||||
Long-term debt repayments | $ | 14 | $ | 729 | $ | 732 | $ | 968 | $ | 2,443 | ||||||||||
Long-term debt interest obligations | 135 | 261 | 192 | 347 | 935 | |||||||||||||||
Lease obligations | 169 | 264 | 226 | 423 | 1,082 | |||||||||||||||
Repayments of other long-term liabilities | 53 | 40 | 15 | 90 | 198 | |||||||||||||||
Natural gas and other | 518 | 728 | 551 | 766 | 2,563 | |||||||||||||||
Other commitments | 86 | 39 | 33 | 2 | 160 | |||||||||||||||
| $ | 975 | $ | 2,061 | $ | 1,749 | $ | 2,596 | $ | 7,381 | |||||||||||
Long-Term Debt Repayments and Long-Term Debt Interest Obligations
We have $700 million of unsecured notes that mature in 2027, $700 million of unsecured notes that mature in 2029, $600 million of unsecured notes that mature in 2032 and $300 million of unsecured notes that mature in 2044. The remaining debt repayments represent the normal course obligations for principal repayments related to our limited recourse debt facilities. For additional information, refer to note 8 of our 2024 consolidated financial statements.
Lease obligations
Lease obligations represent contractual payment dates and amounts for right-of-use assets recognized on balance sheet. The majority of lease obligations are for ocean-going vessels.
Repayments of Other Long-Term Liabilities
Repayments of other long-term liabilities represent contractual payment dates or, if the timing is not known, we have estimated the timing of repayment based on management’s expectations.
Natural Gas and Other
We have commitments under take-or-pay contracts to purchase natural gas, to pay for transportation capacity related to the delivery of natural gas and to purchase oxygen and other feedstock requirements for our operating plants. Take-or-pay means that we are obliged to pay for the supplies regardless of whether we take delivery. Such commitments are common in the methanol industry. These contracts generally provide a quantity that is subject to take-or-pay terms that is lower than the maximum quantity that we are entitled to purchase. The amounts disclosed in the table above represent only the minimum take-or-pay quantity.
The natural gas supply contracts for our facilities in New Zealand, Trinidad and Tobago, Egypt and certain contracts in Chile are take-or-pay contracts denominated in United States dollars and include base and variable price components to manage our commodity price risk exposure. The variable price component of each natural gas contract is adjusted by a formula linked to methanol prices. We believe this pricing relationship enables these facilities to be competitive throughout the methanol price cycle. The amounts disclosed in the table for these contracts represent only the base price component representative of the minimum take-or-pay commitment.
We also have multi-year fixed price natural gas and renewable natural gas contracts and hedges to manage exposure to natural gas price risk and supply our production facilities in Geismar and Medicine Hat. We believe that the fixed price contracts, hedges and long-term natural gas dynamics in North America support the long-term operation of these facilities. In the above table, we have included natural gas commitments, not accounted for as financial instruments, in North America for Geismar and Medicine Hat at the contractual volume and fixed prices.
We have marketing rights for 100% of the production from our jointly owned Egypt plant that results in purchase commitments of up to an additional 0.6 million tonnes per year of methanol offtake supply when Egypt operates at capacity. Up to the idling of the jointly-owned Atlas plant, we also had marketing rights for 100% of the production. Upon cessation of the offtake agreement, the offtake commitment for Atlas is nil. As at December 31, 2024, the Company also had commitments to purchase methanol from other suppliers for approximately 0.8 million tonnes for 2025 and 0.4 million tonnes in aggregate thereafter. The pricing under these purchase commitments is referenced to pricing at the time of purchase or sale, and accordingly, no amounts have been included in the table above.
The above table does not include costs for planned capital maintenance or expansion expenditures for which no commitment has been made to vendors to purchase materials, as these expenditures may change, or any obligations with original maturities of less than one year.
Other Commitments
We have future minimum lease payments under leases relating primarily to vessel charter, terminal facilities, office space and equipment that are outside the scope of IFRS 16. For additional information, refer to note 22 of our 2024 consolidated financial statements.
Off-Balance Sheet Arrangements
As at December 31, 2024, we did not have any off-balance sheet arrangements, as defined by applicable securities regulators in Canada and the United States, that have, or are reasonably likely to have, a current or future material effect on our results of operations or financial condition.
Financial Instruments
A financial instrument is any contract that gives rise to a financial asset of one party and a financial liability or equity instrument of another party. Financial instruments are either measured at amortized cost or fair value.
In the normal course of business, the Company's assets, liabilities and forecasted transactions, as reported in U.S. dollars, are impacted by various market risks including, but not limited to, natural gas prices and currency exchange rates. The time frame and manner in which the Company manages those risks varies for each item based on the Company's assessment of the risk and the available alternatives for mitigating risks.
The Company uses derivatives as part of its risk management program to mitigate variability associated with changing market values. Changes in the fair value of derivative financial instruments are recorded in earnings unless the instruments are designated as cash flow hedges, in which case the changes in fair value are recorded in other comprehensive income and are reclassified to profit or loss or accumulated other comprehensive income when the underlying hedged transaction is recognized in earnings or inventory. The Company designates as cash flow hedges certain derivative financial instruments to hedge its risk exposure to fluctuations in natural gas prices and to hedge its risk exposure to fluctuations on certain foreign-currency-denominated transactions.
Until settled, the fair value of Level 2 derivative financial instruments will fluctuate based on changes in commodity prices or foreign currency exchange rates and the fair value of Level 3 derivative financial instruments will fluctuate based on changes in the observable and unobservable valuation model inputs.
The following table shows the carrying value of each of our categories of financial assets and liabilities and the related balance sheet items as at December 31, 2024 and December 31, 2023:
($ Millions) | 2024 | 2023 | ||||||
Financial assets: | ||||||||
Financial assets measured at fair value: | ||||||||
Derivative instruments designated as cash flow hedges 1 | $ | 129 | $ | 121 | ||||
Fair value of Egypt gas supply contract derivative 2 | 14 | 20 | ||||||
Fair value of New Zealand gas supply contract derivative 3 | 9 | — | ||||||
Financial assets not measured at fair value: | ||||||||
Cash and cash equivalents | 892 | 458 | ||||||
Trade and other receivables, excluding tax receivable | 454 | 515 | ||||||
Restricted cash included in other assets | 14 | 16 | ||||||
Total financial assets 4 | $ | 1,512 | $ | 1,130 | ||||
Financial liabilities: | ||||||||
Financial liabilities measured at fair value: | ||||||||
Derivative instruments designated as cash flow hedges 1 | $ | 37 | $ | 92 | ||||
Financial liabilities not measured at fair value: | ||||||||
Trade, other payables and accrued liabilities, excluding tax payable | 430 | 672 | ||||||
| Lease obligations, including current portion | 818 | 872 | ||||||
Long-term debt, including current portion | 2,415 | 2,142 | ||||||
| Land mortgage | 27 | 28 | ||||||
Total financial liabilities | $ | 3,727 | $ | 3,806 | ||||
1 Geismar natural gas hedges and Euro foreign currency hedges designated as cash flow hedges are measured at fair value based on industry-accepted valuation models and inputs obtained from active markets.
2 The Egypt natural gas supply contract is measured at fair value using a Monte-Carlo model classified within Level 3 of the fair value hierarchy.
3 The New Zealand natural gas supply contract is measured at fair value using an economic model classified within Level 3 of the fair value hierarchy.
4 The carrying amount of the financial assets represents the maximum exposure to credit risk at the respective reporting periods.
As at December 31, 2024, all of the financial instruments were recorded on the consolidated statements of financial position at amortized cost with the exception of derivative financial instruments, which were recorded at fair value unless exempted.
The fair value of derivative instruments is determined based on industry-accepted valuation models using market observable inputs and are classified within Level 2 of the fair value hierarchy and those using significant unobservable inputs classified as Level 3. The fair value of all of the Company's derivative contracts as presented in the consolidated statements of financial position are determined based on present values and the discount rates used are adjusted for credit risk. The effective portion of the changes in fair value of derivative financial instruments designated as cash flow hedges is recorded in other comprehensive income. The spot element of forward contracts in the hedging relationships is recorded in other comprehensive income as the change in fair value of cash flow hedges. The change in the fair value of the forward element of forward contracts is recorded in other comprehensive income as the forward element excluded from the hedging relationships. Once a commodity hedge settles, the amount realized during the period and not recognized immediately in the statement of income is reclassified from accumulated other comprehensive income (equity) to inventory and ultimately through cost of goods sold. Foreign currency hedges settled, are realized during the period directly to the statement of income reclassified from the statement of other comprehensive income.
The Company has entered into forward contracts designated as cash flow hedges to manage its exposure to changes in natural gas prices for Geismar. Natural gas is fungible across the Geismar plants.
The Company manages its foreign currency exposure to euro denominated sales by executing a number of forward contracts which it has designated as cash flow hedges for its highly probable forecast euro collections.
Related Party Transactions
We own 63.1% of the Atlas methanol facility and a contractual agreement with our partners establishes joint control which results in our accounting for Atlas as an equity investment. As our equity investee, Atlas is our most significant related party. Refer to note 23 to the 2024 consolidated financial statements for information on our related party transactions.
RISK FACTORS AND RISK MANAGEMENT
We are subject to risks that require prudent risk management. We believe the following risks, in addition to those described in the Critical Accounting Estimates section on page 36, to be among the most important for understanding the issues that face our business and our approach to risk management. Our strategic risk management process drives the identification, measurement, prioritization and management of our principal strategic risks. The Audit, Finance and Risk Committee of the Board provides oversight to the Company's risk management process.
Methanol Market Fundamentals
Methanol Price
The methanol business is a highly competitive commodity industry and future methanol prices will ultimately depend on the strength of global demand and methanol industry supply but can also be impacted by other factors such as global trade disputes and government sanctions. Methanol demand and industry supply are driven by several factors as described below. Methanol prices have historically been, and are expected to continue to be, characterized by cyclicality. We are not able to predict future methanol prices, which are driven by several factors that are beyond our control. Since methanol is the only product we produce and market, a decline in the price of methanol has a significant negative effect on our results of operations and financial condition.
Methanol Demand
Based on the diversity of end products in which methanol is used, demand for methanol is driven by a number of factors, including: the strength of global and regional economies, industrial production levels, energy prices, pricing of end products, downstream capacity and government regulations and policies. In addition, increasing focus on climate change and the timing and pace of the transition to a lower-carbon economy could impact the demand for methanol that is manufactured in a manner that produces GHG emissions. Changes in methanol demand based on availability of substitute products, consumer preference (including preference for low-or-zero-carbon emission products), government regulation, or other factors may have a significant negative effect on our results of operations and financial condition irrespective of energy prices or economic growth rates. We cannot provide assurance that methanol demand will not be negatively impacted and this could have an adverse effect on our results of operations and financial condition.
Energy Prices
Demand for energy-related applications, which represents over 30% of global methanol demand, includes several applications including methyl tertiary-butyl ether ("MTBE"), fuel applications (including vehicle fuel, marine fuel and other thermal applications), di-methyl ether and biodiesel. Demand into methanol-to-olefins ("MTO") represents approximately 20% of global methanol demand. MTO plants produce light olefins which have wide applications in packaging, textiles, plastic parts and automotive components.
Methanol is an alternative feedstock for the production of light olefins in the methanol-to-olefins application. MTO competes with olefins made from ethane, propane and naphtha, which are typically derived from natural gas and oil-based feedstocks. The price of methanol relative to the price of ethane, propane and naphtha can impact the competitiveness of methanol in this application. The price of olefins and downstream derivative products are also affected by their industry supply and demand fundamentals. In a low olefin product price environment, methanol could be a less competitive feedstock in the production of olefins, which could reduce demand for methanol or contribute to negative pressure on methanol prices.
Methanol can also be used to produce MTBE (an oxygenate blended into gasoline to improve air quality), blended directly with gasoline and used to produce di-methyl ether which can be blended with liquefied petroleum gas (propane). Because of this relationship, methanol demand is sensitive to the pricing of these energy products, which in turn are generally linked to global energy prices.
We cannot provide assurance that energy prices will not negatively impact methanol demand, which could have an adverse effect on our results of operations and financial condition.
Global Economic Growth Rates
Traditional chemical demand, which represents approximately 50% of global methanol demand, is used to produce traditional chemical derivatives, including formaldehyde, acetic acid and a variety of other chemicals that form the basis of a wide variety of industrial and consumer products. Over the long term, we believe that traditional chemical demand is influenced by the strength of global and regional economies and industrial production levels. Any slowdown in the global or regional economies, specifically manufacturing and industrial economies, can negatively impact demand for methanol and have a detrimental impact on methanol prices.
Methanol Supply
Methanol industry supply is impacted by the cost of production, methanol industry operating rates and methanol industry capacity changes. Methanol is produced from natural gas and is also produced from coal, particularly in China. The cost of production is influenced by the availability and cost of raw feedstock materials, freight costs, other operating and maintenance costs and government policies. An increase in economically competitive methanol supply, all else equal, can displace supply from higher cost producers and have a negative impact on methanol price. The industry has historically operated below stated capacity on a consistent basis, even in periods of high methanol prices, primarily due to shutdowns for planned or unplanned maintenance and feedstock shortages and/or uneconomical feedstock costs. Methanol industry supply can increase through improving operating rates of existing methanol plants. Methanol industry capacity can increase through the construction of new methanol plants, by restarting idle methanol plants, or by expanding or debottlenecking existing plants to increase their operating capacity. There is typically a span of four to six years to plan and construct a new world-scale methanol plant. Typical of most commodity chemicals, periods of sustained high methanol prices encourage producers to operate at maximum rates and encourage the construction of new plants and expansion projects, leading to the possibility of oversupply in the market. However, historically, many of the announced capacity additions have not been constructed for a variety of reasons. The construction of world-scale methanol facilities requires significant capital over a long lead time, a location with access to significant natural gas or coal feedstock with appropriate pricing, and an ability to market and deliver methanol cost-effectively and reliably to customers.
Operating rates continue to be uncertain and challenged due to the impact of trade sanctions, plant technical issues, and structural and seasonal natural gas constraints. The methanol industry ran at similar rates in 2024 compared to 2023. In 2024, there were approximately 1.5 million tonnes of production capacity additions in China. In North America, our new 1.8 million tonne Geismar 3 facility completed its commercial performance tests and is now operating at full rates. With the idling of Atlas and the restart of Titan in September 2024 overall production in Trinidad is lower by approximately 1 million tonnes annually. In Malaysia, we understand that a 1.8 million tonne plant started up in early 2025. We expect limited capacity additions in the next five years. In Iran, projects under development are showing slow progress due to technical and financing challenges from sanctions and the operating rates of existing methanol plants are constrained by gas availability due to depleting gas fields. If sanctions impacting Iran and/or other methanol producing countries are eased or removed, this could lead to an increase in methanol supply. China has planned capacity additions which we expect will be somewhat offset by the closure of some inefficient older plants. New capacity built in China is expected to be consumed domestically as China requires methanol imports to meet growing demand.
We cannot provide assurance that increases in methanol supply will not outpace the level of future demand growth thereby contributing to negative pressure on methanol price.
Macroeconomic Risks
Global Economic Conditions
In addition to the potential influence of global economic activity levels on methanol demand and price, changing global economic conditions can also result in changes in capital markets. A deterioration in economic conditions could have a negative impact on supply or demand for methanol, our investments, diminish our ability to access existing or future credit, and it could increase the risk of defaults by customers, suppliers, insurers and other counterparties. Also, inflationary pressures associated with buoyant economic activity, supply chain challenges or geopolitical events such as war or international trade relations, could have a negative impact on our cost structure or access to feedstock or logistics services. Considering these potential impacts, we cannot provide assurance that a deterioration in economic conditions or inflationary pressures associated with buoyant economic activity will not have an adverse impact on our results of operations and financial condition.
Global Operations
Our operations and investments are primarily located in North America, New Zealand, Trinidad and Tobago, Egypt, Chile, Europe and Asia. We are subject to risks inherent in global operations which are more significant in certain jurisdictions, such as loss of revenue, property and equipment as a result of expropriation; import or export restrictions; anti-dumping measures; nationalization, war, insurrection, civil unrest, social activism, sabotage, terrorism and other political risks; increases in duties, taxes and governmental royalties; renegotiation of contracts with governmental entities; as well as changes in laws or policies or other actions by governments that may adversely affect our operations, including lack of certainty with respect to foreign legal systems, corruption and other factors inconsistent with the rule of law. Many of the foregoing risks related to foreign operations may also exist for our domestic operations in North America. We are also subject to potential risks associated with geopolitical disputes including: (i) those between countries in which we operate, buy, sell or transport methanol, (ii) those that border such countries such as over rights to water flowing across political boundaries including the Nile river which supplies water to our Egypt plant, and (iii) significant geopolitical disputes including wars, such as the war between Ukraine and Russia or the Israel-Palestinian conflict where the globalized nature of our operations and the commodity we sell could be negatively impacted by the actions of multiple countries and stakeholders.
The Company is committed to doing business in accordance with all applicable laws and its code of business conduct, but there is a risk that it, its subsidiaries or affiliated entities or their respective officers, directors, employees or agents could act in violation of its
codes and applicable laws. Any such violation could severely damage our reputation and could result in substantial civil and criminal fines or penalties. Such damage to our reputation and fines and penalties could materially affect the Company's business and have an adverse impact on our results of operations and financial condition.
Because we derive a significant portion of our revenues from production and sales by subsidiaries outside of Canada, the payment of dividends or the making of other cash payments or advances by these subsidiaries may be subject to restrictions or exchange controls on the transfer of funds in or out of the respective countries or result in the imposition of taxes on such payments or advances.
Global Trade
Methanol is a globally traded commodity produced at facilities located around the world. Trade in methanol is subject to duty in a number of jurisdictions. Methanol sold in certain regions from the countries in which we produce methanol is currently subject to import duties ranging from 0% to 6%. As well, there is currently an additional 25% duty on methanol imported from the US to China. There is also heightened uncertainty and volatility with regards to the implementation of further tariffs between various countries in which we produce or sell methanol. Over the years, methanol demand growth has been concentrated in certain high-demand regions, while our production has also become more concentrated in certain jurisdictions. As a result, we face potential risks related to access to certain regions, as governments in key regions may impose tariffs, increase duties, or implement other trade restrictions that could limit methanol trade to or from certain jurisdictions or cause it to become uneconomical. Diversion of trade flows to avoid uneconomical consequences of such restrictions may also create longer supply chain routes at additional cost. There can be no assurance that the countries where we produce methanol will continue to have access to all sales regions, that duties or tariffs will not increase, that duties or tariffs will not be levied in other jurisdictions in the future or that we will be able to mitigate the impact of future duties or tariffs, if levied, or that future duties or tariffs will not have a significant negative effect.
Some producers and marketers of methanol may have direct or indirect contacts with countries that may, from time to time, be subject to international trade sanctions or other similar prohibitions ("sanctioned countries"). Methanol produced in sanctioned countries may sell at a lower price to methanol produced in non-sanctioned countries creating competitive price pressure for the methanol we produce. In addition to the methanol we produce, we purchase methanol from third parties under purchase contracts or on the spot market in order to meet our commitments to customers, and we also engage in product exchanges with other producers and marketers. We believe that we are in compliance with all applicable laws with respect to sales and purchases of methanol and product exchanges. However, as a result of the participation of sanctioned countries in our industry, we cannot provide assurance that we will not be exposed to reputational or other risks that could have an adverse impact on our results of operations and financial condition.
Pandemic Risk
Should a pandemic arise, measures introduced in response by governments and health authorities could lead to greater uncertainty in our business, commodity industries, energy markets and the broader global economy. Pandemic responses could lead to substantial reduction in global manufacturing and general economic activity, which in turn leads to supply constraints and supply chain disruptions, impacting the supply-demand balance and inventory levels across many industries.
A pandemic may increase our exposure to, and the magnitude of, each of the risks identified, whether they be methanol specific, macroeconomic, financial, or operational. The magnitude of the impact will depend on future developments that cannot be predicted and therefore we cannot provide assurance that a deterioration in economic conditions related to a pandemic will not have an adverse impact on our results of operations and financial condition.
Financial Risks
Taxation Risk
The Company is subject to taxes, duties, levies, governmental royalties and other government-imposed compliance costs in numerous jurisdictions, as well as to the global minimum tax as developed by the Organization for Economic Co-operation and Development (“OECD”). New taxes and/or increases to the rates at which these amounts are determined could have an adverse impact on our results of operations and financial condition.
We have organized our foreign operations in part based on certain assumptions about various tax laws (including capital gains, withholding taxes and transfer pricing), foreign currency exchange and capital repatriation laws and other relevant laws of a variety of foreign jurisdictions. While we believe that such assumptions are reasonable, we cannot provide assurance that foreign taxation or other authorities will reach the same conclusion. The results of audit of prior tax filings and the final determination of these events may have a material impact on the Company. Refer to Litigation and Legal Proceedings on page 36 for more information related to current legal matters. Further, if such foreign jurisdictions were to change or modify such laws, we could suffer adverse tax and financial consequences.
Liquidity Risk
As at December 31, 2024, we had a cash balance of $892 million, as well as an undrawn $500 million revolving credit facility with a syndicate of highly rated financial institutions. We renewed the $500 million revolving credit facility and increased the total amount available thereunder to $600 million, and a term loan commitment of $650 million was added. Both are subject to the closing of the OCI Acquisition. Our ability to maintain access to the facilities is subject to meeting certain financial covenants, including a interest coverage ratio of EBITDA to net interest expense and a funded debt to total capitalization ratio. Both ratios are calculated in accordance with definitions in the credit agreement that include adjustments related to the Company's limited recourse subsidiaries.
As at December 31, 2024, our long-term debt obligations include $2,274 million in unsecured notes and $141 million related to other limited recourse debt for ocean-going vessels (100% basis).
The covenants governing the unsecured notes, which are specified in indentures governing the Company, apply to the Company and its subsidiaries, excluding the Egypt entity and the Atlas joint venture entity, and include restrictions on liens, sale and lease-back transactions, a merger or consolidation with another corporation or a sale of all or substantially all of the Company’s assets. The indentures also contain customary default provisions.
For additional information regarding long-term debt, refer to note 8 of our 2024 consolidated financial statements.
We cannot provide assurance that we will have sufficient liquidity to fund future capital projects without incurring additional debt. Additionally, we cannot provide assurance that we will be able to access capital in the future on commercially acceptable terms or at all, or that the financial institutions providing the credit facilities will have the ability to honour future draws. Additionally, failure to comply with any of the covenants or default provisions of the long-term debt facilities described above could result in a default under the applicable credit agreement that would allow the lenders to not fund future loan requests, accelerate the due date of the principal and accrued interest on any outstanding loans or restrict the payment of cash or other distributions. Any of these factors could have a significant negative effect on our results of operations, our ability to pursue and complete strategic initiatives or on our financial condition.
Risks Related to Our Indebtedness
We monitor our level of debt for optimal leverage. Our expected leverage at closing of the OCI Acquisition is higher than it has been traditionally and to bring it down to a normalized level requires sufficient cash generation from our operating business to meet planned debt repayments. We cannot provide assurance that our operations will transpire as planned and that our target level of debt will be achieved in the timeline anticipated.
Foreign Currency Risk
The dominant currency in which we conduct business is the United States dollar, which is also our reporting currency. The most significant components of our costs are natural gas feedstock and ocean-shipping costs and substantially all of these costs are incurred in United States dollars. Some of our underlying operating costs, capital expenditures and purchases of methanol, however, are incurred in currencies other than the United States dollar, principally the Canadian dollar, the Chilean peso, the Trinidad and Tobago dollar, the New Zealand dollar, the euro, the Egyptian pound, the Chinese yuan and Korean won. We are exposed to increases in the value of these currencies that could have the effect of increasing the United States dollar equivalent of cost of sales, operating expenses and capital expenditures. A portion of our revenue is earned in Chinese yuan, euros, Canadian dollars and, to a lesser extent, other currencies. We are exposed to declines in the value of these currencies compared to the United States dollar, which could have the effect of decreasing the United States dollar equivalent of our revenue.
Customer Credit Risk
Our customers are large global or regional petrochemical manufacturers or distributors and a number are highly leveraged, though we have not experienced significant credit losses in the past. We monitor our customers’ financial status closely; however, some customers may not have the financial ability to pay for methanol in the future and this could have an adverse effect on our results from operations and financial condition.
Insurance Risks
Although we maintain operational and construction insurance, including business interruption insurance, we cannot provide assurance that we will not incur losses beyond the limits of, or outside the coverage of, such insurance or that insurers will be financially capable of honouring future claims. From time to time, various types of insurance for companies in the chemical and petrochemical industries have not been available on commercially acceptable terms or, in some cases, have been unavailable. We cannot provide assurance that in the future we will be able to maintain existing coverage or that premiums will not increase substantially.
Operational Risks
Security of Natural Gas Supply and Price
Natural gas is the principal feedstock for producing methanol and it accounts for a significant portion of our operating costs. Accordingly, our results from operations depend in large part on the availability and security of supply and the price of natural gas. If, for any reason, we are unable to obtain sufficient natural gas for any of our plants on commercially acceptable terms or we experience interruptions in the supply of contracted natural gas, we could be forced to curtail production or shut down such plants, which could have an adverse effect on our results of operations and financial condition.
United States
With our new 1.8 million tonne Geismar 3 facility reaching commercial production in 2024, we now have three plants in Geismar, Louisiana with an annual operating capacity of 4.0 million tonnes.
We utilize a combination of fixed price financial hedges and fixed price physical gas supply agreements to manage natural gas price risk for our Geismar facilities. In the United States, we have fixed price gas supply contracts and hedges in place targeting minimum operating rate requirements of approximately 70% in the near-term, declining over time. The balance of our gas requirements are purchased at spot prices.
We believe that the long-term natural gas dynamics in North America will support the long-term operations of these facilities; however, we cannot provide assurance that our contracted suppliers will be able to meet their commitments or that we will be able to secure additional natural gas on commercially acceptable terms and this could have an adverse impact on our results of operations and financial condition.
Trinidad and Tobago
We have two plants in Trinidad and Tobago, Atlas (Methanex interest 63.1%) and Titan, with Methanex's interest in Trinidad and Tobago representing an operating capacity of 2.0 million tonnes per year. Natural gas for our Titan plant is supplied by the National Gas Company of Trinidad and Tobago Limited ("NGC"), pursuant to a two-year take-or-pay contract that commenced in September 2024. The Titan plant successfully restarted operations in September 2024, having previously been idled in the first quarter of 2020. The natural gas sale agreement for Titan is a take-or-pay contract with the NGC, which purchases the natural gas from upstream gas producers. The contract has a U.S. dollar base and variable price components, where the variable portion is adjusted by a formula linked to methanol prices above a certain level.
The legacy natural gas agreement for our Atlas methanol production facility in Trinidad and Tobago, with our share of total production capacity being 1.1 million tonnes per year, expired in September 2024, after which the plant was idled.
We cannot provide assurance that our contracted supplier will be able to meet their commitments, that we will be able to secure additional natural gas on commercially acceptable terms or that exploration and development activities in Trinidad and Tobago will be successful to enable us to operate at capacity or at all. These factors could have an adverse impact on our results of operations and financial condition.
New Zealand
We have two plants located at Motunui in New Zealand with a total operating capacity of 1.7 million tonnes of methanol per year. In September 2024, we restructured our operations in New Zealand to support a one-plant operation, and idled one of the Motunui plants. A third plant located at nearby Waitara Valley was idled indefinitely in the first quarter of 2021. The plants were idled due to a lack of available gas supply. We have agreements with various natural gas suppliers with terms that range in length up to 2029. All gas supply agreements in New Zealand are take-or-pay agreements and include U.S. dollar base and variable price components where the variable price component is adjusted by a formula linked to methanol prices above a certain level. We believe this pricing relationship enables New Zealand methanol production to be competitive at all points in the methanol price cycle. Certain contracts require the supplier to deliver a minimum amount of natural gas with additional volume dependent on the success of exploring and developing the related natural gas field. Supplier upstream development activities have not delivered the expected gas production results and have resulted in reduced gas quantities delivered under our contracts.
The future operation of our New Zealand facilities depends on the ability of our contracted suppliers to meet their commitments and the success of ongoing exploration and development activities in the region. We cannot provide assurance that our contracted suppliers will be able to meet their commitments or that exploration and development activities in New Zealand will be successful to enable us to operate at capacity or at all. We cannot provide assurance that we will be able to secure additional natural gas on commercially acceptable terms. These factors could have an adverse impact on our results of operations and financial condition.
Chile
We have two long-term natural gas supply agreements for our two plants in Chile with each of Empresa Nacional del Petróleo ("ENAP") and YPF S.A. ("YPF"). As of 2024, gas agreements and gas export permits from Argentina provide for sufficient gas to allow for a two-plant operation in Chile during the southern hemisphere summer months. Both of these long-term supply agreements are subject to deliver-or-pay and take-or-pay provisions. In 2024, both plants operated at full capacity for seven months during the southern hemisphere summer, and one plant operated at close to minimum capacity production levels for the remaining five months of the year.
Our primary Chilean natural gas supplier, ENAP, has made significant investments over the past several years in the development of natural gas from unconventional reservoirs, which has resulted in stable gas deliveries from ENAP to our facilities. In August 2024, Methanex extended its gas supply agreement with ENAP until 2030. In August 2024 we extended our gas supply agreement with YPF securing gas until the end of 2027.
In addition, in 2024, we received natural gas from Argentina from four different natural gas suppliers pursuant to firm supply agreements from January through April and from September through December. Each of the four supply agreements were subject to deliver-or-pay and take-or-pay provisions. We have similar firm contracts for 2025 in place. The price paid for natural gas for our Chilean facilities from our Chilean and Argentine suppliers is a U.S. dollar base price plus a variable price component that is adjusted by a formula linked to methanol prices above a certain level.
While we continue to work with gas suppliers in Chile and Argentina to secure sufficient natural gas to sustain our Chile operations, we cannot provide assurance that our contracted suppliers will be able to meet their commitments, that we will be able to secure additional natural gas on commercially acceptable terms, that Argentina will grant future export permits for natural gas to be delivered to Chile or that exploration and development activities in Chile and Argentina will be successful to enable us to operate at capacity or at all. These factors could have an adverse impact on our results of operations or financial condition.
Egypt
We have a 25-year, take-or-pay natural gas supply agreement expiring in 2035 for the 1.3 million tonne per year methanol plant in Egypt in which we have a 50% equity interest. The price paid for gas is based on a U.S. dollar base price plus a variable price component that is adjusted by a formula linked to methanol prices above a certain level. Under the contract, the gas supplier is obligated to supply, and we are obliged to take or pay for, a specified annual quantity of natural gas. In addition, the natural gas supply agreement has a mechanism whereby we are partially compensated when gas delivery shortfalls in excess of a certain threshold occur. Natural gas is supplied to this facility from the same gas delivery grid infrastructure that supplies other industrial users in Egypt, as well as the general Egyptian population.
Our Egypt facility has experienced gas restrictions in the past during periods of significant social unrest and government transition and we believe this contributed to past constraints in the development of natural gas reserves. Over the past few years demand for natural gas for power generation has increased substantially while domestic natural gas supply has declined, increasing reliance on pipeline and LNG imports to meet demand. This has contributed to recent gas curtailments to our plant, particularly during the summer months when demand for natural gas for power generation is at its peak. The restrictions experienced in recent periods may occur in the future. We cannot provide assurance that our contracted supplier will be able to meet its commitments or that exploration and development activities in Egypt will be successful to enable us to operate at capacity or at all. These factors could have an adverse impact on our results of operations and financial condition.
Canada
We have entered into fixed price contracts to supply 80-90% of our natural gas requirements for our Medicine Hat facility through 2031. The balance of our gas requirements is purchased under contracts at spot prices.
We cannot provide assurance that our contracted suppliers will be able to meet their commitments or that we will be able to secure additional natural gas for our Medicine Hat facility on commercially acceptable terms and this could have an adverse impact on our results of operations and financial condition.
Production Risks
Most of our earnings are derived from the sale of methanol produced at our plants. Many of our methanol plants have been in operation for multiple decades and with appropriate maintenance they are still capable of operating safely, efficiently and cost-effectively today. Our business is subject to the risks of operating methanol production facilities, such as a process safety event, equipment breakdowns, interruptions in the supply of natural gas and other feedstocks, including oxygen and utilities such as water and steam, power failures, longer-than-anticipated planned maintenance activities, loss of port facilities, natural disasters or any other event, including unanticipated events beyond our control, that could result in a prolonged shutdown of any of our plants or impede our ability to produce and deliver methanol to customers. A prolonged plant shutdown at any of our major facilities could have an adverse effect on our results of operations and financial condition.
Capital Projects
Our ability to effectively allocate capital, including successfully identifying, developing, constructing, completing, and starting up capital projects is subject to a number of risks, including finding and selecting favourable locations for new facilities where sufficient natural gas and other feedstock is available with acceptable commercial terms, obtaining project or other financing on satisfactory terms, constructing, completing, and starting up the projects within the contemplated budgets and schedules, and other risks commonly associated with the design, construction, completion, and startup of large complex industrial projects. Further risks include the impact of evolving government regulation relating to carbon intensive industries and evaluating the technological feasibility and anticipated operation of new plant designs such as those with lower carbon intensity.
We cannot provide assurance that we will be able to effectively allocate capital to identify or develop methanol projects or that any changes to the targeted timing of construction, completion, and start up or estimated cost or ability to construct, complete, and start up capital projects or future ability to operate at production capacity, due to a number of factors, which could have an adverse impact on our results of operations and financial condition.
Acquisition of OCI Global's Methanol Business
The OCI Acquisition involves various risks that may have a negative effect on our results of operations and financial condition.
Closing of the Acquisition
The closing of the OCI Acquisition is subject to the receipt of required regulatory approvals and the satisfaction of certain closing conditions. There is no certainty, nor can we provide any assurance, that these conditions will be satisfied or, if satisfied, when they will be satisfied. If the conditions to the closing of the OCI Acquisition are not satisfied or waived, it will not be completed. If the OCI Acquisition is not completed as contemplated, we could suffer adverse consequences, including the loss of investor confidence. Any delay in completing the OCI Acquisition could cause us not to realize some or all of the benefits that we expect to achieve if the acquisition is successfully completed within the expected timeframe.
Inclusion of Joint Venture in the OCI Acquisition
Approximately 40% of the gross transaction and operating metrics in respect of the OCI Acquisition are attributable to the OCI global methanol business's 50% joint venture interest in Natgasoline. If the dispute between OCI and its joint venture partner in Natgasoline is not successfully resolved and Methanex exercises its right to carve the Natgasoline interest out of the acquisition, the benefits of the acquisition to Methanex may not be as significant as anticipated. If the dispute is not successfully resolved and we nonetheless determine to proceed with the acquisition of the Natgasoline interest, the anticipated benefit of acquiring the interest in Natgasoline could be adversely impacted by the ongoing dispute.
Failure to Realize Anticipated Benefits
There is a risk that some or all of the expected benefits of the OCI Acquisition may fail to materialize, may cost more to achieve or may not occur within the time periods that we anticipate. The realization of such benefits may be affected by a number of factors, many of which are beyond our control. Realization of the anticipated benefits of the OCI Acquisition will also depend in part on management’s ability to successfully achieve the anticipated growth opportunities and synergies from the acquisition.
Unexpected Costs
The decision to acquire OCI's global methanol business is based in large part on engineering, environmental, commercial and economic assessments made by independent engineers, consultants, and directly by us. These assessments include a series of assumptions regarding factors such as commodity pricing, non-commodity input costs, plant operating rates and efficiencies, market interest rates, government policies, among others. Many of these factors are subject to change and are beyond our control. All such assessments involve a measure of engineering, environmental, commercial and regulatory uncertainty that could result in lower income or higher operating or capital expenditures than anticipated.
In connection with the OCI Acquisition, there may be liabilities that we failed to discover or was unable to quantify in the due diligence conducted prior to the execution of the acquisition agreement, which does not contain any indemnities for breached representations and warranties, The discovery or quantification of any material liabilities could have a material adverse effect on our results of operations and financial condition.
Significant Demands of Managing a Business Combination
As a result of the combination of our business with OCI's global methanol business, significant demands will be placed on our operational and financial personnel and systems as well as those of OCI's global methanol business. We cannot provide assurance that the collective systems, procedures and controls will be adequate to support the expansion of operations following and resulting from the combination of the businesses. The future operating results of the combined company will be affected by the ability of our officers and key employees to manage changing business conditions and to implement and expand our operational and financial controls and reporting systems in response.
Significant Transaction Costs
We expect to incur significant costs and expenses associated with completing the OCI Acquisition and integrating the acquired business with our operations, and additional unanticipated costs may yet be incurred. Any expected elimination of duplicative costs and the expected realization of other operational synergies, which may offset incremental transaction and transaction-related costs over time, may not be achieved as projected, or at all.
Further, while we anticipate that certain expenses will be incurred, such expenses are difficult to estimate accurately, and may exceed current estimates. Accordingly, unexpected costs incurred or delays in integrating the acquired business with our existing business and assets could have a negative effect on our results of operations and financial condition.
Exposure to Litigation
We may be exposed to litigation from customers, suppliers, shareholders or other third-parties in connection with the OCI Acquisition. Such litigation may have an adverse impact on our business and results of operations or may cause disruptions to our operations. Even if any such claims are without merit, defending against such claims can result in substantial costs and divert the time and resources of management. Furthermore, public attitudes towards the OCI Acquisition could result in negative press coverage and other adverse public statements. Adverse press coverage and other adverse statements could negatively impact our ability to achieve the benefits of the OCI Acquisition or take advantage of various business and market opportunities. The direct and indirect effects of negative publicity, and the demands of responding to and addressing it, may have a material adverse effect on our business, financial condition, results of operations and cash flows.
Securities class action lawsuits and derivative lawsuits are often brought against companies that have entered into acquisition agreements. Even if the lawsuits are without merit, defending against these claims can result in substantial costs and divert management time and resources. Additionally, if a plaintiff is successful in obtaining an injunction prohibiting consummation of the OCI Acquisition, then that injunction may delay or prevent the OCI Acquisition from being completed.
Technological Risks
New technologies for natural-gas-based methanol production have been primarily incremental rather than transformational. Alternative feedstocks and methods for methanol production, including producing methanol from renewable resources exist today, but are not currently economically competitive at scale. The adoption of new technologies for methanol production or methanol derivatives, including those that reduce the GHG emissions intensity, may make our plants less competitive or obsolete over time. In addition, implementing technologies to reduce GHG emissions, including carbon capture and storage, could result in significant capital expenditures.
As a result, we cannot provide assurance that new technologies in methanol production will not have an adverse effect on our results of operations and financial condition.
Joint Arrangement Risk
Certain Methanex assets are jointly held and are governed by partnership and shareholder agreements. As a result, certain decisions regarding these assets require a simple majority, while others require 100 percent approval of the owners. In addition, certain of these assets (ocean-going vessels) are operated by unrelated third-party entities. The operating results of these assets is to some extent dependent on the effectiveness of the business relationship and decision making among Methanex and the other joint owner(s) and the expertise and ability of these third-party operators to successfully operate and maintain the assets. While Methanex believes that there are prudent governance and contractual rights in place, there can be no assurance that Methanex will not encounter disputes with partners. Such events could impact operations or cash flows of these assets which, in turn, could have an adverse effect on our results of operations and financial condition.
Purchased Product Price Risk
In addition to the sale of methanol produced at our plants, we also purchase methanol produced by others on the spot market and through purchase contracts to meet our customer commitments and support our marketing efforts. We have adopted the first-in, first-out method of accounting for inventories and it generally takes between 30 and 60 days to sell the methanol we purchase. Consequently, we have the risk of holding losses on the resale of this product to the extent that methanol prices decrease from the date of purchase to the date of sale. Holding losses, if any, on the resale of purchased methanol could have an adverse effect on our results of operations and financial condition.
Supply Chain Risks
Our production is transported through various pipelines, terminals, marine, rail and road networks making up our integrated supply chain. These networks, and ultimately our supply chain, may be interrupted by means outside of our control or have operational constraints or restrictions that could prohibit the safe and timely transportation and distribution of methanol to our customers and prolonged disruptions could have an adverse effect on our results of operations, financial condition and leadership position.
Shipping Capacity Risks
Excess capacity within our fleet of ocean vessels resulting from a prolonged plant shutdown or other event could have an adverse effect on our results of operations and financial condition as our vessel fleet is subject to fixed time charter costs. In the event we have excess shipping capacity, we may be able to mitigate some of the excess costs by entering into sub-charters or third-party backhaul arrangements, although the success of this mitigation is dependent on conditions within the broader global shipping industry. If we suffer any disruptions in our distribution system and are unable to mitigate these costs, this could have an adverse effect on our results from operations and financial condition.
Talent Attraction and Retention Risks
The safe and reliable operation of our methanol plants, logistics and supporting functions rely on a skilled and experienced workforce. We compete for skilled employees in various locations globally where labour market conditions can be highly competitive. If we are unable to attract, develop, and retain a skilled and experienced workforce or effectively manage succession in key roles, this may be an impediment to the operations of our methanol plants, the optimization of logistics and impact our daily operations which could have an adverse impact on our results of operations and financial condition.
Cybersecurity Risks
Our business processes rely on Information Technology ("IT") systems that are interconnected with external networks and increasingly hosted by third parties in the cloud. The interconnection of external networks increases the threat of cyberattack and the importance of cybersecurity. Cyberattacks are becoming increasingly sophisticated, particularly with the use of artificial intelligence. In particular, if a cyberattack was targeted at our production facilities, our supply chain or other key infrastructure networks, the result could harm our plants, customers, environment, people and our ability to meet customer commitments for a period of time. In addition, targeted attacks on our systems (or third parties that we rely on), failure of a key IT system or a breach in security measures designed to protect our IT systems, including attempts to divert financial assets or introduce ransomware to extract payment could have an adverse impact on our results of operations, financial condition and reputation. We have previously been the subject of cyber attacks on our internal systems, but these incidents have not had a significant negative impact on our results of operations.
We have a comprehensive program in place to protect our assets, detect malicious activity and respond in the event of a cybersecurity incident. This includes: cyber education for our staff; risk-prioritized controls to protect against known and emerging threats; segregating core operating systems from our corporate systems; tools to provide automated monitoring and alerting; incident response planning and testing to ensure an agile response and backup and recovery procedures to restore systems and return to normal operations. We may be required to commit additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerabilities to cyberattacks.
As the cyberthreat landscape continues to evolve, we pivot to adjust or add to our existing controls to protect the organization. We collect, use and store sensitive data in the normal course of business, including intellectual property, proprietary business information and personal information of our employees and third parties. Despite our security measures in place, our IT systems may be vulnerable to cyberattacks or breaches. In addition, the use of artificial intelligence tools may increase our exposure to data privacy and security risks. Any such breach could compromise information used or stored on our IT systems and/or networks and, as a result, the information could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, regulatory penalties or other negative consequences, including disruption to our operations and damage to our reputation, which could have an adverse impact on our results of operations and financial condition.
Reputational Risk
Damage to our reputation could result from the actual or perceived occurrence of any number of events, and could include any negative publicity (for example, with respect to our handling of environmental, GHG emissions, employment, health or safety, or process safety matters), whether true or not. There is a risk of increasing stakeholder expectations around climate change and transition to a lower-carbon economy. Further risks arise from these changing stakeholder perceptions related to the way in which we are viewed as contributing to (or hindering) a transition to a low-carbon economy and responding to climate change. In March 2025, we issued our 2024 Sustainability Report, aligned with the Sustainability Accounting Standards Board (SASB) and the Task-Force on Climate-related Financial Disclosures (TCFD).The Report is also a transitional report as we shift towards CSRD and European Sustainability Reporting Standards requirements for 2025. The 2024 Sustainability Report is available at https://www.methanex.com/sustainability. Our reputation could be impacted by evolving perceptions of carbon-intensive industries, petrochemical industries and, most specifically, the methanol industry and its associated downstream derivatives. Although we believe that we conduct our operations in a prudent manner and that we take care in protecting our reputation, we do not ultimately have direct control over how we are perceived by others. Reputation loss may result in decreased access to capital and insurance coverage, decreased investor confidence, challenges with employee retention and talent attraction, an impediment to our overall ability to advance our projects, difficulty in obtaining permits, or increased challenges in maintaining our social license to operate, which could have an adverse impact on our results of operations and financial condition.
Climate Related Risks
Transition Risks - Regulatory
GHG Legislation
We generate GHG emissions, primarily as carbon dioxide ("CO2"), directly and indirectly through the production, distribution and use of methanol. GHG emissions are a byproduct of the development and extraction of hydrocarbons, including natural gas used as a feedstock in methanol production, as well as the methanol production process. GHG emissions are also generated when fuel is consumed during the global transport of methanol. The GHG Protocol Corporate Standard classifies a company’s GHG emissions into three ‘scopes’. Scope 1 emissions are direct emissions from owned or controlled sources. Scope 2 emissions are indirect emissions from the generation of purchased energy. Scope 3 emissions are all indirect emissions (not included in Scope 2) that occur in the value chain, including both upstream and downstream emissions.
We monitor and manage our GHG emissions intensity for Scope 1 and Scope 2 emissions, defined as the equivalent quantity of CO2 released per unit of production or transported tonne, relating to both methanol equity production and our owned marine operations. The amount of GHG emissions generated by the methanol production process is highly dependent on a number of factors including the design of the methanol plant, plant reliability and availability of natural gas. Similarly, the distance of trade routes, volume of transported cargo, as well as ship technology and operating efficiency, influence the emissions intensity of our marine operations. Accordingly, GHG emissions may vary from year to year depending on the mix of production assets and vessels and their respective operations.
Public attitudes around climate change and the transition to a lower-carbon economy continue to evolve. Under the Paris Agreement within the United Nations Framework Convention on Climate Change, many of the countries we operate in have agreed to put forth substantial efforts and commitments to reduce GHG emissions that they are implementing through GHG regulations that include carbon prices. We are currently subject to GHG regulations in New Zealand, Canada and Chile, while our production in the United States, Trinidad and Tobago, and Egypt is currently not subject to such regulations. These regulations result in additional costs to produce methanol. Many of our competitors produce methanol in countries with no imposed GHG regulations or carbon taxes and as such, further increases in regulations or carbon taxes in the countries in which we operate may negatively impact our competitive position within the methanol industry. In addition, as of January 2024, Waterfront Shipping is subject to the EU’s Emissions Trading System (ETS) for fifty percent of emissions from voyages where the point of origin or the point of destination is within the EU and 100 percent of emissions that occur for voyages between two EU ports and when ships are within EU ports. In 2025, Waterfront Shipping will need to purchase and surrender 70 percent of EU ETS credits for shipping emissions within the EU and 100 percent in 2026. There are ongoing reviews and potential changes to government GHG regulations in countries where we have operations or conduct business, including potential carbon border adjustment mechanisms that could impact the efficient management of our global supply chain.
We cannot provide assurance that changes in existing or the introduction of new GHG regulations, carbon taxes, or other initiatives related to climate change in jurisdictions where we have operations or conduct business will not have an adverse impact on our results of operations and financial condition.
Marine Demand
The European Union and the International Maritime Organization (IMO) are moving to regulate maritime GHG emissions on a lifecycle basis, which includes upstream production, transport and storage. They have also set multiple maritime decarbonization targets that variously imply the requirement to decrease the GHG emissions intensity of energy used by ships, reduce absolute emissions from shipping as a whole, and increase uptake of zero and near zero ("ZNZ") emission fuels. Regulation that is intended to enable and ensure these targets are met, and which has the potential to effectively drive the uptake of low carbon fuels, includes the EU's FuelEU Maritime that took effect on January 1, 2025, and the IMO's "midterm measures", which are anticipated to take effect during 2027. Low-carbon methanol is one of several potential fuels that could be used to comply with these regulations. We cannot provide assurance that low-carbon methanol will be the preferred fuel for demand under shipping or clean fuel regulations.
Physical Impacts
Climate change poses a number of potential risks and impacts to Methanex that may increase over time. The prospective impact of climate change may have an adverse impact on our operations, our suppliers or customers. The physical impacts of climate change may include water scarcity, changing sea or river levels, changing storm patterns and intensities, and changing temperature levels, and the impact of any of these changes could be severe.
The New Zealand, Geismar, Medicine Hat and Egypt facilities rely on access to fresh water in the methanol production process. Potential shortages or constraints in fresh water supply could impact methanol production at these sites and may impact considerations of future growth locations. Our other two sites, Trinidad and Chile, rely on ocean water and have equipment to desalinate water for the methanol production process.
Our transport of methanol relies primarily on vessels to ship methanol from our production sites to customers around the world. We have, at times, experienced logistics delays in our supply chain due to high and low river or canal levels in exporting methanol from a production site or delivering methanol by vessel or barge to customers. High or low river levels impacting our production assets and supply chain, more severe and frequent storms and weather events could have a material adverse impact on our operating capacity and supply chain. We cannot predict, at this time, the prospective impact of climate change on our operations, suppliers or customers, which could have an adverse impact on our results of operations and financial condition.
Regulatory and Compliance Risks
Environmental Regulation
The countries in which we operate and international and jurisdictional waters in which our vessels operate have laws, regulations, treaties and conventions in force to which we are subject, governing the environment and the management of natural resources as well as the handling, storage, transportation and disposal of hazardous or waste materials. We are also subject to laws and regulations governing emissions and the import, export, use, discharge, storage, disposal and transportation of toxic substances. The products we use and produce are subject to regulation under various health, safety and environmental laws. Non-compliance with these laws and regulations may give rise to compliance orders, fines, injunctions, civil liability and criminal sanctions.
Laws and regulations with respect to protecting the environment have become more stringent over time and may, in certain circumstances, impose absolute liability rendering a person liable for environmental damage without regard to negligence or fault on the part of such person. Such laws and regulations may also expose us to liability for the conduct of, or conditions caused by others or for our own acts even if we complied with applicable laws at the time such acts were performed. To date, environmental laws and regulations have not had a significant adverse effect on our capital expenditures, earnings or competitive position. However, operating petrochemical manufacturing plants and distributing methanol exposes us to risks in connection with compliance with such laws and we cannot provide assurance that we will not incur significant costs or liabilities in the future.
Although we have formal and proactive compliance management systems in place, we cannot provide assurance over ongoing compliance with existing legislation or that future laws and regulations to which we are subject governing the environment and the management of natural resources as well as the handling, storage, transportation and disposal of hazardous or waste materials will not have an adverse effect on our results of operations and financial condition.
Government Regulations and Policies – Methanol
Changes in environmental, health and safety laws, regulations or requirements in any country where methanol is produced or consumed could impact methanol demand. Methanol is subject to the chemical control laws of the countries in which they are located. These laws include the regulation of chemical substances and inventories under the Toxic Substances Control Act (“TSCA”) in the U.S. and the Registration, Evaluation and Authorization of Chemicals (“REACH”) and the Classification, Labeling and Packaging of substances and mixtures (“CLP”) regulations in Europe.
Above certain inhalation and ingestion levels, methanol is toxic to humans. In past years, the United States Environmental Protection Agency ("EPA") had assessed methanol for carcinogenicity and issued levels of maximum ingestion and inhalation that it claims will not result in adverse health impacts. While methanol is not currently on the priority list of chemicals to be evaluated under the Toxic Substances Control Act, we are unable to determine whether the current classifications relating to the carcinogenicity of methanol will be maintained or if other government agencies will take actions related to methanol. Any further action or reclassification of methanol could reduce future methanol demand, which could have an adverse effect on our results of operations and financial condition.
Government Regulations and Policies – Methanol-Derived Products
Similar to methanol, methanol-derived chemical products are subject to the chemical control laws of the countries in which they are located. These laws include the regulation of chemical substances and inventories under the Toxic Substances Control Act (“TSCA”) in the U.S. and the Registration, Evaluation and Authorization of Chemicals (“REACH”) and the Classification, Labeling and Packaging of substances and mixtures (“CLP”) regulations in Europe. Analogous regimes exist in other parts of the world, including China, South Korea, and Taiwan. In addition, a number of countries where our customers operate, including the U.K., have adopted rules to conform chemical labeling in accordance with the globally harmonized system. Many of these foreign regulatory regimes are in the process of a multi-year implementation period for these rules.
In the US, changes to the US Environmental Protection Agency's risk evaluation process under the TSCA could also result in additional restrictions or bans of methanol-derived products, such as formaldehyde. The EPA released risk evaluation findings for formaldehyde in 2024. These are under review by the EPA.
In 2023, global methanol demand for the production of formaldehyde represented approximately 25% of global methanol demand and is the largest demand segment. The largest use for formaldehyde is as a component of urea-formaldehyde and phenol-formaldehyde resins, which are used in adhesives for plywood, particleboard, oriented strand board, medium-density fibreboard and other reconstituted or engineered wood products. There is also demand for formaldehyde as a raw material for engineering plastics and in
the manufacture of a variety of other products, including elastomers, paints, building products, foams, polyurethane and automotive products.
Assessments under TSCA may result in heightened concerns about methanol-derived products and may result in additional requirements or bans being placed on the production, handling, labeling or use of those chemicals. Any such actions could reduce future methanol demand for use in producing methanol-derived products and could have an adverse effect on our results of operations and financial condition.
Litigation and Legal Proceedings
The Company is subject, from time to time, to litigation and may be involved in disputes with other parties in the future, which may result in litigation and claims under such litigation may be material. Various types of claims may be raised in these proceedings, including, but not limited to breach of contract, product liability, tax, employment matters and in relation to an attack, breach or unauthorized access to Methanex's information technology and infrastructure, environmental damage, climate change and the impact thereof, antitrust, bribery, and other forms of corruption. The Company cannot predict the outcome of any litigation. Defense and settlement costs may be substantial, even with respect to claims that have no merit. If the Company cannot resolve these disputes favourably, its business, financial condition, results of operations and future prospects may be materially adversely affected.
Trinidad and Tobago
The Board of Inland Revenue of Trinidad and Tobago ("the "BIR") has audited and issued assessments against our 63.1% owned joint venture, Atlas, in respect of the 2005 to 2017 financial years. All subsequent tax years remain open to assessment. The assessments relate to the pricing arrangements of certain long-term fixed-price sales contracts with affiliates that commenced in 2005 and continued with affiliates through 2014 and with an unrelated third party through 2019. The long-term fixed-price sales contracts with affiliates were established as part of the formation of Atlas and management believes these were reflective of market considerations at that time.
During the periods under assessment and continuing through 2014, approximately 50% of Atlas-produced methanol was sold under these fixed-price contracts. From late 2014 through 2019 fixed-prices sales to an unrelated third party represented approximately 10% of Atlas-produced methanol. Atlas had partial relief from corporation income tax until late July 2014.
The Company believes it is impractical to disclose a reasonable estimate of the potential contingent liability due to the wide range of assumptions and interpretations implicit in the assessments.
The Company has lodged objections to the assessments. No deposits have been required to lodge objections. Although there can be no assurance that these tax assessments will not have a material adverse impact, based on the merits of the case and advice from legal counsel, we believe our position should be sustained, that Atlas has filed its tax returns and paid applicable taxes in compliance with Trinidadian tax law, and as such has not accrued for any amounts relating to these assessments. Contingencies inherently involve the exercise of significant judgment, and as such the outcomes of these assessments and the financial impact to the Company could be material.
During 2024, the Trinidad tax court issued a ruling in the Company's favour. At present, the BIR is reviewing whether to proceed with an appeal and should it decide to proceed, the Company will continue to defend its position. We anticipate the resolution of this matter through the court systems may be lengthy and, at this time, cannot predict a date as to when we expect this matter to be ultimately resolved.
CRITICAL ACCOUNTING ESTIMATES
We believe the following selected accounting policies and issues are critical to understanding the estimates, assumptions and uncertainties that affect the amounts reported and disclosed in our consolidated financial statements and related notes. Certain of our accounting policies, including depreciation and amortization, recoverability of asset carrying values, leases, income taxes and fair value measurement of financial instruments require us to make assumptions relating to operations and about the price and availability of natural gas feedstock. See additional discussion of the risk factors and risk management by region in the Security of Natural Gas Supply and Price section on page 29. See note 2 to our 2024 consolidated financial statements for our material accounting policies.
Property, Plant and Equipment
Our business is capital intensive and has required, and will continue to require, significant investments in property, plant and equipment. As at December 31, 2024, the net book value of our property, plant and equipment was $4.2 billion.
Capitalization
Property, plant and equipment are initially recorded at cost. The cost of purchased equipment includes expenditures that are directly attributable to the purchase price, delivery and installation. The cost of self-constructed assets includes the cost of materials and direct labour, any other costs directly attributable to bringing the assets to the location and condition for their intended use, the costs of dismantling and removing the items and restoring the site on which they are located, and borrowing costs on self-constructed assets that meet certain criteria. Routine repairs and maintenance costs are expensed as incurred.
As at December 31, 2024, we had accrued $38 million for site restoration costs relating to the decommissioning and reclamation of our methanol production sites. Inherent uncertainties exist in this estimate because the restoration activities will take place in the future and there may be changes in governmental and environmental regulations and changes in removal technology and costs. It is difficult to estimate the future costs of these activities as our estimate of fair value is based on current regulations and technology. Because of uncertainties related to estimating the cost and timing of future site restoration activities, future costs could differ materially from the amounts estimated.
Depreciation and Amortization
Depreciation and amortization is generally provided on a straight-line basis at rates calculated to amortize the cost of property, plant and equipment from the commencement of commercial operations over their estimated useful lives to estimated residual value.
The estimated useful lives of the Company’s buildings, plant installations and machinery at installation, excluding costs related to turnarounds, initially range up to 25 years depending on the specific asset component and the production facility to which it is related. The Company determines the estimated useful lives of individual asset components based on the shorter of its physical life or economic life. The physical life of these assets is generally longer than the economic life. The economic life is primarily determined by the nature of the natural gas feedstock available to our various production facilities. The estimated useful life of production facilities may be adjusted from time-to-time based on turnarounds, plant refurbishments and gas availability. Factors that influence the nature of natural gas feedstock availability include the terms of individual natural gas supply contracts, access to natural gas supply through open markets, regional factors influencing the exploration and development of natural gas and the expected price of securing natural gas supply. We review the factors related to each production facility on an annual basis to determine if changes are required to the estimated useful lives.
Recoverability of Asset Carrying Values
Long-lived assets are tested for recoverability whenever events or changes in circumstances, either internal or external, indicate that the carrying amount may not be recoverable ("impairment indicators"). Examples of such impairment indicators related to our long-lived assets include, but are not restricted to: a significant adverse change in the extent or manner in which the asset is being used or in its physical condition; a change in management's intention or strategy for the asset, which includes a plan to dispose of the asset or idle the asset for a significant period of time; a significant adverse change in our long-term methanol price assumption or in the price or availability of natural gas feedstock required to manufacture methanol; a significant adverse change in legal factors or in the business climate that could affect the asset’s value, including an adverse action or assessment by a foreign government that impacts the use of the asset; or a current period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the asset’s use.
When an impairment indicator is identified, recoverability of long-lived assets is measured by comparing the carrying value of an asset or cash-generating unit to the estimated recoverable amount, which is the higher of its estimated fair value less costs to sell or its value in use. Fair value less costs of disposal is determined by ascertaining the price that would be received to sell an asset in an orderly transaction between market participants under current market conditions, less incremental costs directly attributable to the disposal, excluding finance costs and income tax expense. Value in use is determined by measuring the pre-tax cash flows expected to be generated from the cash-generating unit over its estimated useful life discounted by a pre-tax discount rate. An impairment writedown is recorded if the carrying value exceeds the estimated recoverable amount. An impairment writedown recognized in prior periods for an asset or cash-generating unit is reversed if there has been a subsequent recovery in the value of the asset or cash-generating unit due to changes in events and circumstances. For the purposes of recognition and measurement of an impairment writedown or reversal, we group our long-lived assets with other assets and liabilities to form a cash-generating unit at the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. To the extent that our methanol facilities in a particular location are interdependent as a result of common infrastructure and/or feedstock from shared sources that can be shared within a facility location, we group our assets based on site locations for the purpose of determining impairment.
When impairment indicators exist, there are two key variables that impact our estimate of future cash flows from producing assets: (1) the methanol price and (2) the price and availability of natural gas feedstock. Short-term methanol price estimates are based on current supply and demand fundamentals and current methanol prices. Long-term methanol price estimates are based on our view of long-term supply and demand, incorporating third-party assumptions, forecasts and market-observable prices when appropriate. Consideration is given to many factors, including, but not limited to, estimates of global industrial production rates, energy prices, changes in general economic conditions, the ability for the industry to add further global methanol production capacity and earn an
appropriate return on capital, industry operating rates and the global industry cost structure. Our estimate of the price and availability of natural gas takes into consideration the current contracted terms, as well as factors that we believe are relevant to supply under these contracts and supplemental natural gas sources. Other assumptions included in our estimate of future cash flows include the estimated cost incurred to maintain the facilities, estimates of transportation costs and other variable costs incurred in producing methanol in each period. Changes in these assumptions will impact our estimates of future cash flows when testing for impairment and could impact our estimates of the useful lives of property, plant and equipment. Consequently, it is possible that our future operating results could be adversely affected by further asset impairment charges or by changes in depreciation and amortization rates related to property, plant and equipment. In relation to previous impairment charges, we do not believe that there are significant changes in events or circumstances that would support their reversal.
In 2024, we announced our intention to idle the Motunui I plant indefinitely and restructure to a single-plant operation in New Zealand moving forward. The reorganizing of operations to a single plant operation was identified as an impairment indicator for the New Zealand CGU. The impairment test performed on the New Zealand CGU resulted in a non-cash before-tax asset impairment charge of $125 million ($90 million after-tax) to write down the carrying value of the New Zealand assets to $93 million.
We believe the estimated recoverable amount of all long-lived assets exceed their carrying value as at December 31, 2024.
Income Taxes
We calculate current and deferred tax provisions for each of the jurisdictions in which we operate. Actual amounts of income tax expense or recoveries are not final until tax returns are filed and accepted by the relevant tax authorities and as a result, the ultimate amount of taxes the Company may owe could differ from the amounts recognized in the consolidated financial statements. The filing of annual tax returns primarily occurs subsequent to the issuance of the financial statements and the final determination of actual amounts may not be completed for a number of years. Transactions may be challenged by tax authorities and the Company's operations may be assessed in subsequent periods, which could result in significant additional taxes, penalties and interest. Uncertain tax positions derive from the complexity of tax law and its interpretation by tax authorities and ultimately the judicial system in place in each jurisdiction. Uncertain tax positions, including interest and penalties, are recognized and measured applying management estimates. Given the complexity, management engages third-party experts as required, for the interpretation of tax law, transfer pricing regulations and determination of the ultimate resolution of its tax positions. The Company is subject to various taxation authorities who may interpret tax legislation differently, and resolve matters over longer periods of time. The differences in judgement in assessing uncertain tax positions may result in material differences in the final amount or timing of the payment of taxes or settlement of tax assessments.
Deferred income tax assets and liabilities are determined using enacted or substantially enacted tax rates for the effects of net operating losses and temporary differences between the book and tax bases of assets and liabilities. We recognize deferred tax assets to the extent it is probable that taxable profit will be available against which the asset can be utilized. In making this determination, certain judgments are made relating to the level of expected future taxable income and to available tax-planning strategies and their impact on the use of existing loss carryforwards and other income tax deductions. We also consider historical profitability and volatility to assess whether we believe it is probable that the existing loss carryforwards and other income tax deductions will be used to offset future taxable income otherwise calculated. Management routinely reviews these judgments. As at December 31, 2024, we had recognized deferred tax assets of $204 million primarily relating to non-capital loss carryforwards and other temporary differences in the United States, Trinidad and Tobago, and New Zealand. As at December 31, 2024, the Company had $170 million of unrecognized deductible temporary differences in the United States. If judgments or estimates in the determination of our current and deferred tax provision prove to be inaccurate, or if certain tax rates or laws change, or new interpretations or guidance emerge on the application of tax legislation, our results from operations and financial position could be materially impacted.
Financial Instruments Measured at Fair Value
The Company uses derivatives as part of its risk management program to mitigate variability associated with changing market values. Changes in the fair value of derivative financial instruments are recorded in earnings unless the instruments are designated as cash flow hedges, in which case the changes in fair value are recorded in other comprehensive income and are reclassified to profit or loss or accumulated other comprehensive income when the underlying hedged transaction is recognized in earnings or inventory. The Company designates as cash flow hedges certain derivative financial instruments to hedge its risk exposure to fluctuations in natural gas prices and to hedge its risk exposure to fluctuations on certain foreign-currency-denominated transactions. Assessment of contracts as derivative instruments, applicability of the own use exemption, determination of whether contracts contain embedded derivatives to be separated, the valuation of financial instruments and derivatives and hedge effectiveness assessments require a high degree of judgment and are considered critical accounting estimates due to their complex nature and the potential impact on our financial statements.
The Company holds a long-term natural gas supply contract expiring in 2035 with the Egyptian Natural Gas Holding Company, a State-Owned enterprise in Egypt. The natural gas supply contract includes a base fixed price plus a premium based on the realized price of methanol for the full volume of natural gas to supply the plant for the remainder of its useful life. As a result of the amendment in 2022, the contract is being treated as a derivative measured at fair value.
There is no observable, liquid spot market or forward curve for natural gas in Egypt. In addition, there are limited observable prices for natural gas in Egypt as all natural gas purchases and sales are controlled by the government and the observed prices differ based on the produced output or usage.
Due to the absence of an observable market price for an equivalent or similar contract to measure fair value, the contract's fair value is estimated using a Monte-Carlo model. We consider market participant assumptions in establishing the model inputs and determining fair value, including adjusting the base fixed price and methanol based premium at the valuation date to consider estimates of inflation since contract inception.
The Company holds a long-term natural gas supply contract expiring in 2029 with OMV New Zealand ("OMV"), one of the largest gas suppliers in New Zealand. The natural gas supply contract includes a base fixed price plus a premium based on the realized price of methanol.
During 2024 the Company entered into short-term commercial arrangements to provide its contracted natural gas into the New Zealand electricity market. The on-sale of natural gas has impacted the accounting assessment for the contract whereby it is now considered a derivative to be measured at fair value.
The New Zealand wholesale gas market is relatively small and concentrated as there are a limited number of suppliers and consumers. There is a limited observable, liquid spot market and no forward curve for natural gas in New Zealand. The gas trading platform used to facilitate short-term balance in the gas market trades inconsequential volumes relative to the scope of the Company’s gas consumption and the overall gas market. The Company does not believe transactions on this platform take place with sufficient frequency and volume to provide pricing information.
Due to the absence of an observable market price for an equivalent or similar contract to measure fair value, we have estimated fair value using an economic model. The model includes significant unobservable inputs and as a result is classified within Level 3 of the fair value hierarchy. We have considered market participant assumptions in establishing the model inputs and determining fair value, including potential sharing mechanisms for gas on-sales to consider the change in the local market gas supply and demand dynamics since contract inception.
Refer to note 19 of our 2024 consolidated financial statements for more information.
ADOPTION OF NEW ACCOUNTING STANDARDS
The Company has adopted the amendments to IAS 1, Presentation of Financial Statements regarding the classification of liabilities as current or non-current, IFRS 16, Leases regarding sale-and-leaseback transactions and IAS 7, Statement of Cash Flows regarding supplier finance arrangements, which were effective for annual periods beginning on January 1, 2024. The amendments did not have a material impact on the Company's consolidated financial statements.
ANTICIPATED CHANGES TO INTERNATIONAL FINANCIAL REPORTING STANDARDS
The following new or amended standards or interpretations that are effective for annual periods beginning on or after January 1, 2025 and subsequent years are being reviewed to determine the potential impact: amendments to IAS 21, The Effects of Changes in Foreign Exchange Rates regarding the lack of exchangeability, IFRS 9, Financial Instruments and IFRS 7, Financial Instruments: Disclosures regarding the classification and measurement of financial instruments and the accounting for power purchase agreements and IFRS 18, Presentation and Disclosure in Financial Statements regarding the replacement of IAS 1, Presentation of Financial Statements.
NON-GAAP MEASURES
In addition to providing measures prepared in accordance with IFRS, we present certain supplemental measures that are not defined terms under IFRS (non-GAAP measures or ratios). These are Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share, Adjusted net income (loss) before income tax, Adjusted income tax expense, and Adjusted effective tax rate. These non-GAAP financial measures and ratios reflect our 63.1% economic interest in the Atlas facility, 50% economic interest in the Egypt facility and our 60% economic interest in Waterfront Shipping, and are useful as they are a better measure of our underlying performance and assist in assessing the operating performance of the Company’s business. These measures, at our economic share, are a better measure of our underlying performance, as we fully run the operations on our partners' behalf, despite having less than full share of the economic interest. Adjusted EBITDA is also frequently used by securities analysts and investors when comparing our results with those of other companies.
In addition, the Company also presents non-GAAP capital management measures, specifically, Net debt to capitalization and Total liquidity, which are useful in assessing the liquidity of the Company’s ongoing business. Total liquidity is useful because it illustrates the extent to which management has immediate access to cash for operational and construction purposes, and is indicative of our
flexibility should uses for these facilities immediately arise. Net debt to capitalization is useful because it illustrates the relative risk of our financing structure to potential lenders and investors.These measures and ratios do not have any standardized meaning prescribed by IFRS and therefore are unlikely to be comparable to similar measures presented by other companies.
These measures should be considered in addition to, and not as a substitute for, net income, cash flows and other measures of financial performance and liquidity reported in accordance with IFRS.
Adjusted EBITDA
Adjusted EBITDA is a non-GAAP financial measure and differs from the most comparable GAAP measure, net income attributable to Methanex shareholders, because it excludes finance costs, finance income and other, income tax expense, depreciation and amortization, asset impairment charge, gas contract settlement charge, and mark-to-market impact of share-based compensation. Adjusted EBITDA includes an amount representing our 63.1% share of the Atlas facility and excludes the non-controlling shareholders' interests in entities which we control but do not fully own.
Adjusted EBITDA and Adjusted net income exclude the mark-to-market impact of share-based compensation related to the impact of changes in our share price on SARs, TSARs, deferred share units, restricted share units and performance share units. The mark-to-market impact related to share-based compensation that is excluded from Adjusted EBITDA and Adjusted net income is calculated as the difference between the grant date value and the fair value recorded at each period-end. As share-based awards will be settled in future periods, the ultimate value of the units is unknown at the date of grant and therefore the grant date value recognized in Adjusted EBITDA and Adjusted net income may differ from the total settlement cost.
The following table shows a reconciliation from net income attributable to Methanex shareholders to Adjusted EBITDA:
($ Millions) | 2024 | 2023 | ||||||
Net income attributable to Methanex shareholders | $ | 164 | $ | 174 | ||||
Mark-to-market impact of share-based compensation | 2 | 16 | ||||||
| Gas contract settlement, net of tax | — | (31) | ||||||
Depreciation and amortization | 386 | 392 | ||||||
Finance costs | 133 | 117 | ||||||
Finance income and other | (12) | (40) | ||||||
Income tax expense | 30 | 1 | ||||||
| Asset impairment charge | 125 | — | ||||||
Earnings of associate adjustment 1 | 43 | 67 | ||||||
Non-controlling interests adjustment 1 | (107) | (74) | ||||||
Adjusted EBITDA (attributable to Methanex shareholders) | $ | 764 | $ | 622 | ||||
1 These adjustments represent depreciation and amortization, finance costs, finance income and other and income taxes associated with our 63.1% interest in the Atlas methanol facility and the non-controlling interests.
Adjusted Net Income and Adjusted Net Income per Common Share
Adjusted net income and Adjusted net income per common share are a non-GAAP measure and ratio, respectively, because they exclude the mark-to-market impact of share-based compensation, the impact of the Egypt and New Zealand gas contract revaluation included in finance income and other and the impact of certain items associated with specific identified events. The following table shows a reconciliation from net income attributable to Methanex shareholders to Adjusted net income and the calculation of Adjusted diluted net income per common share:
($ Millions, except number of shares and per share amounts) | 2024 | 2023 | ||||||
Net income attributable to Methanex shareholders | $ | 164 | $ | 174 | ||||
Mark-to-market impact of share-based compensation, net of tax | 2 | 13 | ||||||
Impact on earnings of associate of gas contract settlement, net of tax | — | (31) | ||||||
Impact of Egypt and New Zealand gas contract revaluation, net of tax | (4) | (3) | ||||||
Asset impairment charge, net of tax | 90 | — | ||||||
Adjusted net income | $ | 252 | $ | 153 | ||||
Diluted weighted average shares outstanding (millions) | 68 | 68 | ||||||
Adjusted net income per common share | $ | 3.72 | $ | 2.25 | ||||
Management uses these measures to analyze net income and net income per common share after adjusting for our economic interest in the Atlas and Egypt facilities and Waterfront Shipping, for reasons as described above. The exclusion of the mark-to-market portion of the impact of shared-based compensation is due to these amounts not being seen as indicative of the operational performance and can fluctuate in the intervening periods until settlement. The exclusion of the impact of the Egypt and New Zealand gas contract
revaluation is due to the change in the derivative being unrealized with the fair value of the derivative expected to fluctuate in the intervening periods until settlement. The exclusion of the asset impairment charge is due to the item not being operational in nature.
QUARTERLY FINANCIAL DATA (UNAUDITED)
Our operations consist of a single operating segment – the production and sale of methanol. Quarterly results vary due to the average realized price of methanol, sales volume and total cash costs.
A summary of selected financial information is as follows:
Three months ended | ||||||||||||||
($ Millions, except per share amounts) | Dec 31 | Sep 30 | Jun 30 | Mar 31 | ||||||||||
| 2024 | ||||||||||||||
Revenue | $ | 949 | $ | 935 | $ | 920 | $ | 916 | ||||||
Cost of sales and operating expenses | (734) | (794) | (745) | (736) | ||||||||||
Net income (attributable to Methanex shareholders) | 45 | 31 | 35 | 53 | ||||||||||
Basic net income per common share | 0.67 | 0.46 | 0.52 | 0.78 | ||||||||||
Diluted net income per common share | 0.67 | 0.35 | 0.52 | 0.77 | ||||||||||
Adjusted EBITDA 1 | 224 | 216 | 164 | 160 | ||||||||||
Adjusted net income 1 | 84 | 82 | 42 | 44 | ||||||||||
Adjusted net income per common share 1 | 1.24 | 1.21 | 0.62 | 0.65 | ||||||||||
| 2023 | ||||||||||||||
Revenue | $ | 922 | $ | 823 | $ | 939 | $ | 1,038 | ||||||
Cost of sales and operating expenses | (772) | (730) | (724) | (841) | ||||||||||
Net income (attributable to Methanex shareholders) | 33 | 24 | 57 | 60 | ||||||||||
Basic net income per common share | 0.50 | 0.36 | 0.84 | 0.87 | ||||||||||
Diluted net income per common share | 0.50 | 0.36 | 0.73 | 0.87 | ||||||||||
Adjusted EBITDA 1 | 148 | 105 | 160 | 209 | ||||||||||
Adjusted net income 1 | 35 | 1 | 41 | 76 | ||||||||||
Adjusted net income per common share 1 | 0.52 | 0.02 | 0.60 | 1.11 | ||||||||||
1 The Company has used the terms Adjusted EBITDA, Adjusted net income, and Adjusted net income per common share, throughout this document. These items are non-GAAP measures and ratios that do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Refer to the Non-GAAP Measures section on page 39 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.
A discussion and analysis of our results for the fourth quarter of 2024 is set out in our fourth quarter of 2024 Management’s Discussion and Analysis filed with the Canadian Securities Administrators on SEDAR+ at www.sedarplus.ca and the U.S. Securities and Exchange Commission on EDGAR at www.sec.gov and is incorporated herein by reference.
SELECTED ANNUAL INFORMATION
($ Millions, except per share amounts) | 2024 | 2023 | 2022 | ||||||||
Total assets | $ | 6,597 | $ | 6,427 | $ | 6,631 | |||||
Total long-term liabilities (excluding deferred income tax) | 3,247 | 2,733 | 3,032 | ||||||||
Revenue | 3,720 | 3,723 | 4,311 | ||||||||
Net income (attributable to Methanex shareholders) | 164 | 174 | 354 | ||||||||
Adjusted net income 1 | 252 | 153 | 343 | ||||||||
Adjusted EBITDA 1 | 764 | 622 | 932 | ||||||||
Basic net income per common share | 2.43 | 2.57 | 4.95 | ||||||||
Diluted net income per common share | 2.39 | 2.57 | 4.86 | ||||||||
Adjusted net income per common share 1 | 3.72 | 2.25 | 4.79 | ||||||||
Cash dividends declared per common share | 0.740 | 0.730 | 0.620 | ||||||||
1 The Company has used the terms Adjusted EBITDA, Adjusted net income, and Adjusted net income per common share,throughout this document. These items are non-GAAP measures and ratios that do not have any standardized meaning prescribed by GAAP and therefore are unlikely to be comparable to similar measures presented by other companies. Refer to the Non-GAAP Measures section on page 39 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.
CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
Disclosure controls and procedures (as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended (the "Exchange Act")), and NI 52-109, are those controls and procedures that are designed to ensure that the information required to be disclosed in the filings under applicable securities regulations is recorded, processed, summarized and reported within the time periods specified. As of December 31, 2024, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of the effectiveness of the design and operation of the Company’s disclosure controls and procedures. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures are effective as of that date.
Management’s Annual Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting. 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. 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 our assets; (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 our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.
Internal control over financial reporting has inherent limitations. Internal control over financial reporting is a process that involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting also can be circumvented by collusion or improper management override. Because of such limitations, there is a risk that material misstatements will not be prevented or detected on a timely basis by internal control over financial reporting. However, these inherent limitations are known features of the financial reporting process. Therefore, it is possible to design into the process safeguards to reduce, though not eliminate, this risk.
Under the supervision and with the participation of our Chief Executive Officer and our Chief Financial Officer, management conducted an evaluation of the effectiveness of our internal control over financial reporting, as of December 31, 2024, based on the framework set forth in Internal Control – Integrated Framework issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission (the "COSO framework"). Based on its evaluation under this framework, management concluded that our internal control over financial reporting was effective as of that date.
KPMG LLP, an independent registered public accounting firm that audited and reported on our consolidated financial statements, has issued an attestation report on the effectiveness of our internal control over financial reporting as of December 31, 2024. The attestation report is included in our consolidated financial statements on page 48.
Changes in Internal Control over Financial Reporting
There have been no changes in the Company’s internal control over financial reporting that occurred during the most recent interim period and year ended December 31, 2024, that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.
FORWARD-LOOKING STATEMENTS
This 2024 Management’s Discussion and Analysis ("MD&A") contains forward-looking statements with respect to us and our industry. These statements relate to future events or our future performance. All statements other than statements of historical fact are forward-looking statements. Statements that include the words "believes," "expects," "may," "will," "should," "potential," "estimates," "anticipates," "aim", "goal," "targets," "plan," "predict" or other comparable terminology and similar statements of a future or forward-looking nature identify forward-looking statements.
More particularly, and without limitation, any statements regarding the following are forward-looking statements:
▪anticipated closing date of the OCI Acquisition and the expected benefits of the OCI Acquisition, including benefits related to expected synergies and commodity diversification,
▪anticipated synergies and Methanex's ability to achieve
such synergies following closing of the OCI Acquisition,
▪whether the OCI Acquisition will include OCI Global's 50%
share of the Natgasoline plant,
▪expected demand for methanol, including demand for methanol for energy uses, and its derivatives,
▪expected new methanol supply or restart of idled capacity and timing for startup of the same,
▪expected increase in methanol production of assets to be acquired as part of the OCI Acquisition,
▪expected shutdowns (either temporary or permanent) or restarts of existing methanol supply (including our own facilities), including, without limitation, the timing and length of planned maintenance outages,
▪expected methanol and energy prices,
▪expected levels of methanol purchases from traders or other third parties,
▪expected levels, timing and availability of economically priced natural gas supply to each of our plants,
▪capital committed by third parties towards future natural gas exploration and development in the vicinity of our plants,
▪our expected capital expenditures and anticipated timing and rate of return of such capital expenditures,
▪anticipated operating rates of our plants,
▪expected operating costs, including natural gas feedstock costs and logistics costs,
▪expected tax rates or resolutions to tax disputes,
▪expected cash flows, cash balances, earnings capability, debt levels, debt reduction and deleveraging plans, and share price,
▪availability of committed credit facilities and other financing,
▪our ability to meet covenants associated with our long-term debt obligations,
▪our shareholder distribution strategy and anticipated distributions to shareholders,
▪commercial viability and timing of, or our ability to execute future projects, plant restarts, capacity expansions, plant relocations or other business initiatives or opportunities,
▪our financial strength and ability to meet future financial commitments,
▪expected global or regional economic activity (including industrial production levels) and gross domestic product growth,
▪expected outcomes of litigation or other disputes, claims and assessments, and
▪expected actions of governments, governmental agencies, gas suppliers, courts, tribunals or other third parties.
We believe that we have a reasonable basis for making such forward-looking statements. The forward-looking statements in this document are based on our experience, our perception of trends, current conditions and expected future developments as well as other factors. Certain material factors or assumptions were applied in drawing the conclusions or making the forecasts or projections that are included in these forward-looking statements, including, without limitation, future expectations and assumptions concerning the following:
▪future expectations and assumptions concerning the receipt of all regulatory approvals required to complete the OCI Acquisition,
▪Methanex's ability to realize the expected strategic, financial and other benefits of the OCI Acquisition in the timeframe anticipated or at all,
▪our ability to procure natural gas feedstock on commercially acceptable terms,
▪operating rates of our facilities,
▪receipt or issuance of third-party consents or approvals or governmental approvals related to rights to purchase natural gas,
▪the establishment of new fuel standards,
▪operating costs, including natural gas feedstock and logistics costs, capital costs, tax rates, cash flows, foreign exchange rates and interest rates,
▪the availability of committed credit facilities and other financing,
▪our ability to sustain the designed operating rates of the Geismar 3 plant,
▪global and regional economic activity (including industrial production levels) and gross domestic product growth,
▪absence of a material negative impact from major natural disasters,
▪absence of a material negative impact from changes in laws or regulations,
▪absence of a material negative impact from political instability in the countries in which we operate, and
▪enforcement of contractual arrangements and ability to perform contractual obligations by customers, natural gas and other suppliers and other third parties.
However, forward-looking statements, by their nature, involve risks and uncertainties that could cause actual results to differ materially from those contemplated by the forward-looking statements. The risks and uncertainties primarily include those attendant with producing and marketing methanol and successfully carrying out major capital expenditure projects in various jurisdictions, including, without limitation:
▪failure to complete the OCI Acquisition in accordance with the material terms of the OCI Acquisition agreement or at all,
▪failure to obtain any of the approvals required for the OCI Acquisition,
▪failure to acquire OCI Global's 50% joint venture interest in Natgasoline,
▪failure to close the OCI Acquisition credit facility,
▪unforeseen difficulties in integrating the business operations or assets purchased pursuant to the OCI Acquisition into our business and operations,
▪failure to realize the expected strategic, financial and other benefits of the OCI Acquisition in the timeframe anticipated or at all,
▪unexpected costs or liabilities associated with the OCI Acquisition,
▪increased litigation or negative public perception as a result of the OCI Acquisition,
▪increased indebtedness of Methanex,
▪conditions in the methanol and other industries, including fluctuations in the supply, demand and price for methanol and its derivatives, including demand for methanol for energy uses,
▪the price of natural gas, coal, oil and oil derivatives,
▪our ability to obtain natural gas feedstock on commercially acceptable terms to underpin current operations and future production growth opportunities,
▪the ability to carry out corporate initiatives and strategies,
▪actions of competitors, suppliers and financial institutions,
▪conditions within the natural gas delivery systems that may prevent delivery of our natural gas supply requirements,
▪competing demand for natural gas, especially with respect to any domestic needs for gas and electricity,
▪actions of governments and governmental authorities, including, without limitation, implementation of policies or other measures that could impact the supply of or demand for methanol or its derivatives,
▪changes in laws or regulations,
▪import or export restrictions, anti-dumping measures, increases in duties, taxes and government royalties and other actions by governments that may adversely affect our operations or existing contractual arrangements,
▪worldwide economic conditions, and
▪other risks described in this 2024 MD&A.
Having in mind these and other factors, investors and other readers are cautioned not to place undue reliance on forward-looking statements. They are not a substitute for the exercise of one’s own due diligence and judgment. The outcomes implied in forward-looking statements may not occur and we do not undertake to update forward-looking statements except as required by applicable securities laws.
Exhibit 99.3
Responsibility for Financial Reporting
The consolidated financial statements and all financial information contained in the annual report are the responsibility of management.
The consolidated financial statements have been prepared in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board and, where appropriate, have incorporated estimates based on the best judgment of management.
Management is responsible for establishing and maintaining adequate internal control over financial reporting. Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the internal control framework set out in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation, our management concluded that our internal control over financial reporting was effective as of December 31, 2024.
The Board of Directors ("the Board") is responsible for ensuring that management fulfills its responsibilities for financial reporting and internal control, and is responsible for reviewing and approving the consolidated financial statements. The Board carries out this responsibility principally through the Audit, Finance and Risk Committee ("the Committee").
The Committee consists of five non-management directors, all of whom are independent as defined by the applicable rules in Canada and the United States. The Committee is appointed by the Board to assist the Board in fulfilling its oversight responsibility relating to: the integrity of the Company’s financial statements; the financial reporting process; the systems of accounting and financial controls; the professional qualifications and independence of the external auditor; the performance of the external and internal auditors; risk management processes; financing plans; and the Company’s compliance with ethics policies and legal and regulatory requirements.
The Committee meets regularly with management and the Company’s auditors, KPMG LLP, Chartered Professional Accountants, to discuss internal controls and significant accounting and financial reporting issues. KPMG LLP has full and unrestricted access to the Committee. KPMG LLP audited the consolidated financial statements and the effectiveness of internal controls over financial reporting. Their opinions are included in the annual report.
 |  |  | ||||||
Benita Warmbold Chair of the Audit, Finance and Risk Committee March 7, 2025 | Rich Sumner President and Chief Executive Officer | Dean Richardson Senior Vice President, Finance and Chief Financial Officer | ||||||
45
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors of Methanex Corporation:
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated statements of financial position of Methanex Corporation (the Company) as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, changes in equity, and cash flows for each of the years in the two-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 its financial performance and its cash flows for each of the years in the two-year period ended December 31, 2024, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board.
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 March 7, 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 matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate 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 critical audit matters 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 matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Recognition and Measurement of Uncertain Tax Positions
As discussed in Notes 6(b) and 16 to the consolidated financial statements, the Company has identified and, in certain cases, recognized uncertain tax positions (tax positions) including associated interest and penalties. As discussed in Note 2(q) to the consolidated financial statements, uncertain tax positions derive from the complexity of tax law and its interpretation by tax authorities and ultimately the judicial system in place in each jurisdiction. Given the complexity, the Company engages third-party experts as required, for the interpretation of tax law, transfer pricing regulations and determination of the ultimate resolution of its tax positions. The Company is subject to various taxation authorities who may interpret tax legislation differently, and resolve matters over longer-periods of time.
We identified the assessment of the recognition and measurement of uncertain tax positions as a critical audit matter. Complex auditor judgment was required to evaluate the Company’s interpretation of tax law and its identification and determination of the ultimate resolution of its tax positions. Additionally, the evaluation of the recognition and measurement of the Company's uncertain tax positions required specialized skills and knowledge.
46
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 process for recognizing uncertain tax positions. This included controls related to the interpretation of tax law and identification of tax positions, the determination of the probability that the tax authorities would accept the Company's tax positions, and the estimation of reserves recorded for tax positions. We involved domestic and international tax professionals with specialized skills and knowledge, who assisted in assessing the Company's tax positions by:
–inspecting tax rulings and correspondence between the Company and the applicable taxation authorities;
–inspecting transfer pricing studies and information obtained from external tax specialists and legal counsel; and
–comparing our understanding and interpretation of tax laws to the Company's evaluation.
Assessment of the Recoverable Amount of the New Zealand Cash Generating Unit
As discussed in Note 2(g) to the consolidated financial statements, long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. When such an impairment indicator is identified, the recoverability of long-lived assets is measured by comparing the carrying value of the asset or cash-generating unit to the estimated recoverable amount. As discussed in Note 5(b) to the consolidated financial statements, the Company identified an impairment indicator for the New Zealand cash-generating unit (“New Zealand CGU”) and the carrying value of the New Zealand CGU was tested for impairment. The recoverable amount was determined using a discounted cash flow approach to measure the fair value less costs of disposal of the New Zealand CGU. During the year ended December 31, 2024, the Company recorded an asset impairment charge of $125 million in property, plant and equipment to write down the carrying value of the New Zealand CGU to its recoverable amount.
We identified the assessment of the recoverable amount of the New Zealand CGU to be a critical audit matter. Challenging auditor judgment was required to evaluate the availability of natural gas assumption used in determining the recoverable amount of the New Zealand CGU, as the assumption is subject to significant measurement uncertainty. Changes in the availability of natural gas assumption could have had a significant impact on the recoverable amount of the New Zealand CGU.
The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of an internal control over the Company's process to determine the recoverable amount of the New Zealand CGU, including the availability of natural gas assumption. We compared the availability of natural gas assumption to third party gas supplier forecasts of gas volumes available during the forecast period. We compared the Company’s historical forecasts to actual results to assess the accuracy of the Company’s forecasting process. We performed a sensitivity analysis over the availability of natural gas assumption to assess the impact on the Company’s determination of the recoverability of the New Zealand CGU.
/s/ KPMG LLP
Chartered Professional Accountants
We have served as the Company's auditor since 1992.
Vancouver, Canada
March 7, 2025
47
Report of Independent Registered Public Accounting Firm
To the Shareholders and Board of Directors of Methanex Corporation:
Opinion on Internal Control Over Financial Reporting
We have audited Methanex Corporation'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. In our opinion, Methanex Corporation (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 statements of financial position of the Company as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, changes in equity, and cash flows for each of the years in the two-year period ended December 31, 2024, and the related notes (collectively, the consolidated financial statements), and our report dated March 7, 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 under the heading ”Management’s Annual Report on Internal Control Over Financial Reporting” in Management's Discussion and Analysis for the year ended December 31, 2024. 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
Vancouver, Canada
March 7, 2025
48
Consolidated Statements of Financial Position
(thousands of U.S. dollars, except number of common shares)
| As at | Dec 31 2024 | Dec 31 2023 | ||||||
| ASSETS | ||||||||
| Current assets: | ||||||||
| Cash and cash equivalents | $ | $ | ||||||
| Trade and other receivables (note 3) | ||||||||
| Inventories (note 4) | ||||||||
| Prepaid expenses | ||||||||
| Other assets (note 7) | ||||||||
| Non-current assets: | ||||||||
| Property, plant and equipment (note 5) | ||||||||
| Investment in associate (note 6) | ||||||||
| Deferred income tax assets (note 16) | ||||||||
| Other assets (note 7) | ||||||||
| $ | $ | |||||||
| LIABILITIES AND EQUITY | ||||||||
| Current liabilities: | ||||||||
| Trade, other payables and accrued liabilities | $ | $ | ||||||
| Current maturities on long-term debt (note 8) | ||||||||
| Current maturities on lease obligations (note 9) | ||||||||
| Current maturities on other long-term liabilities (note 10) | ||||||||
| Non-current liabilities: | ||||||||
| Long-term debt (note 8) | ||||||||
| Lease obligations (note 9) | ||||||||
| Other long-term liabilities (note 10) | ||||||||
| Deferred income tax liabilities (note 16) | ||||||||
| Equity: | ||||||||
| Capital stock | ||||||||
| Unlimited authorization of common shares without nominal or par value | ||||||||
Issued and outstanding common shares at December 31, 2024 were | ||||||||
| Contributed surplus | ||||||||
| Retained earnings | ||||||||
| Accumulated other comprehensive income | ||||||||
| Shareholders’ equity | ||||||||
| Non-controlling interests | ||||||||
| Total equity | ||||||||
| $ | $ | |||||||
Commitments and contingencies (note 22)
See accompanying notes to consolidated financial statements.
Approved by the Board:
| | ||||
| Benita Warmbold (Director) | Rich Sumner (Director) | ||||
49
Consolidated Statements of Income
(thousands of U.S. dollars, except number of common shares and per share amounts)
For the years ended December 31 | 2024 | 2023 | ||||||
| Revenue | $ | $ | ||||||
| Cost of sales and operating expenses (note 11) | ( | ( | ||||||
| Depreciation and amortization (note 11) | ( | ( | ||||||
| New Zealand gas sale net proceeds (note 25) | ||||||||
| Egypt insurance recovery (note 26) | ||||||||
| Asset impairment charge (note 5) | ( | |||||||
| Operating income | ||||||||
| Earnings of associate (note 6) | ||||||||
| Finance costs (note 12) | ( | ( | ||||||
| Finance income and other | ||||||||
| Income before income taxes | ||||||||
| Income tax (expense) recovery (note 16): | ||||||||
| Current | ( | ( | ||||||
| Deferred | ||||||||
| ( | ( | |||||||
| Net income | $ | $ | ||||||
| Attributable to: | ||||||||
| Methanex Corporation shareholders | $ | $ | ||||||
| Non-controlling interests (note 24) | ||||||||
| $ | $ | |||||||
| Income per common share for the year attributable to Methanex Corporation shareholders: | ||||||||
| Basic net income per common share (note 13) | $ | $ | ||||||
| Diluted net income per common share (note 13) | $ | $ | ||||||
| Weighted average number of common shares outstanding (note 13) | ||||||||
| Diluted weighted average number of common shares outstanding (note 13) | ||||||||
See accompanying notes to consolidated financial statements.
50
Consolidated Statements of Comprehensive Income
(thousands of U.S. dollars)
For the years ended December 31 | 2024 | 2023 | ||||||
Net income | $ | $ | ||||||
Other comprehensive income: | ||||||||
Items that may be reclassified to income: | ||||||||
| Change in cash flow hedges and excluded forward element (note 19) | ( | ( | ||||||
| Realized losses (gains) on foreign exchange hedges reclassified to revenue | ( | |||||||
| Amounts reclassified on discontinuation of hedging relationship (note 19) | ||||||||
Items that will not be reclassified to income: | ||||||||
| Actuarial gain (loss) on defined benefit pension plans (note 21(a)) | ( | |||||||
Taxes on above items | ( | |||||||
| ( | ( | |||||||
Comprehensive income | $ | $ | ||||||
Attributable to: | ||||||||
Methanex Corporation shareholders | $ | $ | ( | |||||
Non-controlling interests (note 24) | ||||||||
| $ | $ | |||||||
See accompanying notes to consolidated financial statements.
51
Consolidated Statements of Changes in Equity
(thousands of U.S. dollars, except number of common shares)
Number of common shares | Capital stock | Contributed surplus | Retained earnings | Accumulated other comprehensive income (loss) | Shareholders’ equity | Non-controlling interests | Total equity | ||||||||||||||||||||||||||||
| Balance, December 31, 2022 | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||
Net income | — | — | — | — | |||||||||||||||||||||||||||||||
Other comprehensive loss | — | — | — | ( | ( | ( | — | ( | |||||||||||||||||||||||||||
Compensation expense recorded for stock options | — | — | — | — | — | ||||||||||||||||||||||||||||||
Issue of shares on exercise of stock options | — | — | — | — | |||||||||||||||||||||||||||||||
Reclassification of grant date fair value on exercise of stock options | — | ( | — | — | — | — | |||||||||||||||||||||||||||||
| Payments for repurchase of shares | ( | ( | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||
Dividend payments to Methanex Corporation shareholders ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||
Distributions made and accrued to non-controlling interests | — | — | — | — | — | — | ( | ( | |||||||||||||||||||||||||||
Realized hedge losses recognized in cash flow hedges | — | — | — | — | — | ||||||||||||||||||||||||||||||
| Balance, December 31, 2023 | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||
Net income | — | — | — | — | |||||||||||||||||||||||||||||||
Other comprehensive income (loss) | — | — | — | ( | ( | — | ( | ||||||||||||||||||||||||||||
Compensation expense recorded for stock options | — | — | — | — | — | ||||||||||||||||||||||||||||||
Issue of shares on exercise of stock options | — | — | — | — | |||||||||||||||||||||||||||||||
Reclassification of grant date fair value on exercise of stock options | — | ( | — | — | — | — | |||||||||||||||||||||||||||||
Dividend payments to Methanex Corporation shareholders ($ | — | — | — | ( | — | ( | — | ( | |||||||||||||||||||||||||||
Distributions made and accrued to non-controlling interests | — | — | — | — | — | — | ( | ( | |||||||||||||||||||||||||||
Realized hedge losses recognized in cash flow hedges | — | — | — | — | — | ||||||||||||||||||||||||||||||
| Balance, December 31, 2024 | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||
See accompanying notes to consolidated financial statements.
52
Consolidated Statements of Cash Flows
(thousands of U.S. dollars)
For the years ended December 31 | 2024 | 2023 | |||||||||
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES | |||||||||||
| Net income | $ | $ | |||||||||
Deduct earnings of associate | ( | ( | |||||||||
Add dividends received from associate | |||||||||||
Add (deduct) non-cash items: | |||||||||||
Depreciation and amortization | |||||||||||
Income tax expense | |||||||||||
Share-based compensation expense | |||||||||||
Finance costs | |||||||||||
| Mark-to-market impact of Level 3 derivatives | ( | ||||||||||
| Asset impairment charge | |||||||||||
Other | ( | ( | |||||||||
Interest received | |||||||||||
Income taxes paid | ( | ( | |||||||||
Other cash payments, including share-based compensation | ( | ( | |||||||||
Cash flows from operating activities before undernoted | |||||||||||
Changes in non-cash working capital (note 17(a)) | ( | ( | |||||||||
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES | |||||||||||
| Payments for repurchase of shares | ( | ||||||||||
Dividend payments to Methanex Corporation shareholders | ( | ( | |||||||||
Interest paid | ( | ( | |||||||||
Net proceeds on issue of long-term debt | |||||||||||
| Repayment of long-term debt and financing fees (note 8) | ( | ( | |||||||||
Repayment of lease obligations | ( | ( | |||||||||
Distributions to non-controlling interests | ( | ( | |||||||||
Proceeds on issue of shares on exercise of stock options | |||||||||||
| Restricted cash for debt service accounts | ( | ||||||||||
| Changes in non-cash working capital related to financing activities (note 17(a)) | ( | ||||||||||
| ( | ( | ||||||||||
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES | |||||||||||
| Property, plant and equipment | ( | ( | |||||||||
Geismar plant under construction | ( | ( | |||||||||
Proceeds of share capital reduction from associate | |||||||||||
Loan repayment from associate | |||||||||||
Changes in non-cash working capital related to investing activities (note 17(a)) | ( | ( | |||||||||
| ( | ( | ||||||||||
Increase (decrease) in cash and cash equivalents | ( | ||||||||||
Cash and cash equivalents, beginning of year | |||||||||||
Cash and cash equivalents, end of year | $ | $ | |||||||||
See accompanying notes to consolidated financial statements.
53
Notes to Consolidated Financial Statements
(Tabular dollar amounts are shown in thousands of U.S. dollars, except where noted)
Year ended December 31, 2024
1. Nature of operations:
2. Material accounting policies:
a) Statement of compliance:
b) Basis of presentation and consolidation:
c) Reporting currency and foreign currency translation:
d) Cash and cash equivalents:
e) Receivables:
f) Inventories:
g) Property, plant and equipment:
Initial recognition
Property, plant and equipment are initially recorded at cost. The cost of purchased equipment includes expenditures that are directly attributable to the purchase price, delivery and installation. The cost of self-constructed assets includes the cost of materials and direct
54
labour, any other costs directly attributable to bringing the assets to the location and condition for their intended use, the costs of dismantling and removing the items and restoring the site on which they are located, and borrowing costs on self-constructed assets that meet certain criteria. Borrowing costs incurred during construction and commissioning are capitalized until the plant is operating in the manner intended by management.
Subsequent costs
Routine repairs and maintenance costs are expensed as incurred. At regular intervals, the Company conducts a planned shutdown and inspection (turnaround) at its plants to perform major maintenance and replacement of catalysts. Costs associated with these shutdowns are capitalized and amortized over the period until the next planned turnaround and the carrying amounts of replaced components are derecognized and included in earnings.
Depreciation
Depreciation and amortization is generally provided on a straight-line basis at rates calculated to amortize the cost of property, plant and equipment from the commencement of commercial operations over their estimated useful lives to estimated residual value.
The estimated useful lives of the Company’s buildings, plant installations and machinery at installation, excluding costs related to turnarounds, initially range up to 25 years depending on the specific asset component and the production facility to which it is related. Right-of-use (leased) assets are depreciated from the lease commencement date to the earlier of the end of the useful life of the right-of-use asset or the end of the lease term. The Company determines the estimated useful lives of individual asset components based on the shorter of its physical life or economic life. The physical life of these assets is generally longer than the economic life. The economic life is primarily determined by the nature of the natural gas feedstock available to the various production facilities. The estimated useful life of production facilities may be adjusted from time-to-time based on turnarounds, plant refurbishments and gas availability. Factors that influence the nature of natural gas feedstock availability include the terms of individual natural gas supply contracts, access to natural gas supply through open markets, regional factors influencing the exploration and development of natural gas and the expected price of securing natural gas supply. The Company reviews the factors related to each production facility on an annual basis to determine if changes are required to the estimated useful lives.
Recoverability of asset carrying values
Long-lived assets are tested for recoverability whenever events or changes in circumstances, either internal or external, indicate that the carrying amount may not be recoverable (“triggering events”). Examples of such triggering events related to our long-lived assets may include, but are not restricted to: a significant adverse change in the extent or manner in which the asset is being used or in its physical condition; a change in management’s intention or strategy for the asset, which includes a plan to dispose of the asset or idle the asset for a significant period of time; a significant adverse change in our long-term methanol price assumption or in the price or availability of natural gas feedstock required to manufacture methanol; a significant adverse change in legal factors or in the business climate that could affect the asset’s value, including an adverse action or assessment by a foreign government that impacts the use of the asset; or a current period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the asset’s use.
When a triggering event is identified, recoverability of long-lived assets is measured by comparing the carrying value of an asset or cash-generating unit to the estimated recoverable amount, which is the higher of its estimated fair value less costs to sell or its value in use. Fair value less costs of disposal is determined by estimating the price that would be received to sell an asset in an orderly transaction between market participants under current market conditions, less incremental costs directly attributable to the disposal, excluding finance costs and income tax expense. Value in use is determined by measuring the pre-tax cash flows expected to be generated from the cash-generating unit over its estimated useful life discounted by a pre-tax discount rate. An impairment writedown is recorded if the carrying value exceeds the estimated recoverable amount. An impairment writedown recognized in prior periods for an asset or cash-generating unit is reversed if there has been a subsequent recovery in the value of the asset or cash-generating unit due to changes in events and circumstances. For the purposes of recognition and measurement of an impairment writedown or reversal, we group our long-lived assets with other assets and liabilities to form a “cash-generating unit” at the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities. To the extent that our methanol facilities in a particular location are interdependent as a result of common infrastructure and/or feedstock from shared sources that can be shared within a facility location, we group our assets based on site locations for the purpose of determining impairment.
When impairment indicators exist, there are two key variables that impact our estimate of future cash flows from producing assets: (1) the methanol price and (2) the price and availability of natural gas feedstock. Short-term methanol price estimates are based on current supply and demand fundamentals and current methanol prices. Long-term methanol price estimates are based on our view of long-term supply and demand, incorporating third-party assumptions, forecasts and market observable prices when appropriate. Consideration is given to many factors, including, but not limited to, estimates of global industrial production rates, energy prices, changes in general economic conditions, the ability for the industry to add further global methanol production capacity and earn an appropriate return on capital, industry operating rates and the global industry cost structure. Our estimate of the price and availability of natural gas takes into consideration the current contracted terms, as well as factors that we believe are relevant to supply under these contracts and supplemental natural gas sources. Other assumptions included in our estimate of future cash flows include the
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estimated cost incurred to maintain the facilities, estimates of transportation costs and other variable costs incurred in producing methanol in each period. Changes in these assumptions will impact our estimates of future cash flows when testing for impairment and could impact our estimates of the useful lives of property, plant and equipment. Consequently, it is possible that our future operating results could be adversely affected by further asset impairment charges or by changes in depreciation and amortization rates related to property, plant and equipment. In relation to previous impairment charges, we do not believe that there are significant changes in events or circumstances that would support their reversal.
h) Other assets:
i) Leases:
At inception of a contract, the Company assesses whether a contract is, or contains, a lease. A contract is, or contains, a lease if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration.
For contracts that contain a lease, the Company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured at cost, which comprises the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date, plus any initial direct costs incurred and an estimate of costs to dismantle and remove the underlying asset or to restore the underlying asset or the site on which it is located, less any lease incentives received.
The right-of-use asset is subsequently depreciated using the straight-line method from the commencement date to the earlier of the end of the useful life of the right-of-use asset or the end of the lease term. The estimated useful lives of right-of-use assets are determined on the same basis as those of property, plant and equipment. In addition, the right-of-use asset is assessed for impairment losses, should a trigger be identified and adjusted for impairment if required. Lease terms range up to 20 years for vessels, terminals, equipment, and other items.
The lease liability is measured at amortized cost using the effective interest method. It is remeasured when there is a change in future lease payments arising from a change in an index or rate, if there is a change in the Company’s estimate of the amount expected to be payable under a residual value guarantee or if the Company changes its assessment of whether it will exercise a purchase, extension or termination option. When the lease liability is remeasured in this way, a corresponding adjustment is made to the carrying amount of the right-of-use asset, or is recorded in profit or loss if the carrying amount of the right-of-use asset has been reduced to zero.
In determining the lease term, management considers all facts and circumstances that create an economic incentive to exercise an extension option, or not exercise a termination option. The assessment is reviewed upon a trigger by an event or a significant change in circumstances.
Certain leases contain non-lease components, excluded from the right-of-use asset and lease liability, related to operating charges for ocean vessels, terminal facilities and rail transport contracts. Judgment is applied in the determination of the stand-alone price of the lease and non-lease components.
The Company has elected not to recognize right-of-use assets and lease liabilities for short-term leases that have a lease term of 12 months or less and leases of low-value assets, except for terminal and vessel leases. The Company recognizes the lease payments associated with these leases as an expense on a straight-line basis over the lease term.
j) Site restoration costs:
k) Employee future benefits:
The Company has non-contributory defined benefit pension plans covering certain employees and defined contribution pension plans. The Company does not provide any significant post-retirement benefits other than pension plan benefits. For defined benefit pension plans, the net of the present value of the defined benefit obligation and the fair value of plan assets is recorded to the consolidated statements of financial position. The determination of the defined benefit obligation and associated pension cost is based on certain
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l) Share-based compensation:
The Company grants share-based awards as an element of compensation. Share-based awards granted by the Company can include stock options, tandem share appreciation rights, share appreciation rights, deferred share units, restricted share units or performance share units.
For stock options granted by the Company, the cost of the service received is measured based on an estimate of the fair value at the date of grant. The grant date fair value is recognized as compensation expense over the vesting period with a corresponding increase in contributed surplus. On the exercise of stock options, consideration received, together with the compensation expense previously recorded to contributed surplus, is credited to share capital. The Company uses the Black-Scholes option pricing model to estimate the fair value of each stock option tranche at the date of grant.
Share appreciation rights ("SARs") are units that grant the holder the right to receive a cash payment upon exercise for the difference between the market price of the Company’s common shares and the exercise price that is determined at the date of grant. Tandem share appreciation rights ("TSARs") give the holder the choice between exercising a regular stock option or a SAR. For SARs and TSARs, the cost of the service received is initially measured based on an estimate of the fair value at the date of grant. The grant date fair value is recognized as compensation expense over the vesting period with a corresponding increase in liabilities. For SARs and TSARs, the liability is re-measured at each reporting date based on an estimate of the fair value with changes in fair value recognized as compensation expense for the proportion of the service that has been rendered at that date. The Company uses the Black-Scholes option pricing model to estimate the fair value for SARs and TSARs.
Deferred, restricted and performance share units are grants of notional common shares that are redeemable for cash based on the market value of the Company’s common shares and are non-dilutive to shareholders.
Performance share units ("PSUs") granted from 2019 onwards are redeemable for cash based on the market value of the Company's common shares and are non-dilutive to shareholders. PSUs vest over three years and include two performance factors: (i) relative total shareholder return of Methanex shares versus a specific market index (the market performance factor) and (ii) three year average Return on Capital Employed ("ROCE") (the non-market performance factor). The market performance factor is measured by the Company at the grant date and reporting date using a Monte-Carlo simulation model to determine fair value. The non-market performance factor reflects management's best estimate of ROCE over the performance period (using actual ROCE as applicable) to determine the expected number of units to vest. Based on these performance factors the performance share unit payout will range between 0 % to 200 %.
For deferred, restricted and performance share units, the cost of the service received as consideration is initially measured based on the market value of the Company’s common shares at the date of grant. The grant date fair value is recognized as compensation expense over the vesting period with a corresponding increase in liabilities. Deferred, restricted and performance share units are re-measured at each reporting date based on the market value of the Company’s common shares with changes in fair value recognized as compensation expense for the proportion of the service that has been rendered at that date.
Additional information related to the stock option plan, TSARs, SARs and the deferred, restricted and performance share units is described in note 14.
m) Net income (loss) per common share:
The Company calculates basic net income (loss) per common share by dividing net income (loss) attributable to Methanex shareholders by the weighted average number of common shares outstanding and calculates diluted net income (loss) per common share under the treasury stock method. Under the treasury stock method, diluted net income (loss) per common share is calculated by considering the potential dilution that would occur if outstanding stock options and, under certain circumstances, TSARs were exercised or converted to common shares. Stock options and TSARs are considered dilutive when the average market price of the Company’s common shares during the period disclosed exceeds the exercise price of the stock option or TSAR.
The calculation of basic net income (loss) per common share and a reconciliation to diluted net income (loss) per common share is presented in note 13.
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n) Revenue recognition:
Revenue is recognized based on individual contract terms at the point in time when control of the product transfers to the customer, which usually occurs at the time shipment is made. Revenue is recognized at the time of delivery to the customer’s location if the contractual performance obligation has not been met at the time of shipment. For methanol sold on a consignment basis, revenue is recognized at the point in time the customer draws down the consigned methanol. Revenue is measured and recorded at the most likely amount of consideration the Company expects to receive.
By contract, the Company sells all the methanol produced by the Atlas Joint Venture and earns a commission on the sale of the methanol. As the Company obtains title and control of the methanol from the Atlas facility and directs the sale of the methanol to the Company's customers, the Company recognizes the revenue on these sales to customers at the gross amount receivable from the customers based on the Company's revenue recognition policy noted above. Cost of sales is recognized for these sales as the amount due to the Atlas Joint Venture which is the gross amount receivable less the commission earned by the Company.
o) Financial instruments:
All financial instruments are measured at fair value on initial recognition. Measurement in subsequent periods is dependent on the classification of the respective financial instrument. Financial instruments are classified into one of three categories and, depending on the category, will either be measured at amortized cost or fair value with fair value changes either recorded through profit or loss or other comprehensive income. All non-derivative financial instruments held by the Company are classified and measured at amortized cost.
The Company enters into derivative financial instruments to manage certain exposures to commodity price and foreign exchange volatility. Under these standards, derivative financial instruments, including embedded derivatives, are classified as fair value through profit or loss and are recorded in the consolidated statements of financial position at fair value unless they are in accordance with the Company’s normal purchase, sale or usage requirements. The valuation of derivative financial instruments is a critical accounting estimate due to the complex nature of these instruments, the degree of judgment required to appropriately value these instruments and the potential impact of such valuation on the Company’s financial statements. The Company records all changes in fair value of derivative financial instruments in profit or loss unless the instruments are designated as cash flow hedges. The Company enters into and designates as cash flow hedges certain forward contracts to hedge its highly probable forecast natural gas purchases and certain forward exchange purchase and sales contracts to hedge foreign exchange exposure on anticipated purchases or sales. The Company assesses at inception and on an ongoing basis whether the hedges are and continue to be effective in offsetting changes in the cash flows of the hedged transactions. The effective portion of changes in the fair value of these hedging instruments is recognized in other comprehensive income. Any gain or loss in fair value relating to the ineffective portion is recognized immediately in profit or loss. Until settled, the fair value of the derivative financial instruments will fluctuate based on changes in commodity prices, foreign currency exchange rates or variable interest rates.
Assessment of contracts as derivative instruments, applicability of the own use exemption, determination of whether hybrid instruments contain embedded derivatives to be separated, the valuation of financial instruments and derivatives and hedge effectiveness assessments require a high degree of judgment and are considered critical accounting judgements and estimates due to the complex nature of these products and the potential impact on our financial statements.
p) Fair value measurements:
q) Income taxes:
Income tax expense represents current tax and deferred tax. The Company records current tax based on the taxable profits for the period calculated using tax rates that have been enacted or substantively enacted by the reporting date. Income taxes relating to uncertain tax positions are provided for based on the Company’s best estimate. Deferred income taxes are accounted for using the liability method. The liability method requires that income taxes reflect the expected future tax consequences of temporary differences between the carrying amounts of assets and liabilities and their tax bases. Deferred income tax assets and liabilities are determined for each temporary difference based on currently enacted or substantially enacted tax rates that are expected to be in effect when the underlying items are expected to be realized. The effect of a change in tax rates or tax legislation is recognized in the period of substantive enactment. Deferred tax assets, such as non-capital loss carryforwards, are recognized to the extent it is probable that taxable profit will be available against which the asset can be utilized.
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The Company accrues for taxes that will be incurred upon distributions from its subsidiaries when it is probable that the earnings will be repatriated.
Uncertain tax positions derive from the complexity of tax law and its interpretation by tax authorities and ultimately the judicial system in place in each jurisdiction. Uncertain tax positions, including interest and penalties, are recognized and measured applying management estimates. Given the complexity, management engages third-party experts as required, for the interpretation of tax law, transfer pricing regulations and determination of the ultimate resolution of its tax positions. The Company is subject to various taxation authorities who may interpret tax legislation differently, and resolve matters over longer-periods of time. The differences in judgement in assessing uncertain tax positions may result in material differences in the final amount or timing of the payment of taxes or settlement of tax assessments.
r) Segmented information:
s) Application of new and revised accounting standards:
The Company has adopted the amendments to IAS 1, Presentation of Financial Statements regarding the classification of liabilities as current or non-current, IFRS 16, Leases regarding sale-and-leaseback transactions and IAS 7, Statement of Cash Flows regarding supplier finance arrangements, which were effective for annual periods beginning on January 1, 2024. The amendments did not have a material impact on the Company's consolidated financial statements.
t) Anticipated changes to International Financial Reporting Standards:
3. Trade and other receivables:
| As at | Dec 31 2024 | Dec 31 2023 | ||||||
| Trade | $ | $ | ||||||
| Value-added and other tax receivables | ||||||||
| Other | ||||||||
| $ | $ | |||||||
4. Inventories:
Inventories are valued at the lower of cost, determined on a first-in first-out basis, and estimated net realizable value. The amount of inventories recognized as an expense in cost of sales and operating expenses and depreciation and amortization for the year ended December 31, 2024 is $2,800 million (2023 - $2,860 million).
5. Property, plant and equipment:
| Owned Assets (a) | Right-of-use assets (c) | Total | |||||||||
| Net book value at December 31, 2024 | $ | $ | $ | ||||||||
| Net book value at December 31, 2023 | $ | $ | $ | ||||||||
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a) Owned assets:
Buildings, plant installations and machinery | Plants Under Construction1 | Ocean vessels | Other | TOTAL | ||||||||||||||||
| Cost at January 1, 2024 | $ | $ | $ | $ | $ | |||||||||||||||
Additions | ||||||||||||||||||||
Disposals and other | ( | ( | ( | ( | ( | |||||||||||||||
Transfers | ( | |||||||||||||||||||
| Cost at December 31, 2024 | ||||||||||||||||||||
| Accumulated depreciation at January 1, 2024 | ||||||||||||||||||||
Depreciation | ||||||||||||||||||||
Asset impairment charge (b) | ||||||||||||||||||||
Disposals and other | ( | ( | ( | |||||||||||||||||
| Accumulated depreciation at December 31, 2024 | ||||||||||||||||||||
| Net book value at December 31, 2024 | $ | $ | $ | $ | $ | |||||||||||||||
1 Geismar 3 completed its commercial performance tests and reached the use intended by management in 2024. As a result, it was transferred to Buildings, Plant Installations & Machinery during the year. Included in the final cost of the Geismar 3 plant is $201 million (2023: $150 million) of capitalized interest and finance charges.
Buildings, plant installations and machinery | Plants under construction | Ocean vessels | Other | TOTAL | ||||||||||||||||
Cost at January 1, 2023 | $ | $ | $ | $ | $ | |||||||||||||||
| Additions | ||||||||||||||||||||
Disposals and other | ( | ( | ( | ( | ||||||||||||||||
Cost at December 31, 2023 | ||||||||||||||||||||
Accumulated depreciation at January 1, 2023 | ||||||||||||||||||||
Depreciation | ||||||||||||||||||||
Disposals and other | ( | ( | ( | |||||||||||||||||
Accumulated depreciation at December 31, 2023 | ||||||||||||||||||||
Net book value at December 31, 2023 | $ | $ | $ | $ | $ | |||||||||||||||
Based on natural gas feedstock availability and the completion of Geismar 3, the Company has extended the useful lives of the Chile facilities and Geismar 1 and 2. The effect of these changes on actual and expected depreciation expense was as follows.
| 2024 | 2025 | 2026 | 2027 | 2028 | Later | |||||||||||||||
| (Decrease) increase in depreciation expense | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | |||||||||
b) Asset impairment charge:
The Company reviews the carrying value of long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. The Company decided to restructure its New Zealand operations to a single plant operation in September 2024 due to a forecasted decline in New Zealand’s gas profile. The restructuring and shift to a one plant operation has been identified as an impairment indicator for the New Zealand cash generating unit ("New Zealand CGU") and the carrying value of the New Zealand CGU was tested for impairment during the year.
The recoverable amount of the New Zealand CGU was based on fair value less costs of disposal, estimated using discounted cash flows. The model contains significant unobservable inputs and as a result is classified within Level 3 of the fair value hierarchy. Impairment was measured by comparing the carrying value of the New Zealand CGU to estimated fair value, discounted at a rate of 9 %.
There are two key variables that impact the Company’s estimates of future cash flows: (1) the methanol price and (2) the price and availability of natural gas feedstock. Methanol price estimates are based on supply and demand fundamentals and consideration is given to many factors, including, but not limited to, estimates of global industrial production rates, energy prices, changes in general economic conditions, future global methanol production capacity, industry operating rates and the global industry cost structure. The Company’s estimate of the price and availability of natural gas takes into consideration the current contracted terms, as well as factors that it believes are relevant to supply under these contracts and supplemental natural gas sources. Other assumptions included in the Company’s estimate of future cash flows include the estimated cost incurred to maintain the facilities, estimates of transportation costs and other variable costs incurred in producing methanol in each period. The values assigned to the key assumptions represent management's assessment of future trends and have been based on historical data from both external and internal sources.
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Based on the test performed, the Company recorded a non-cash before-tax asset impairment charge of $125 million ($90 million after-tax) in property, plant and equipment to write down the carrying value of the New Zealand CGU to its recoverable amount.
The following table presents the Level 3 inputs and the sensitivities of the fair value less costs of disposal model to changes in these inputs:
| Sensitivities | |||||||||||
Valuation input | Input value or range | Change in input | Resulting change in valuation | ||||||||
| Methanol price forecast | $ | +/- $ | $+ | ||||||||
Natural gas availability | Annual estimates based on third party forecasts | +/- | $+ | ||||||||
| Discount rate (after-tax) | +/- | $+/- | |||||||||
The sensitivity has been prepared considering each variable independently. It is possible that the assumptions used in establishing fair value amounts will differ from future outcomes and the impact of such variations could be material.
c) Right-of-use (leased) assets:
| Ocean vessels | Terminals and tanks | Other | TOTAL | ||||||||||||||
| Cost at January 1, 2024 | $ | $ | $ | $ | |||||||||||||
Additions | |||||||||||||||||
Disposals and other | ( | ( | ( | ( | |||||||||||||
| Cost at December 31, 2024 | |||||||||||||||||
| Accumulated depreciation at January 1, 2024 | |||||||||||||||||
Depreciation | |||||||||||||||||
Disposals and other | ( | ( | ( | ( | |||||||||||||
| Accumulated depreciation at December 31, 2024 | |||||||||||||||||
| Net book value at December 31, 2024 | $ | $ | $ | $ | |||||||||||||
| Ocean vessels | Terminals and tanks | Other | TOTAL | ||||||||||||||
| Cost at January 1, 2023 | $ | $ | $ | $ | |||||||||||||
Additions | |||||||||||||||||
Disposals and other | ( | ( | ( | ( | |||||||||||||
| Cost at December 31, 2023 | |||||||||||||||||
| Accumulated depreciation at January 1, 2023 | |||||||||||||||||
Depreciation | |||||||||||||||||
Disposals and other | ( | ( | ( | ||||||||||||||
| Accumulated depreciation at December 31, 2023 | |||||||||||||||||
| Net book value at December 31, 2023 | $ | $ | $ | $ | |||||||||||||
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6. Investment in associate:
a) The Company has a 63.1 % equity interest in Atlas Methanol Company Unlimited ("Atlas"). Atlas owns a 1.8 million tonne per year methanol production facility in Trinidad and Tobago. In mid-September the Atlas facility was idled, as its legacy 20-year natural gas supply agreement expired. The Company accounts for its interest in Atlas using the equity method. Summarized financial information of Atlas (100 % basis) is as follows:
Consolidated statements of financial position as at | Dec 31 2024 | Dec 31 2023 | ||||||
Cash and cash equivalents | $ | $ | ||||||
Other current assets1 | ||||||||
Non-current assets | ||||||||
Current liabilities1 | ( | ( | ||||||
Other long-term liabilities, including current maturities | ( | ( | ||||||
Net assets at | $ | $ | ||||||
Net assets at | $ | $ | ||||||
Long-term receivable from Atlas1 | ||||||||
Investment in associate | $ | $ | ||||||
Consolidated statements of income for the years ended December 31 | 2024 | 2023 | ||||||
Revenue1 | $ | $ | ||||||
Cost of sales and depreciation and amortization | ( | ( | ||||||
| Gas contract settlement | ||||||||
Operating income | ||||||||
Finance costs, finance income and other expenses | ( | ( | ||||||
Income tax expense (b) | ( | ( | ||||||
Net earnings at | $ | $ | ||||||
Earnings of associate at | $ | $ | ||||||
Dividends received from associate | $ | $ | ||||||
Share capital reduction | $ | $ | ||||||
b) Atlas tax assessments:
The Board of Inland Revenue of Trinidad and Tobago ("the BIR") has audited and issued assessments against Atlas in respect of the 2005 to 2018 financial years. All subsequent tax years remain open to assessment. The assessments relate to the pricing arrangements of certain long-term fixed-price sales contracts that commenced in 2005 and continued with affiliates through 2014 and with an unrelated third party through 2019.
The long-term fixed-price sales contracts with affiliates were established as part of the formation of Atlas and management believes these were reflective of market considerations at that time.
During the periods under assessment and continuing through 2014, approximately 50 % of Atlas-produced methanol was sold under these fixed-price contracts. From late 2014 through 2019 fixed-price sales to an unrelated third party represented approximately 10 % of Atlas produced methanol. Atlas had partial relief from corporation income tax until late July 2014.
The Company believes it is impractical to disclose a reasonable estimate of the potential contingent liability due to the wide range of assumptions and interpretations implicit in the assessments.
The Company has lodged objections to the assessments. No deposits have been required to lodge objections. Based on the merits of the cases and advice from legal counsel, the Company believes its position should be sustained, that Atlas has filed its tax returns and paid applicable taxes in compliance with Trinidadian tax law, and as such has not accrued for any amounts relating to these assessments. Contingencies inherently involve the exercise of significant judgment, and as such the outcomes of these assessments and the financial impact to the Company could be material.
During the year, the Trinidad tax court issued a ruling in the Company's favour. At present the BIR is reviewing whether to proceed with an appeal and should it decide to proceed, the Company will continue to defend its position. The Company anticipates the resolution of this matter through the court systems to be lengthy and, at this time, cannot predict a date as to when this matter is expected to be ultimately resolved.
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7. Other assets:
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Cash flow hedges (note 19) | $ | $ | ||||||
Chile VAT receivable | ||||||||
Restricted cash for debt service and major maintenance of vessels (a) | ||||||||
Fair value of Egypt gas supply contract derivatives (note 19) | ||||||||
| Fair value of New Zealand gas supply contract derivatives (note 19) | ||||||||
| Deposit for catalyst supply | ||||||||
Investment in Carbon Recycling International | ||||||||
Defined benefit pension plans (note 21) | ||||||||
Other | ||||||||
| Total other assets | ||||||||
Less current portion (b) | ( | ( | ||||||
| $ | $ | |||||||
a) Restricted cash
The Company holds $14.3 million (2023 - $15.8 million) of restricted cash for the funding of debt service and major maintenance accounts.
b) Current portion of other assets
8. Long-term debt:
| As at | Dec 31 2024 | Dec 31 2023 | |||||||||
| Unsecured notes | |||||||||||
(i) $ | $ | $ | |||||||||
(ii) $ | |||||||||||
(iii) $ | |||||||||||
(iv) $ | |||||||||||
(v) $ | |||||||||||
| Other limited recourse debt facilities | |||||||||||
(i) | |||||||||||
(ii) | |||||||||||
(iii) | |||||||||||
Total long-term debt1 | |||||||||||
Less current maturities1 | ( | ( | |||||||||
| $ | $ | ||||||||||
For the year ended December 31, 2024, non-cash accretion, on an effective interest basis, of deferred financing costs included in finance costs was $3.1 million (2023 - $2.6 million).
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The gross minimum principal payments for long-term debt in aggregate and for each of the five succeeding years are as follows:
| Other limited recourse debt facilities | Unsecured notes | Total | |||||||||||||||
| 2025 | $ | $ | $ | ||||||||||||||
| 2026 | |||||||||||||||||
| 2027 | |||||||||||||||||
| 2028 | |||||||||||||||||
| 2029 | |||||||||||||||||
Thereafter | |||||||||||||||||
| $ | $ | $ | |||||||||||||||
During the year, the maturity date of the previously established $300 million revolving credit facility was renewed to April 2028 and an additional $200 million tranche was added which expires in April 2026, increasing the total amount available under the revolving credit facility as at December 31, 2024 to $500 million. The facilities are with a syndicate of highly rated financial institutions.
The existing revolving credit facility was entered into with the following significant covenants and default provisions:
i) the obligation to maintain a minimum interest coverage ratio of EBITDA to net interest expense greater than or equal to 2 :1 calculated on a four-quarter trailing basis and a funded debt to total capitalization ratio of less than or equal to 60 %, both calculated in accordance with definitions in the credit agreement that include adjustments to limited recourse subsidiaries,
ii) a default if payment is accelerated by a creditor on any indebtedness of $50 million or more of the Company and its subsidiaries, except for limited recourse subsidiaries, and
iii) a default if a default occurs that permits a creditor to demand repayment on any other indebtedness of $50 million or more of the Company and its subsidiaries, except for limited recourse subsidiaries.
The revolving credit facility is partially secured by certain assets of the Company, and also includes other customary covenants including restrictions on the incurrence of additional indebtedness.
To support the OCI Acquisition (Refer to note 27 - Agreement to acquire OCI Global's methanol business), the Company renewed its $500 million revolving credit facility by increasing the existing $300 million tranche to $400 million with a new five-year tenor, and the renewal of the $200 million tranche with a new three-year tenor, both from the closing date of the OCI Acquisition. Additionally, a term loan commitment of $650 million was added to partially finance the OCI Acquisition. The increase to a total availability of $600 million under the revolving credit facility and availability of the $650 million term loan commitment are subject to the closing of the OCI Acquisition. During the year ended December 31, 2024, the Company (through its wholly-owned US subsidiary, Methanex US Operations Inc.) also issued $600 million of senior unsecured notes bearing a coupon of 6.25 % and due March 15, 2032. The $600 million senior unsecured notes are subject to a special mandatory redemption if either (1) the OCI Acquisition is not completed within the time period required by the related acquisition agreement, as it may be extended (but in no event later than May 31, 2026) or (2) Methanex publicly announces that it will not proceed with the OCI Acquisition for any reason, as further described in the terms of the notes. The Company also repaid $300 million of unsecured notes due December 1, 2024.
In October, to support the OCI Acquisition, the Company successfully syndicated a 364-day bridge facility (“Bridge Facility”).
As a result of the successful syndication of the $650 million term loan commitment and successful issuance of the $600 million
senior unsecured notes, the commitment under the Bridge Facility was reduced to nil and the facility was terminated in
November 2024.
The covenants governing the Company’s and Methanex US Operations Inc.'s unsecured notes, which are specified in an indenture, apply to the Company, Methanex US Operations Inc. and its subsidiaries, excluding the Egypt entity and the Atlas joint venture entity, and include restrictions on liens, sale and lease-back transactions, a merger or consolidation with another corporation or sale of all or substantially all of the Company’s assets. The indentures also contain customary default provisions.
Failure to comply with any of the covenants or default provisions of the long-term debt arrangements described above could result in a default under the applicable credit agreement that would allow the lenders to not fund future loan requests, accelerate the due date of the principal and accrued interest on any outstanding loans or restrict the payment of cash or other distributions.
As at December 31, 2024, management believes the Company was in compliance with all covenants related to long-term debt obligations.
64
9. Lease obligations:
| 2024 | 2023 | |||||||
| Opening lease obligations | $ | $ | ||||||
| Additions, net of disposals | ||||||||
| Interest expense | ||||||||
| Lease payments | ( | ( | ||||||
| Effect of movements in exchange rates and other | ( | ( | ||||||
| Lease obligations at December 31 | ||||||||
| Less: current portion | ( | ( | ||||||
| Lease obligations - non current portion | $ | $ | ||||||
The Company incurs lease payments related to ocean vessels, terminal facilities, rail cars, vehicles and equipment, and office facilities. Leases are entered into and exited in coordination with specific business requirements which includes the assessment of the appropriate durations for the related leased assets.
The following table presents the contractual undiscounted cash flows for lease obligations as at December 31, 2024:
| Lease payments | Interest component | Lease obligations | ||||||||||||||||||
| 2025 | $ | $ | $ | |||||||||||||||||
| 2026 | ||||||||||||||||||||
| 2027 | ||||||||||||||||||||
| 2028 | ||||||||||||||||||||
| 2029 | ||||||||||||||||||||
Thereafter | ||||||||||||||||||||
| $ | $ | $ | ||||||||||||||||||
Variable lease payments and short-term and low value leases
Certain leases contain non-lease components, excluded from the right-of-use asset and lease liability, related to operating charges for ocean vessels and terminal facilities. The total expense recognized in cost of sales relating to operating charges for 2024 was $90.9 million (2023 - $83.8 million). Short-term leases are leases with a lease term of twelve months or less while low-value leases are comprised of information technology and miscellaneous equipment. Such items recognized within cost of sales in 2024 were $0.4 million (2023 - $0.2 million).
Extension options
Some leases contain extension options exercisable by the Company. Where practicable, the Company seeks to include extension options in new leases to provide operational flexibility. The extension options held are exercisable only by the Company and not by the lessors. The Company assesses, at lease commencement, whether it is reasonably certain to exercise the extension options. The Company reassesses whether it is reasonably certain to exercise the options if there is a significant event or significant change in circumstances within its control. Total potential future lease payments not included in the lease liabilities should the Company exercise these extension options totals $56.5 million (2023 - $51.8 million).
| Lease liabilities recognized (discounted) | Potential future lease payments not included in lease liabilities (undiscounted) | ||||||||||
| Ocean-going vessels | $ | $ | |||||||||
| Terminals and tanks | |||||||||||
| Other | |||||||||||
| Total | $ | $ | |||||||||
Leases not yet commenced
As at December 31, 2024, the Company has entered into lease agreements for which the leases have not yet commenced. Total exposure to undiscounted future cash outflows not reflected in lease liabilities is $2.8 million (2023 - $68.7 million). The leases not yet commenced as at December 31, 2024 related to the addition of 1 new ocean vessel in 2025 with a 1-year term. The leases not yet commenced as at December 31, 2023 related to terminal agreements, railcar agreements, storage tank agreements and the addition of 1 new ocean vessel in 2024 with a 5-year term, replacing an existing ocean vessel lease that commenced in 2024.
65
10. Other long-term liabilities:
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Share-based compensation liability (note 14) | $ | $ | ||||||
Site restoration costs | ||||||||
Land mortgage | ||||||||
Defined benefit pension plans (note 21) | ||||||||
Cash flow hedges (note 19) | ||||||||
Other | ||||||||
Less current maturities | ( | ( | ||||||
| $ | $ | |||||||
Site restoration costs:
The Company has accrued liabilities related to the decommissioning and reclamation of its methanol production sites and oil and gas properties. Because of uncertainties in estimating the amount and timing of the expenditures related to the sites, actual results could differ from the amounts estimated. As at December 31, 2024, the total undiscounted amount of estimated cash flows required to settle the liabilities was $64.1 million (2023 - $50.6 million). The movement in the provision during the year is explained as follows:
| 2024 | 2023 | |||||||
Balance at January 1 | $ | $ | ||||||
New or revised provisions | ( | |||||||
Accretion expense | ||||||||
Balance at December 31 | $ | $ | ||||||
11. Expenses:
For the years ended December 31 | 2024 | 2023 | ||||||
Cost of sales | $ | $ | ||||||
Selling and distribution | ||||||||
Administrative expenses | ||||||||
Total expenses by function | $ | $ | ||||||
Cost of raw materials and purchased methanol | ||||||||
Ocean freight and other logistics | ||||||||
Employee expenses, including share-based compensation | ||||||||
Other expenses | ||||||||
Cost of sales and operating expenses | ||||||||
Depreciation and amortization | ||||||||
Total expenses by nature | $ | $ | ||||||
For the year ended December 31, 2024 we recorded a share-based compensation expense of $24.0 million (2023 - expense of $34.5 million), the majority of which is included in administrative expenses for the total expenses by function presentation above.
Included in cost of sales is $344.9 million (2023 - $466.3 million) of cost of sales which are recognized as sales to Methanex in our Atlas equity investee’s statements of income.
12. Finance costs:
For the years ended December 31 | 2024 | 2023 | ||||||
Finance costs before capitalized interest | $ | $ | ||||||
| Less capitalized interest related to Geismar plant under construction | ( | ( | ||||||
| Finance costs | $ | $ | ||||||
Finance costs are primarily comprised of interest on the unsecured notes, limited recourse debt facilities, finance lease obligations, amortization of deferred financing fees, and accretion expense associated with site restoration costs. Interest during construction projects is capitalized until the plant is substantially completed and ready for productive use. The Geismar 3 plant completed its commercial performance tests rates during the fourth quarter of 2024, and accordingly, we ceased capitalizing interest costs related to Geismar 3 from the date.
66
13. Net income per common share:
Diluted net income per common share is calculated by considering the potential dilution that would occur if outstanding stock options and, under certain circumstances, tandem share appreciation rights ("TSARs") were exercised or converted to common shares.
Outstanding TSARs may be settled in cash or common shares at the holder’s option and for purposes of calculating diluted net income per common share, the more dilutive of the cash-settled and equity-settled method is used, regardless of how the plan is accounted for. Accordingly, TSARs that are accounted for using the cash-settled method will require adjustments to the numerator if the equity-settled method is determined to have a dilutive effect on diluted net income per common share as compared to the cash-settled method. The equity-settled method was more dilutive for the year ended December 31, 2024, and an adjustment was required for the numerator and the denominator. The cash-settled method was more dilutive for the year ended December 31, 2023, and no adjustment was required for both the numerator and denominator.
Stock options and, if calculated using the equity-settled method, TSARs are considered dilutive when the average market price of the Company’s common shares during the period disclosed exceeds the exercise price of the stock option or TSAR. For the year ended December 31, 2024 and 2023, stock options were dilutive, resulting in an adjustment to the denominator. For the year ended December 31, 2024, TSARs were dilutive, resulting in an adjustment to the denominator. For the year ended December 31, 2023, TSARs were not dilutive, resulting in no adjustment to the denominator.
A reconciliation of the numerator used for the purposes of calculating diluted net income per common share is as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Numerator for basic net income per common share | $ | $ | ||||||
Adjustment for the effect of TSARs: | ||||||||
Cash-settled recovery included in net income | ||||||||
Equity-settled expense | ( | |||||||
Numerator for diluted net income per common share | $ | $ | ||||||
A reconciliation of the denominator used for the purposes of calculating diluted net income per common share is as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Denominator for basic net income per common share | ||||||||
Effect of dilutive stock options | ||||||||
Effect of dilutive TSARS | ||||||||
Denominator for diluted net income per common share | ||||||||
For the years ended December 31, 2024 and 2023, basic and diluted net income per common share attributable to Methanex shareholders were as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Basic net income per common share | $ | $ | ||||||
Diluted net income per common share | $ | $ | ||||||
14. Share-based compensation:
The Company provides share-based compensation to its directors and certain employees through grants of stock options, TSARs, SARs and deferred, restricted or performance share units.
As at December 31, 2024, the Company had 4,211,772 common shares reserved for future grants of stock options and tandem share appreciation rights under the Company’s stock option plan.
67
a) Share appreciation rights and tandem share appreciation rights:
All SARs and TSARs granted have a maximum term of seven years with one-third vesting each year from the date of grant. SARs and TSARs units outstanding at December 31, 2024 and 2023 are as follows:
| SARs | TSARs | ||||||||||||||||
| Number of units | Exercise price USD | Number of units | Exercise price USD | ||||||||||||||
| Outstanding at December 31, 2022 | $ | $ | |||||||||||||||
Granted | |||||||||||||||||
Exercised | ( | ( | |||||||||||||||
Cancelled | ( | ( | |||||||||||||||
| Outstanding at December 31, 2023 | $ | $ | |||||||||||||||
Granted | |||||||||||||||||
Exercised | ( | ( | |||||||||||||||
Cancelled | ( | ( | |||||||||||||||
Expired | ( | ( | |||||||||||||||
| Outstanding at December 31, 2024 | $ | $ | |||||||||||||||
Information regarding the SARs and TSARs outstanding as at December 31, 2024 is as follows:
| Units outstanding at December 31, 2024 | Units exercisable at December 31, 2024 | |||||||||||||||||||
Range of exercise prices | Weighted average remaining contractual life (years) | Number of units outstanding | Weighted average exercise price | Number of units exercisable | Weighted average exercise price | |||||||||||||||
SARs | ||||||||||||||||||||
$ | $ | $ | ||||||||||||||||||
$ | ||||||||||||||||||||
$ | ||||||||||||||||||||
| $ | $ | |||||||||||||||||||
TSARs | ||||||||||||||||||||
$ | $ | $ | ||||||||||||||||||
$ | ||||||||||||||||||||
$ | ||||||||||||||||||||
| $ | $ | |||||||||||||||||||
The fair value of each outstanding SARs and TSARs grant was estimated on December 31, 2024 and 2023 using the Black-Scholes option pricing model with the following weighted average assumptions:
| 2024 | 2023 | |||||||
Risk-free interest rate | ||||||||
Expected dividend yield | ||||||||
Expected life of SARs and TSARs (years) | ||||||||
Expected volatility | ||||||||
Expected forfeitures | ||||||||
Weighted average fair value (USD per unit) | $ | $ | ||||||
Compensation expense for SARs and TSARs is measured based on their fair value and is recognized over the vesting period. Changes in fair value each period are recognized in net income for the proportion of the service that has been rendered at each reporting date. The fair value as at December 31, 2024 was $28.1 million compared with the recorded liability of $25.3 million. The difference between the fair value and the recorded liability of $2.8 million will be recognized over the weighted average remaining vesting period of approximately 1.5 years.
For the year ended December 31, 2024, compensation expense related to SARs and TSARs included an expense in cost of sales and operating expenses of $3.9 million (2023 - expense of $10.5 million). This included a recovery of $1.8 million (2023 - expense of $6.6 million) related to the effect of the change in the Company’s share price.
68
b) Deferred, restricted and performance share units (old plan and new plan):
Deferred, restricted and performance share units (old plan and new plan) outstanding as at December 31, 2024 and 2023 are as follows:
Number of deferred share units | Number of restricted share units | Number of performance share units (new plan) | ||||||||||||||||||
| Outstanding at December 31, 2022 | ||||||||||||||||||||
Granted | ||||||||||||||||||||
Performance factor impact on redemption1 | ||||||||||||||||||||
Granted in lieu of dividends | ||||||||||||||||||||
Redeemed | ( | ( | ( | |||||||||||||||||
Cancelled | ( | ( | ||||||||||||||||||
| Outstanding at December 31, 2023 | ||||||||||||||||||||
Granted | ||||||||||||||||||||
Performance factor impact on redemption1 | ||||||||||||||||||||
Granted in lieu of dividends | ||||||||||||||||||||
Redeemed | ( | ( | ( | |||||||||||||||||
Cancelled | ( | ( | ||||||||||||||||||
| Outstanding at December 31, 2024 | ||||||||||||||||||||
1 The number of performance share units that ultimately vest are determined by performance factors as described below. The performance factors impact relates to performance share units redeemed in the quarter ended March 31, 2024 and the quarter ended March 31, 2023.
Performance share units are redeemable for cash based on the market value of the Company's common shares and are non-dilutive to shareholders. Units vest over three years and include two equally weighted performance factors: (i) relative total shareholder return of Methanex shares versus a specific market index (the market performance factor) and (ii) three year average modified return on capital employed (the non-market performance factor). The market performance factor is measured by the Company at the grant date and reporting date using a Monte-Carlo simulation model to determine fair value. The non-market performance factor reflects management's best estimate to determine the expected number of units to vest. Based on these performance factors the performance share unit payout will range between 0 % to 200 %.
Compensation expense for deferred, restricted and performance share units is measured at fair value based on the market value of the Company’s common shares and is recognized over the vesting period. Changes in fair value are recognized in net income for the proportion of the service that has been rendered at each reporting date. The fair value of deferred, restricted and performance share units at December 31, 2024 was $60.5 million compared with the recorded liability of $48.5 million. The difference between the fair value and the recorded liability of $12.0 million will be recognized over the weighted average remaining vesting period of approximately 1.7 years.
15. Segmented information:
The Company’s operations consist of the production and sale of methanol, which constitutes a single operating segment.
During the years ended December 31, 2024 and 2023, revenues attributed to geographic regions, based on the location of customers, were as follows:
Revenue | China | Europe | United States | South America | South Korea | Other Asia | Canada | TOTAL | |||||||||||||||||||||
| 2024 | $ | $ | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||
| % | % | % | % | % | % | % | % | ||||||||||||||||||||||
| 2023 | $ | $ | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||
| % | % | % | % | % | % | % | % | ||||||||||||||||||||||
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As at December 31, 2024 and 2023, the net book value of property, plant and equipment by geographic region, and the Company's shipping business, was as follows:
Property, plant and equipment 1 | United States | Egypt | New Zealand | Canada | Chile | Trinidad | Waterfront Shipping | Other | TOTAL | |||||||||||||||||||||||
| December 31, 2024 | $ | $ | $ | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||
| December 31, 2023 | $ | $ | $ | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||
1 Includes right-of-use (leased) assets.
16. Income and other taxes:
a) Income tax (expense) recovery:
For the years ended December 31 | 2024 | 2023 | ||||||
Current tax (expense) recovery: | ||||||||
Current period before undernoted items | $ | ( | $ | ( | ||||
| Adjustments to prior years including resolution for certain outstanding audits | ||||||||
| ( | ( | |||||||
Deferred tax recovery (expense): | ||||||||
Origination and reversal of temporary differences | ||||||||
| Adjustments to prior years including resolution for certain outstanding audits | ( | |||||||
Changes in tax rates | ( | |||||||
Impact of foreign exchange and other | ( | |||||||
Total income tax expense | $ | ( | $ | ( | ||||
b) Reconciliation of the effective tax rate:
The Company operates in several tax jurisdictions and therefore its income is subject to various rates of taxation. Income tax expense differs from the amounts that would be obtained by applying the Canadian statutory income tax rate to net income before income taxes as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Income before income taxes | $ | $ | ||||||
Deduct earnings of associate | ( | ( | ||||||
Canadian statutory tax rate | % | % | ||||||
Income tax expense calculated at Canadian statutory tax rate | ( | ( | ||||||
Decrease (increase) in income tax expense resulting from: | ||||||||
Impact of income and losses taxed in foreign jurisdictions | ||||||||
Utilization of unrecognized loss carryforwards and temporary differences | ||||||||
Impact of tax rate changes | ( | |||||||
Impact of foreign exchange | ||||||||
Other business taxes | ( | |||||||
Impact of items not taxable for tax purposes | ||||||||
| Adjustments to prior years including resolution for certain outstanding audits | ( | |||||||
Other | ( | ( | ||||||
Total income tax expense | $ | ( | $ | ( | ||||
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c) Net deferred income tax assets and liabilities:
(i) The tax effect of temporary differences that give rise to deferred income tax liabilities and deferred income tax assets is as follows:
As at | Dec 31, 2024 | Dec 31, 2023 | |||||||||||||||||||||
Net | Deferred tax assets | Deferred tax liabilities | Net | Deferred tax assets | Deferred tax liabilities | ||||||||||||||||||
Property, plant and equipment (owned) | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||
Right-of-use assets | ( | ( | ( | ( | ( | ( | |||||||||||||||||
Repatriation taxes | ( | ( | ( | ( | ( | ( | |||||||||||||||||
Other | ( | ( | ( | ( | ( | ( | |||||||||||||||||
| ( | ( | ( | ( | ( | ( | ||||||||||||||||||
Non-capital loss carryforwards | |||||||||||||||||||||||
Lease obligations | |||||||||||||||||||||||
Share-based compensation | |||||||||||||||||||||||
Other | |||||||||||||||||||||||
Net deferred income tax assets (liabilities) | $ | ( | $ | $ | ( | $ | ( | $ | $ | ( | |||||||||||||
As at December 31, 2024, deferred income tax assets have been recognized in respect of non-capital loss carryforwards generated in the United States. These loss carryforwards expire as follows:
| Dec 31 2024 | ||||||||
| Gross amount | Tax effect | |||||||
Expire | ||||||||
Losses generated in 2015 (expires 2035) | $ | $ | ||||||
Losses generated in 2016 (expires 2036) | ||||||||
Losses generated in 2017 (expires 2037) | ||||||||
No expiry | ||||||||
| Losses generated in 2019 | ||||||||
| Losses generated in 2020 | ||||||||
Losses generated in 2023 | ||||||||
Losses generated in 2024 | ||||||||
Total non-capital loss carryforwards | $ | $ | ||||||
Losses generated in the United States on or after January 1, 2018 may be carried forward indefinitely against future taxable income. Tax losses generated before December 31, 2017 may be carried forward for a 20 year period.
As at December 31, 2024 the Company had $170 million (2023 - $201 million) of deductible temporary differences in the United States that have not been recognized.
As at December 31, 2024, deferred income tax assets have been recognized in respect of non-capital loss carryforwards generated in Trinidad. The loss carryforwards total $107 million (2023 - $82 million), which result in a deferred income tax asset of $38 million (2023 - $29 million). The losses generated in Trinidad may be carried forward indefinitely against future taxable income.
As at December 31, 2024, deferred income tax assets have been recognized in respect of non-capital loss carryforwards generated in New Zealand. The loss carryforwards total $36 million (2023 - $25 million), which result in a deferred income tax asset of $10 million (2023 - $7 million). The losses generated in New Zealand may be carried forward indefinitely against future taxable income.
As at December 31, 2024, deferred income tax assets have been recognized in respect of non-capital loss carryforwards generated in Canada. The loss carryforwards total $47 million (2023 - $123 million), which result in a deferred income tax asset of $12 million (2023 - $30 million). The losses were generated in 2020 and can be carried forward 20 years against future taxable income.
71
(ii) Analysis of the change in deferred income tax assets and liabilities:
| 2024 | 2023 | ||||||||||||||||||||||
| Net | Deferred tax assets | Deferred tax liabilities | Net | Deferred tax assets | Deferred tax liabilities | ||||||||||||||||||
Balance, January 1 | $ | ( | $ | $ | ( | $ | ( | $ | $ | ( | |||||||||||||
Deferred income tax recovery (expense) included in net income | ( | ||||||||||||||||||||||
Deferred income tax recovery (expense) included in other comprehensive income | ( | ( | ( | ||||||||||||||||||||
Other | ( | ( | |||||||||||||||||||||
Balance, December 31 | $ | ( | $ | $ | ( | $ | ( | $ | $ | ( | |||||||||||||
International Tax Reform — Pillar Two Rules
17. Supplemental cash flow information:
a) Changes in non-cash working capital:
Changes in non-cash working capital for the years ended December 31, 2024 and 2023 were as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Changes in non-cash working capital: | ||||||||
Trade and other receivables | $ | $ | ( | |||||
Inventories | ( | |||||||
Prepaid expenses | ( | ( | ||||||
Trade, other payables and accrued liabilities | ( | ( | ||||||
| ( | ( | |||||||
Adjustments for items not having a cash effect and working capital changes relating to taxes and interest paid and interest received | ( | |||||||
Changes in non-cash working capital having a cash effect | $ | ( | $ | ( | ||||
These changes relate to the following activities: | ||||||||
Operating | $ | ( | $ | ( | ||||
Financing | ( | |||||||
Investing | ( | ( | ||||||
Changes in non-cash working capital | $ | ( | $ | ( | ||||
b) Reconciliation of movements in liabilities to cash flows arising from financing activities:
Long term debt (note 8) | Lease obligations (note 9) | ||||||||||||||||
Balance at December 31, 2023 | $ | $ | |||||||||||||||
Changes from financing cash flows | |||||||||||||||||
Repayment of long-term debt and financing fees | ( | ||||||||||||||||
Net proceeds on issue of long-term debt | |||||||||||||||||
Payment of lease obligations | ( | ||||||||||||||||
| Total changes from financing cash flows | ( | ||||||||||||||||
Liability-related other changes | |||||||||||||||||
Finance costs | |||||||||||||||||
New lease obligations | |||||||||||||||||
Other | ( | ||||||||||||||||
Total liability-related other changes | |||||||||||||||||
Balance at December 31, 2024 | $ | $ | |||||||||||||||
72
18. Capital disclosures:
The Company’s objective in managing liquidity and capital is to safeguard the Company’s ability to continue as a going concern and to provide financial capacity and flexibility to meet its strategic objectives, with a focus on cash preservation and liquidity.
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Liquidity: | ||||||||
Cash and cash equivalents | $ | $ | ||||||
Undrawn credit facility | ||||||||
Total liquidity | $ | $ | ||||||
Capitalization: | ||||||||
Unsecured notes, including current portion | ||||||||
Other limited recourse debt facilities, including current portion | ||||||||
Total debt | ||||||||
Non-controlling interests | ||||||||
Shareholders’ equity | ||||||||
Total capitalization | $ | $ | ||||||
Total debt to capitalization 1 | ||||||||
Net debt to capitalization 2 | ||||||||
1 Total debt (including Other limited recourse debt facilities) divided by total capitalization.
The Company manages its liquidity and capital structure and makes adjustments to it in light of changes to economic conditions, the underlying risks inherent in its operations and capital requirements to maintain and grow its operations. The strategies employed by the Company may include the issue or repayment of general corporate debt, the issue of project debt, private placements by limited recourse subsidiaries, the issue of equity, the payment of dividends and the repurchase of shares.
The Company is not subject to any statutory capital requirements and has no commitments to sell or otherwise issue common shares except pursuant to outstanding employee stock options.
19. Financial instruments:
Financial instruments are either measured at amortized cost or fair value.
In the normal course of business, the Company's assets, liabilities and forecasted transactions, as reported in U.S. dollars, are impacted by various market risks including, but not limited to, natural gas prices and currency exchange rates. The time frame and manner in which the Company manages those risks varies for each item based on the Company's assessment of the risk and the available alternatives for mitigating risks.
The Company uses derivatives as part of its risk management program to mitigate variability associated with changing market values. Changes in the fair value of derivative financial instruments are recorded in earnings unless the instruments are designated as cash flow hedges, in which case the changes in fair value are recorded in other comprehensive income and are reclassified to profit or loss or accumulated other comprehensive income when the underlying hedged transaction is recognized in earnings or inventory. The Company designates as cash flow hedges certain derivative financial instruments to hedge its risk exposure to fluctuations in natural gas prices and to hedge its risk exposure to fluctuations on certain foreign-currency-denominated transactions.
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The following table provides the carrying value of each category of financial assets and liabilities and the related balance sheet item:
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Financial assets: | ||||||||
Financial assets measured at fair value: | ||||||||
Derivative instruments designated as cash flow hedges 1 | $ | $ | ||||||
Fair value of Egypt gas supply contract derivative 2 | ||||||||
Fair value of New Zealand gas supply contract derivative 3 | ||||||||
Financial assets not measured at fair value: | ||||||||
Cash and cash equivalents | ||||||||
Trade and other receivables, excluding tax receivable | ||||||||
Restricted cash included in other assets | ||||||||
Total financial assets 4 | $ | $ | ||||||
Financial liabilities: | ||||||||
Financial liabilities measured at fair value: | ||||||||
Derivative instruments designated as cash flow hedges 1 | $ | $ | ||||||
Financial liabilities not measured at fair value: | ||||||||
Trade, other payables and accrued liabilities, excluding tax payable | ||||||||
| Lease obligations, including current portion | ||||||||
Long-term debt, including current portion | ||||||||
| Land mortgage | ||||||||
Total financial liabilities | $ | $ | ||||||
1 The Geismar natural gas hedges and euro foreign currency hedges designated as cash flow hedges are measured at fair value based on industry accepted valuation models and inputs obtained from active markets.
2 The Egypt natural gas supply contract is measured at fair value using a Monte-Carlo model classified within Level 3 of the fair value hierarchy.
3 The New Zealand natural gas supply contract is measured at fair value using an economic model classified within Level 3 of the fair value hierarchy.
As at December 31, 2024, all of the financial instruments were recorded on the consolidated statements of financial position at amortized cost with the exception of derivative financial instruments, which were recorded at fair value unless exempted.
The fair value of derivative instruments is determined based on industry-accepted valuation models using market observable inputs and are classified within Level 2 of the fair value hierarchy and those using significant unobservable inputs classified as Level 3. The fair value of all of the Company's derivative contracts as presented in the consolidated statements of financial position are determined based on present values and the discount rates used are adjusted for credit risk. The effective portion of the changes in fair value of derivative financial instruments designated as cash flow hedges is recorded in other comprehensive income. The spot element of forward contracts in the hedging relationships is recorded in other comprehensive income as the change in fair value of cash flow hedges. The change in the fair value of the forward element of forward contracts is recorded in other comprehensive income as the forward element excluded from the hedging relationships. Once a commodity hedge settles, the amount realized during the period and not recognized immediately in the statement of income is reclassified from accumulated other comprehensive income (equity) to inventory and ultimately through cost of goods sold. Foreign currency hedges settled, are realized during the period directly to the statement of income reclassified from the statement of other comprehensive income.
Until settled, the fair value of Level 2 derivative financial instruments will fluctuate based on changes in commodity prices or foreign currency exchange rates and the fair value of Level 3 derivative financial instruments will fluctuate based on changes in the observable and unobservable valuation model inputs.
North American natural gas forward contracts
The Company manages its exposure to changes in natural gas prices for a portion of its North American natural gas requirements by executing a number of fixed price forward contracts: both financial and physical.
The Company has entered into forward contracts designated as cash flow hedges to manage its exposure to changes in natural gas prices for Geismar. Natural gas is fungible across the Geismar plants. Other costs incurred to transport natural gas from the contracted delivery point, Henry Hub, to the relevant production facility represent an insignificant portion of the overall underlying risk and are recognized as incurred outside of the hedging relationship. During the year ended December 31, 2024, the Company reclassified $11.7 million (2023 - nil ) from other comprehensive income to cost of sales and operating expenses within the statement of income on discontinuation of the hedging relationship for certain gas forward contracts where the hedged future cash flows were no longer highly probable to occur.
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| As at | Dec 31 2024 | Dec 31 2023 | ||||||
| Maturities | 2025-2032 | 2024-2032 | ||||||
Notional quantity 1 | ||||||||
Notional quantity per day, annualized 1 | ||||||||
| Notional amount | $ | $ | ||||||
| Net fair value | $ | $ | ||||||
1 In thousands of Million British Thermal Units (MMBtu)
Information regarding the gross amounts of the Company's natural gas forward contracts designated as cash flow hedges in the audited consolidated statements of financial position is as follows:
| As at | Dec 31 2024 | Dec 31 2023 | ||||||
| Other current assets | $ | $ | ||||||
| Other non-current assets | ||||||||
| Other current liabilities | ( | ( | ||||||
| Other long-term liabilities | ( | ( | ||||||
| Net fair value | $ | $ | ||||||
For the year ended December 31, 2024, the Company reclassified a loss of $76.0 million (2023 - loss of $22.5 million) for natural gas hedge settlements from accumulated other comprehensive income. Realized gains and losses related to settlements of natural gas hedges are presented separately within the Consolidated Statement of Changes in Equity.
Euro forward exchange contracts
The Company manages its foreign currency exposure to euro denominated sales by executing a number of forward contracts which it has designated as cash flow hedges for its highly probable forecast euro collections. The Company has elected to designate the spot element of the forward contracts as cash flow hedges. The forward element of the forward contracts are excluded from the designation and only the spot element is considered for the purpose of assessing effectiveness and measuring ineffectiveness. The excluded forward element of the swap contracts will be accounted for as a cost of hedging (transaction cost) to be recognized in profit or loss over the term of the hedging relationships. Ineffectiveness may arise in the hedging relationship due to changes in the timing of the anticipated transactions and/or due to changes in credit risk of the hedging instrument not replicated in the hedged item. No
As at December 31, 2024, the Company had outstanding forward exchange contracts designated as cash flow hedges to sell a notional amount of 29.7 million euros (2023 - 12.2 million euros). The euro contracts had a positive fair value of $2.0 million included in Other current assets (2023 - negative fair value of $0.5 million included in Other current liabilities).
For the year ended December 31, 2024, the Company reclassified a gain of $3.6 million (2023 - loss of $3.1 million) for foreign currency hedge settlements from other comprehensive income.
Changes in cash flow hedges and excluded forward element
Information regarding the impact of changes in cash flow hedges and cost of hedging reserve in the consolidated statement of comprehensive income is as follows:
| For the years ended December 31 | 2024 | 2023 | ||||||
| Change in fair value of cash flow hedges | $ | $ | ( | |||||
| Forward element excluded from hedging relationships | ( | ( | ||||||
| $ | ( | $ | ( | |||||
Fair value - Level 2 instruments
The table below shows the nominal cash outflows for derivative hedging instruments including natural gas forward contracts and forward exchange contracts, excluding credit risk adjustments, based upon contracted settlement dates. The amounts reflect the maturity profile of the hedging instruments and are subject to change based on the prevailing market rate at each of the future settlement dates. Financial asset derivative positions, if any, are held with investment-grade counterparties and therefore the settlement day risk exposure is considered to be negligible.
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As at | Dec 31 2024 | Dec 31 2023 | ||||||
Within one year | $ | $ | ||||||
1-3 years | ||||||||
3-5 years | ||||||||
More than 5 years | ||||||||
| $ | $ | |||||||
The fair value of the Company’s derivative financial instruments as disclosed above are determined based on Bloomberg quoted market prices, which are adjusted for credit risk.
The Company is exposed to credit-related losses in the event of non-performance by counterparties to derivative financial instruments but does not expect any counterparties to fail to meet their obligations. The Company deals with only highly rated investment-grade counterparties. The Company is exposed to credit risk when there is a positive fair value of derivative financial instruments at a reporting date. The maximum amount that would be at risk if the counterparties to derivative financial instruments with positive fair values failed completely to perform under the contracts was $128.4 million as at December 31, 2024 (2023 - $121.1 million).
The carrying values of the Company’s financial instruments approximate their fair values, except as follows:
As at | December 31, 2024 | December 31, 2023 | ||||||||||||
Carrying value | Fair value | Carrying value | Fair value | |||||||||||
Long-term debt excluding deferred financing fees | $ | $ | $ | $ | ||||||||||
Long-term debt consists of limited recourse debt facilities and unsecured notes. There is no publicly traded market for the limited recourse debt facilities. The fair value of the limited recourse debt facilities as disclosed on a recurring basis and categorized as Level 2 within the fair value hierarchy is estimated by reference to current market rates as at the reporting date. The fair value of the unsecured notes disclosed on a recurring basis and also categorized as Level 2 within the fair value hierarchy is estimated using quoted prices and yields as at the reporting date. The fair value of the Company’s long term debt will fluctuate until maturity.
Fair value - Level 3 instrument - Egyptian natural gas supply contract
The Company holds a long-term natural gas supply contract expiring in 2035 with the Egyptian Natural Gas Holding Company ("EGAS"), a State-Owned enterprise in Egypt. The natural gas supply contract includes a base fixed price plus a premium based on the realized price of methanol for the full volume of natural gas to supply the plant through 2035. As a result of the amendment in 2022, the contract is being treated as a derivative measured at fair value.
There is no observable, liquid spot market or forward curve for natural gas in Egypt. In addition, there are limited observable prices for natural gas in Egypt as all natural gas purchases and sales are controlled by the government and the observed prices differ based on the produced output or usage.
Due to the absence of an observable market price for an equivalent or similar contract to measure fair value, the contract's fair value is estimated using a Monte-Carlo model. The Monte-Carlo model includes significant unobservable inputs and as a result is classified within Level 3 of the fair value hierarchy. We consider market participant assumptions in establishing the model inputs and determining fair value, including adjusting the base fixed price and methanol based premium at the valuation date to consider estimates of inflation since contract inception.
At December 31, 2024 the fair value of the derivative associated with the remaining term of the natural gas supply contract is $14.3 million (2023 - $20.4 million) recorded in Other assets. Changes in fair value of the contract are recognized in Finance income and other expenses.
The table presents the Level 3 inputs and the sensitivities of the Monte-Carlo model valuation to changes in these inputs:
| Sensitivities | |||||||||||
| Valuation input | Input value or range | Change in input | Resulting change in valuation | ||||||||
| Methanol price volatility (before impact of mean reversion) | +/- | $+/- | |||||||||
| Methanol price forecast | $ | +/- $ | $- | ||||||||
| Discount rate | +/- | $+/- | |||||||||
It is possible that the assumptions used in establishing fair value amounts will differ from future outcomes and the impact of such variations could be material.
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Fair value - Level 3 instrument - New Zealand natural gas supply contract
The Company holds a long-term natural gas supply contract expiring in 2029 with OMV New Zealand ("OMV"), one of the largest gas suppliers in New Zealand. The natural gas supply contract includes a base fixed price plus a premium based on the realized price of methanol.
During 2024, the Company entered into short-term commercial arrangements to provide its contracted natural gas into the New Zealand electricity market (Refer to note 25 - New Zealand gas sale proceeds). The on-sale of natural gas has impacted the accounting assessment for the contract whereby it is now considered a derivative to be measured at fair value.
The New Zealand wholesale gas market is relatively small and concentrated as there are a limited number of suppliers and consumers. There is a limited observable, liquid spot market and no forward curve for natural gas in New Zealand. The gas trading platform used to facilitate short-term balance in the gas market trades inconsequential volumes relative to the scope of the Company’s gas consumption and the overall gas market. The Company does not believe transactions on this platform take place with sufficient frequency and volume to provide pricing information.
Due to the absence of an observable market price for an equivalent or similar contract to measure fair value, we have estimated fair value using an economic model. The model includes significant unobservable inputs and as a result is classified within Level 3 of the fair value hierarchy. We have considered market participant assumptions in establishing the model inputs and determining fair value, including potential sharing mechanisms for gas on-sales to consider the change in the local market gas supply and demand dynamics since contract inception.
At December 31, 2024 the fair value associated with the remaining term of the natural gas supply contract including consideration of on-sales is $8.7 million recorded in Other non-current assets. Changes in fair value of the contract are recognized in Finance income and other expenses.
The table presents the Level 3 inputs and the sensitivities of the economic model valuation to changes in these inputs:
| Sensitivities | |||||||||||
| Valuation input | Input value or range | Change in input | Resulting change in valuation | ||||||||
| New Zealand forward electricity pricing | $ | +/- $ | $-/+ | ||||||||
| Methanol price forecast | $ | +/- $ | $-/+ | ||||||||
Natural gas availability | Annual estimates based on third party forecasts | +/- | $+/- | ||||||||
20. Financial risk management:
a) Market risks:
The Company’s operations consist of the production and sale of methanol. Market fluctuations may result in significant cash flow and profit volatility risk for the Company. Its worldwide operating business as well as its investment and financing activities are affected by changes in methanol and natural gas prices and interest and foreign exchange rates. The Company seeks to manage and control these risks primarily through its regular operating and financing activities and uses derivative instruments to hedge these risks when deemed appropriate. This is not an exhaustive list of all risks, nor will the risk management strategies eliminate these risks.
Methanol price risk
The methanol industry is a highly competitive commodity industry and methanol prices fluctuate based on supply and demand fundamentals and other factors. The profitability of the Company is directly related to the market price of methanol. A decline in the market price of methanol could negatively impact the Company's future operations. The Company does not hedge its methanol sales through derivative contracts. The Company manages its methanol price risk, to a certain degree, through natural gas supply contracts that include a variable price component linked to methanol prices, as described below.
Natural gas price risk
Natural gas is the primary feedstock for the production of methanol. The Company has entered into multi-year natural gas supply contracts for its production facilities in New Zealand, Trinidad and Tobago, Egypt and certain contracts in Chile that include base and variable price components to reduce the commodity price risk exposure. The variable price component is adjusted by formulas related to methanol prices above a certain level. The Company also has multi-year fixed price natural gas contracts to supply its production facilities in Geismar, Medicine Hat and Chile and natural gas financial hedges in Geismar to manage its exposure to natural gas price risk.
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Interest rate risk
Interest rate risk is the risk that the Company suffers financial loss due to changes in the value of an asset or liability or in the value of future cash flows due to movements in interest rates. The Company’s interest rate risk exposure is mainly related to the undrawn credit facility.
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Fixed interest rate debt: | ||||||||
Unsecured notes | $ | $ | ||||||
Other limited recourse debt facilities | ||||||||
| $ | $ | |||||||
For fixed interest rate debt, a 1 % change in interest rates would result in a change in the fair value of the debt (disclosed in note 19) of approximately $119.6 million as of December 31, 2024 (2023 - $100.5 million).
Foreign currency risk
The Company’s international operations expose the Company to foreign currency exchange risks in the ordinary course of business. Accordingly, the Company has established a policy that provides a framework for foreign currency management and hedging strategies and defines the approved hedging instruments. The Company reviews all significant exposures to foreign currencies arising from operating and investing activities and hedges exposures if deemed appropriate.
The dominant currency in which the Company conducts business is the United States dollar, which is also the reporting currency.
Methanol is a global commodity chemical that is priced in United States dollars. In certain jurisdictions, however, the transaction price is set either quarterly or monthly in the local currency. Accordingly, a portion of the Company’s revenue is transacted in Chinese yuan, euros, and, to a lesser extent, other currencies. For the period from when the price is set in local currency to when the amount due is collected, the Company is exposed to declines in the value of these currencies compared to the United States dollar. The Company also purchases varying quantities of methanol for which the transaction currency is the euro, Chinese yuan and, to a lesser extent, other currencies. In addition, some of the Company’s underlying operating costs and capital expenditures are incurred in other currencies. The Company is exposed to increases in the value of these currencies that could have the effect of increasing the United States dollar equivalent of cost of sales and operating expenses and capital expenditures. The Company has elected not to actively manage these exposures at this time except for a portion of the net exposure to euro revenues, which is hedged through forward exchange contracts each quarter when the euro price for methanol is established.
As at December 31, 2024, the Company had a net working capital asset of $152.7 million in non U.S. dollar currencies (2023 - $74.4 million). Each 10 % strengthening of the U.S. dollar against these currencies would decrease the value of net working capital and pre-tax cash flows and earnings by approximately $13.9 million (2023 - $6.8 million). Each 10 % weakening of the U.S. dollar against these currencies would increase the value of net working capital and pre-tax cash flows and earnings by approximately $17.0 million (2023 - $8.3 million).
b) Liquidity risks:
Liquidity risk is the risk that the Company will not have sufficient funds to meet its liabilities, such as the settlement of financial debt and lease obligations and payment to its suppliers. The Company maintains liquidity and makes adjustments to it in light of changes to economic conditions, underlying risks inherent in its operations and capital requirements to maintain and grow its operations. As at December 31, 2024, the Company had a strong liquidity position including a cash and cash equivalents balance of $892 million. In addition, the Company has access to a $500 million committed undrawn revolving credit facility.
In addition to the above-mentioned sources of liquidity, the Company monitors funding options available in the capital markets, as well as trends in the availability and costs of such funding, with a view to maintaining financial flexibility and limiting refinancing risks.
The expected cash flows of financial liabilities from the date of the balance sheet to the contractual maturity date are as follows:
| As at December 31, 2024 | Carrying amount | Contractual cash flows | 1 year or less | 1-3 years | 3-5 years | More than 5 years | |||||||||||||||||
Trade and other payables 1 | $ | $ | $ | $ | $ | $ | |||||||||||||||||
Lease obligations 2 | |||||||||||||||||||||||
Other long-term liabilities2 | |||||||||||||||||||||||
Long-term debt 2 | |||||||||||||||||||||||
Cash flow hedges 3 | |||||||||||||||||||||||
| $ | $ | $ | $ | $ | $ | ||||||||||||||||||
1 Excludes tax, accrued interest and euro foreign currency hedges.
2 Contractual cash flows include contractual interest payments related to debt obligations and lease obligations.
78
c) Credit risks:
Counterparty credit risk is the risk that the financial benefits of contracts with a specific counterparty will be lost if a counterparty defaults on its obligations under the contract. This includes any cash amounts owed to the Company by those counterparties, less any amounts owed to the counterparty by the Company where a legal right of offset exists and also includes the fair values of contracts with individual counterparties that are recorded in the financial statements.
Trade credit risk
Trade credit risk is defined as an unexpected loss in cash and earnings if the customer is unable to pay its obligations in due time or if the value of the security provided declines. The Company has implemented a credit policy that includes approvals for new customers, annual credit evaluations of all customers and specific approval for any exposures beyond approved limits. The Company employs a variety of risk-mitigation alternatives, including credit insurance, certain contractual rights in the event of deterioration in customer credit quality and various forms of bank and parent company guarantees and letters of credit to upgrade the credit risk to a credit rating equivalent or better than the stand-alone rating of the counterparty. Trade credit losses have historically been minimal and as at December 31, 2024 substantially all of the trade receivables were classified as current.
Cash and cash equivalents
To manage credit and liquidity risk, the Company’s investment policy specifies eligible types of investments, maximum counterparty exposure and minimum credit ratings. Therefore, the Company invests only in highly rated investment-grade instruments that have maturities of three months or less.
Derivative financial instruments
The Company’s hedging policies specify risk management objectives and strategies for undertaking hedge transactions. The policies also include eligible types of derivatives and required transaction approvals, as well as maximum counterparty exposures and minimum credit ratings. The Company does not use derivative financial instruments for trading or speculative purposes.
To manage credit risk, the Company only enters into derivative financial instruments with highly rated investment-grade counterparties. Hedge transactions are reviewed, approved and appropriately documented in accordance with Company policies.
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21. Retirement plans:
a) Defined benefit pension plans:
The Company has non-contributory defined benefit pension plans covering certain employees. The Company does not provide any significant post-retirement benefits other than pension plan benefits. Information concerning the Company’s defined benefit pension plans, in aggregate, is as follows:
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Accrued benefit obligations: | ||||||||
Balance, beginning of year | $ | $ | ||||||
Current service cost | ||||||||
Past service cost | ||||||||
Interest cost on accrued benefit obligations | ||||||||
Benefit payments | ( | ( | ||||||
Settlements | ( | ( | ||||||
Actuarial (gain) loss | ( | |||||||
Foreign exchange (gain) loss | ( | |||||||
Balance, end of year | ||||||||
Fair values of plan assets: | ||||||||
Balance, beginning of year | ||||||||
Interest income on assets | ||||||||
Contributions | ||||||||
Benefit payments | ( | ( | ||||||
Settlements | ( | ( | ||||||
Return on plan assets | ( | |||||||
Foreign exchange gain (loss) | ( | |||||||
Balance, end of year | ||||||||
Unfunded status | ||||||||
Minimum funding requirement | ||||||||
Defined benefit obligation, net | $ | $ | ||||||
The net defined benefit obligation above is comprised of unfunded retirement obligations and funded retirement net assets from defined benefit pension plans, as follows:
The Company has an unfunded retirement obligation of $19.2 million as at December 31, 2024 (2023 - obligation of $20.2 million) for its employees in Chile that will be funded in accordance with Chilean law. The Company also has an unfunded retirement obligation of $1.2 million as at December 31, 2024 (2023 - $2.5 million) for its employees in Egypt. The accrued benefits for the unfunded retirement arrangement in Chile and Egypt are paid when an employee leaves the Company in accordance with the plan terms and country regulations.The Company estimates that it may make benefit payments based on actuarial assumptions related to the unfunded retirement obligation of $11.0 million in Chile and $0.1 million in Egypt for 2025. Actual benefit payments in future periods will fluctuate based on employee retirements.
The Company has a net funded retirement asset of $3.7 million as at December 31, 2024 (2023 - $5.3 million) for certain employees and retirees in Canada and a net funded retirement asset of $0.1 million as at December 31, 2024 (2023 - asset of $0.4 million) in Europe. The Company estimates that it will make no additional contributions relating to its defined benefit pension plan in Canada and that it will make additional contributions relating to its defined benefit pension plan in Europe of $0.5 million in 2025.
These defined benefit plans expose the Company to actuarial risks, such as longevity risk, currency risk, interest rate risk and market risk on the funded plans. Additionally, as the plans provide benefits to plan members predominantly in Canada, Chile and Egypt, the plans expose the Company to foreign currency risk for funding requirements. The primary long-term risk is that the Company will not have sufficient plan assets and liquidity to meet obligations when they fall due. The weighted average duration of the net defined benefit obligation is 6 years.
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The Company’s net defined benefit pension plan expense charged to the consolidated statements of income for the years ended December 31, 2024 and 2023 is as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Net defined benefit pension plan expense: | ||||||||
Current service cost | $ | $ | ||||||
Past service cost | ||||||||
Net interest cost | ||||||||
Cost of settlement | ( | |||||||
| Total net defined benefit pension plan expense | $ | $ | ||||||
The Company’s current year actuarial gain (loss), recognized in the consolidated statements of comprehensive income for the years ended December 31, 2024 and 2023, are as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Actuarial gain (loss) | $ | $ | ( | |||||
The Company had no
The Company uses a December 31 measurement date for its defined benefit pension plans. Actuarial reports for the Company’s defined benefit pension plans were prepared by independent actuaries for funding purposes as of December 31, 2022 in Canada. The next actuarial reports for funding purposes for the Company’s Canadian defined benefit pension plans are scheduled to be completed as of December 31, 2025.
The discount rate is the most significant actuarial assumption used in accounting for the defined benefit pension plans. As at December 31, 2024, the weighted average discount rate for the defined benefit obligation was 5.2 % (2023 - 5.3 %). A change of 1 2.3 million.
The asset allocation for the defined benefit pension plan assets as at December 31, 2024 and 2023 is as follows:
As at | Dec 31 2024 | Dec 31 2023 | ||||||
Equity securities | ||||||||
Debt securities | ||||||||
Cash and other short-term securities | ||||||||
Total | ||||||||
The fair value of the above equity and debt instruments are determined based on quoted market prices in active markets whereas the fair value of cash and other short-term securities are not based on quoted market prices in active markets. The plan assets are held separately from those of the Company in funds under the control of trustees.
b) Defined contribution pension plans:
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22. Commitments and contingencies:
a) Take-or-pay purchase contracts and related commitments:
The Company has commitments under take-or-pay contracts to purchase natural gas, to pay for transportation capacity related to the delivery of natural gas and to purchase oxygen and other feedstock requirements for our operating plants up to 2044. The minimum estimated commitment under these contracts, except as noted below, is as follows:
As at December 31, 2024
| 2025 | 2026 | 2027 | 2028 | 2029 | Thereafter | ||||||||||||
| $ | $ | $ | $ | $ | $ | ||||||||||||
Take-or-pay means that we are obliged to pay for the supplies regardless of whether we take delivery. Such commitments are common in the methanol industry. These contracts generally provide a quantity that is subject to take-or-pay terms that is lower than the maximum quantity that we are entitled to purchase. The amounts disclosed in the table above represent only the minimum take-or-pay quantity.
The natural gas supply contracts for our facilities in New Zealand, Trinidad and Tobago, Egypt and Chile are take-or-pay contracts denominated in United States dollars and include base and variable price components to manage our commodity price risk exposure. The variable price component of each natural gas contract is adjusted by a formula linked to methanol prices. We believe this pricing relationship enables these facilities to be competitive throughout the methanol price cycle. The amounts disclosed in the table for these contracts represent only the base price component representative of the minimum take-or-pay commitment.
b) Other commitments:
The Company has future minimum payments relating primarily to short-term vessel charters, terminal facilities, and other commitments that are not leases, as follows:
As at December 31, 2024
| 2025 | 2026 | 2027 | 2028 | 2029 | Thereafter | ||||||||||||
| $ | $ | $ | $ | $ | $ | ||||||||||||
Refer to note 9 for a summary of lease commitments.
c) Purchased methanol:
The Company has marketing rights for 100 % of the production from its jointly owned plant in Egypt (in which it has a 50 % interest). This results in purchase commitments of an additional 0.6 million tonnes per year of methanol offtake supply when Egypt operates at capacity. As at December 31, 2024, the Company also had commitments to purchase methanol from other suppliers for approximately 0.8 million tonnes for 2025 and 0.4 million tonnes in aggregate thereafter. The pricing under these purchase commitments is referenced to pricing at the time of purchase or sale, and accordingly, no amounts have been included in the table above.
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23. Related parties:
The Company has interests in significant subsidiaries and joint ventures as follows:
Name | Country of incorporation | Principal activities | Interest % | |||||||||||
| Dec 31 2024 | Dec 31 2023 | |||||||||||||
Significant subsidiaries: | ||||||||||||||
Methanex Asia Pacific Limited | Hong Kong | Marketing & distribution | ||||||||||||
Methanex Services (Shanghai) Co., Ltd. | China | Marketing & distribution | ||||||||||||
Methanex Europe NV | Belgium | Marketing & distribution | ||||||||||||
Methanex Methanol Company, LLC | United States | Marketing & distribution | ||||||||||||
Egyptian Methanex Methanol Company S.A.E. ("Methanex Egypt") | Egypt | Production | ||||||||||||
Methanex Chile SpA | Chile | Production | ||||||||||||
Methanex New Zealand Limited | New Zealand | Production | ||||||||||||
Methanex Trinidad (Titan) Unlimited | Trinidad and Tobago | Production | ||||||||||||
Methanex USA LLC | United States | Production | ||||||||||||
Methanex Louisiana LLC | United States | Production | ||||||||||||
Methanex Geismar III LLC | United States | Production | ||||||||||||
Waterfront Shipping Limited 1 | Canada | Shipping | ||||||||||||
Significant joint ventures: | ||||||||||||||
Atlas Methanol Company Unlimited 2 | Trinidad and Tobago | Production | ||||||||||||
1 Waterfront Shipping Limited has a controlling interest in multiple ocean-going vessels owned through less than wholly-owned entities as disclosed in note 24.
2 Summarized financial information for the investment in Atlas is disclosed in note 6.
Transactions between the Company and Atlas are considered related party transactions and are included within the summarized financial information in note 6. Atlas revenue for the year ended December 31, 2024 of $312 million (2023 - $466 million) is a related party transaction included in cost of sales of the Company as Methanex had marketing rights for 100 % of the methanol produced by Atlas. Balances outstanding with Atlas as at December 31, 2024 and provided in the summarized financial information in note 6 include receivables owing from Atlas to the Company of nil (2023 - $74 million) and payables to Atlas of $7 million (2023 - $172 million). As at December 31, 2024, Atlas has repaid its total loans outstanding to the Company and the balance is now nil (2023 - $76 million).
Remuneration to non-management directors and senior management, which includes the members of the executive leadership team, is as follows:
For the years ended December 31 | 2024 | 2023 | ||||||
Short-term employee benefits | $ | $ | ||||||
Post-employment benefits | ||||||||
Other long-term employee benefits | ||||||||
Share-based compensation expense 1 | ||||||||
Total | $ | $ | ||||||
1 Balance includes realized and unrealized expenses and recoveries from share-based compensation awards granted.
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24. Non-controlling interests:
Set out below is summarized financial information for each of our subsidiaries that have non-controlling interests. The amounts disclosed are before inter-company eliminations.
As at | Dec 31, 2024 | Dec 31, 2023 | |||||||||||||||||||||
| Methanex Egypt | Waterfront Shipping Limited | Total | Methanex Egypt | Waterfront Shipping Limited | Total | ||||||||||||||||||
Current assets | $ | $ | $ | $ | $ | $ | |||||||||||||||||
Non-current assets | |||||||||||||||||||||||
Current liabilities | ( | ( | ( | ( | ( | ( | |||||||||||||||||
Non-current liabilities | ( | ( | ( | ( | ( | ( | |||||||||||||||||
Net assets | |||||||||||||||||||||||
Carrying amount of Methanex non-controlling interests | $ | $ | $ | $ | $ | $ | |||||||||||||||||
For the years ended December 31 | 2024 | 2023 | |||||||||||||||||||||
| Methanex Egypt | Waterfront Shipping Limited | Total | Methanex Egypt | Waterfront Shipping Limited | Total | ||||||||||||||||||
Revenue | $ | $ | $ | $ | $ | $ | |||||||||||||||||
Net and total comprehensive income | |||||||||||||||||||||||
Net and total comprehensive income attributable to Methanex non-controlling interests | |||||||||||||||||||||||
Distributions made and accrued to non-controlling interests | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||
For the years ended December 31 | 2024 | 2023 | |||||||||||||||||||||
| Methanex Egypt | Waterfront Shipping Limited | Total | Methanex Egypt | Waterfront Shipping Limited | Total | ||||||||||||||||||
Cash flows from operating activities | $ | $ | $ | $ | $ | $ | |||||||||||||||||
Cash flows used in financing activities | ( | ( | ( | ( | ( | ( | |||||||||||||||||
Cash flows from (used in) investing activities | $ | ( | $ | ( | $ | ( | $ | ( | $ | $ | ( | ||||||||||||
25. New Zealand gas sale proceeds:
During 2024, the Company entered into short-term commercial arrangements to provide the natural gas available to the Company into the New Zealand electricity market. As a result, the Company has recognized $103 million of net proceeds in the year ended December 31, 2024 relating to gas provided. This does not include fixed costs, the impact of lost margin on the sale of methanol that was not produced in the period and additional supply chain costs incurred.
26. Egypt insurance recovery:
We experienced an outage at the Egypt plant from October 2023 to February 2024. For the year ended December 31, 2024, we have recorded a $59 million ($30 million - attributable to Methanex) insurance recovery which partially offsets repair costs charged to earnings and lost margins incurred in the fourth quarter of 2023 and first quarter of 2024.
27. Agreement to acquire OCI Global's methanol business:
On September 8, 2024, Methanex entered into a definitive agreement to acquire OCI Global’s international methanol business, subject to certain conditions and approvals. Excluding the impact of cash, debt, and working capital adjustments, and including the assumption of a share of non-recourse debt, consideration for the OCI Acquisition will consist of $1.18 billion in cash and the issuance of 9.9 million common shares of Methanex Corporation.
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