MethanexCorporation is the world’s largest producer and supplier of methanol to TABLE OF CONTENTS major international markets in North America, Asia Pacific, 2 3 2017 Financial Highlights President’s Message to Shareholders 5 Chairman’s Message to Shareholders 6 Management’s Discussion and Analysis 42 Consolidated Financial Statements 51 Notes to Consolidated Financial Statements Europe and South America. Our production sites are located in New Zealand, the United States, Trinidad, Egypt, Canada and Chile. Our primary objective is to create value by maintaining and enhancing our leadership in the global production, marketing and delivery of methanol to customers. Methanol is a clear, biodegradable liquid commodity chemical that is a key ingredient in a variety of chemical derivatives, and serves as a building block to produce a multitude of everyday consumer and industrial items. Methanol is also used in an increasing number of energy- related applications and is an innovative, clean-burning alternative fuel. Methanex – Global Methanol Industry Leader …………………………………………………………………………………………………………………………………………………………………………………………………………………………… EUROPE Brussels Damietta MIDDLE EAST Dubai Cairo AFRICA ASIA Beijing Seoul Shanghai Tokyo Hong Kong Vancouver Medicine Hat NORTH AMERICA Dallas Geismar Trinidad SOUTH AMERICA Santiago Punta Arenas Auckland New Plymouth Production Sites Global Office Locations Distribution Terminals and Storage Facilities Shipping Lanes Global Production Facilities Methanex’s global production sites are strategically positioned to supply every major global market. New Zealand Our three plants in New Zealand supply methanol primarily to customers in Asia Pacific. United States Our two plants in Geismar have the capability to serve customers in all major markets around the globe. Trinidad Our two plants in Trinidad, Titan and Atlas (Methanex interest 63.1%), supply all major methanol markets around the globe. Egypt Our joint venture in Egypt (Methanex interest 50%) is located on the Mediterranean Sea and primarily supplies methanol to the European market, but can also supply Asia. Canada Our plant in Medicine Hat, Alberta, supplies methanol to customers in North America. Chile Our production site in Punta Arenas, Chile supplies methanol to customers in South America. We have two plants at the site, but one plant is idled due to insufficient gas availability. We are continuing to work with gas suppliers to sustain our Chile operations into the future. Global Supply Chain Methanex has an extensive global supply chain and distribution network of terminals and storage facilities throughout Asia Pacific, North America, Europe and South America. Methanex’s wholly-owned subsidiary, Waterfront Shipping, operates the largest methanol ocean tanker fleet in the world. The fleet forms a seamless transportation network dedicated to keeping an uninterrupted flow of methanol moving to storage terminals and customers’ plant sites around the world. For further information on Waterfront Shipping, please visit www.wfs-cl.com. Our Responsible Care Commitment Methanex is a Responsible Care company. Responsible Care is the umbrella under which Methanex and other leading chemical manufacturers manage issues relating to health, safety, the environment, community involvement, social responsibility, security and emergency preparedness. The total commitment to Responsible Care is an integral part of Methanex’s global corporate culture. 2017 Methanex Corporation Annual Report 1 2017 Financial Highlights (U.S.$ millions, except where noted) Operations Revenue Adjusted net income (loss)1 Net income (loss) (attributable to Methanex shareholders) Adjusted EBITDA1 Cash flows from operating activities Modified Return on Capital Employed (ROCE)2 Diluted Per Share Amounts (U.S.$ per common share) Adjusted net income (loss)1 Net income (loss) (attributable to Methanex shareholders) Financial Position Cash and cash equivalents Total assets Long-term debt, including current portion Net debt to capitalization3 Net debt to market capitalization4 Other Information Average realized price (U.S.$ per tonne)5 Total sales volume (000s tonnes) Sales of Methanex-produced methanol (000s tonnes) Total production (000s tonnes) 2017 3,061 409 316 838 788 12.9% 4.71 3.64 375 4,611 1,502 39% 20% 337 10,669 7,229 7,187 2016 2015 2014 2013 1,998 2,226 3,223 3,024 (15) (13) 287 227 110 201 401 297 397 455 702 801 471 329 736 586 0.4% 6.2% 16.2% 23.0% (0.17) (0.14) 224 4,557 1,556 42% 30% 242 9,478 6,828 7,017 1.20 2.01 255 4,556 1,536 39% 22% 322 8,471 5,050 5,193 4.12 4.55 952 4,775 1,722 27% 10% 437 8,504 4,878 4,853 4.88 3.41 733 4,121 1,168 19% 8% 441 7,991 4,304 4,344 Adjusted EBITDA (U.S.$ million) Production (thousands of tonnes) 6 3 7 2 0 7 8 3 8 7 2 4 9 2 4 0 3 3 1 9 2 2 4 1 1 0 4 7 8 2 3 6 6 3 , 3 4 5 3 , 0 4 5 3 , 7 4 8 3 , 1 7 0 4 , 4 4 3 4 , 7 1 0 7 , 7 8 1 7 , 3 5 8 4 , 3 9 1 5 , 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 Dividends and Shares Outstanding Share Price Performance (Indexed at December 31) 100 95 92 Regular Dividends per Share ($U.S./share) Outstanding Common Shares at December 31 (millions of shares) 8 0 1 . 0 1 1 . 5 9 0 . 1 6 0 . 2 6 0 . 2 6 0 . 7 6 0 . 9 7 0 . 3 7 0 . Methanex (U.S.$, NASDAQ) S&P 500 Chemicals Index 8 1 1 . 84 600 500 400 300 200 100 90 85 80 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2008 2009 2010 2011 2012 2013 2014 2015 2016 0 2017 1 The Company has used the terms Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share, Adjusted revenue, and Operating income throughout this document. These items are non-GAAP measures 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 Supplemental Non-GAAP Measures section on page 36 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures. 2 Modified ROCE is defined as adjusted net income (loss) before finance costs (after-tax) divided by average productive capital employed. Average productive capital employed is the sum of average total assets (excluding plants under construction) less the average of current non-interest bearing liabilities. Average total assets excludes cash held in excess of $50 million. We use an estimated mid-life depreciated cost base for calculating our average assets in use during the period. The calculation of Modified ROCE includes our share of income, assets and liabilities in the Egypt and Atlas methanol facilities. 3 Defined as total debt less cash and cash equivalents divided by the sum of total equity and total debt less cash and cash equivalents (including 100% of debt related to the Egypt methanol facility). 4 Defined as total debt less cash and cash equivalents divided by the sum of the weighted average market capitalization for the year and total debt (including 100% of debt related to the Egypt methanol facility). 5 Average realized price is calculated as revenue, excluding commissions earned and the Egypt non-controlling interest share of revenue, but including an amount representing our share of Atlas revenue, divided by the total sales volume of Methanex-produced and purchased methanol, but excluding any volume produced in Chile using natural gas supplied from Argentina under a tolling arrangement. 2 2017 Methanex Corporation Annual Report President’s Message to Shareholders DEAR FELLOW SHAREHOLDERS, 2017 was a milestone year for Methanex. We celebrated our Responsible Care is integral to Methanex’s culture and we 25th anniversary and achieved outstanding operational continue to undertake initiatives to advance health and safety, performance and financial results. We had record production environmental stewardship, product safety and social and sales volume, recorded the highest adjusted EBITDA in responsibility across all facets of our operations and supply Methanex’s history and posted adjusted net income of $4.71 chain. In 2017, we have focused on continuous improvement per share. These results reflect the investments we’ve made and have taken preventative measures to improve job planning over the past few years to increase our production capability through greater focus on the identification and mitigation of and substantially improve our earnings power, demonstrating related hazards. We also advanced work on our process safety our ability to generate significant cash flow across a broad management program that focuses on safely operating our range of methanol prices. Our shareholders benefited from our long track record of returning excess cash through regular dividends, as well as our repurchase of 6.2 million common shares in 2017, representing 10% of the public float. It was a year of remarkable plants. Our environmental performance remains steady and we are focused on continually reducing our environmental impact. We will continue to work on improving our global Responsible Care performance and reliability, with the ultimate goal of zero incidents. performance that confirmed our leadership position in the Our overall plant reliability in 2017 was 93% compared to our methanol industry. Looking back at 2017: Record production and growing demand for methanol target of 97%. Reliability was impacted as a result of minor repairs at some of our plants during planned or unplanned maintenance activities to improve their long-term operating rates. We are seeking to improve plant reliability and optimize Global demand for methanol in 2017 increased by 4% over production levels. We believe our goal of 97% reliability is an 2016, supported by steady growth in traditional applications, achievable target that provides an opportunity to improve on growing methanol-to-olefin (“MTO”) demand and demand for our record production performance in 2017. other energy applications. Rising energy prices in 2017, including increases in the price of coal and oil and the price of derivatives such as olefins, supported methanol prices and the affordability of methanol into energy applications. While prices fluctuated over the year, our average realized methanol price in 2017 was $337 per tonne compared to $242 in 2016 – an increase of nearly 40% year-over-year, supported by strong methanol demand and global supply challenges. We produced a record 7.2 million tonnes of methanol in 2017. This achievement reflects both the investments made in our asset base and improved access to natural gas feedstock. In Egypt, we have received 100% of contracted gas since late 2016 and we continue to believe efforts by the Egyptian government will result in strong allocations of gas going forward. For the second consecutive year, the Chile I plant produced methanol during the southern hemisphere winter months, a period when lower gas deliveries are common. We also entered into an agreement with Empresa Nacional del Petroleo (ENAP) for additional gas supply to support our Chile operations. This agreement supports our commitment to restart the Chile IV plant at a very low capital cost, which is a key step in moving towards a two-plant operation in Chile by the end of the decade. Our financial and liquidity position remains healthy, giving us the flexibility we need to achieve our goals. As of December 31, 2017, we had $375 million in cash on the balance sheet, and during the year we extended the term of our $300 million revolving credit facility to December 2022. We continued our balanced approach to capital allocation in 2017. This included delivering on our commitment to return excess cash to shareholders by increasing our regular dividend by 9% and completing a 10% share repurchase program, which together returned $388 million to shareholders in 2017. Looking ahead: Enhancing our leadership position Strong industry fundamentals support a promising medium- term outlook. Demand growth forecasts are healthy, led by China and energy applications, including the MTO sector, along with the potential for significant demand from emerging applications over the next decade. In 2018, we will focus on exceeding customer expectations and maintaining our leadership position in the methanol industry through our sustainable, competitive advantage of unmatched secure supply. Our six production locations, world’s largest fleet of methanol ocean tankers and integrated global supply 2017 Methanex Corporation Annual Report 3 chain enable us to deliver secure, high-quality and reliable 2018. Several other countries are in the assessment or near- supply to our loyal customers around the world. commercial stage for low-level methanol fuel blending. In We will continue to profitably grow our production capacity to enhance our leadership position in line with market growth. This includes the restart of our Chile IV plant, expected in the third quarter of 2018. We remain optimistic that we can secure sufficient gas to restore Chile to a 1.7-million-tonne two-plant operation over the coming years. We are also assessing debottlenecking opportunities at our sites to increase production capability with limited capital investment. In 2016, Methanex’s wholly owned subsidiary, Waterfront Shipping, expanded its fleet to include seven new dual-fuel ocean tankers that can run on methanol. These tankers have been operating safely and reliably for almost two years and we plan to add another four dual-fuel vessels in 2019. These and other emerging energy applications that use methanol as a clean-burning fuel are expected to become even more prevalent over the next decade. addition, we are continuing to progress with advantaged We continue to deliver on our capital allocation strategy by projects in Geismar, Louisiana and Medicine Hat, Alberta. Our returning excess cash to shareholders. In January 2018, we plan is to have a project ready when the timing is right and it announced a 10% increase in the quarterly dividend to $0.33 makes sense for the business. In the longer term, we are per share from $0.30 per share, building on our long track looking for opportunities to grow our business and expand our record of growing the regular dividend. We also announced in operations globally. We are also focused on increasing the demand for our one product, methanol. The MTO sector is anticipated to grow as March 2018 that our Board of Directors has approved a new 10% share repurchase program, through a normal course issuer bid. there are three additional MTO units currently under We are very proud of our record achievements and results in construction with the combined capacity to consume over 2017, with the year ahead looking equally promising. three million tonnes of methanol, and we expect these plants to be completed in 2018. Global regulations to promote clean- burning fuels support the growing long-term demand for methanol in emerging energy applications. We are actively promoting new applications for methanol as a cleaner-burning and energy-efficient product, including methanol-to-power, fuel blending and marine fuel. In China, stricter environmental regulations are impacting the use of coal-fueled industrial boilers, and clean-burning methanol is an economic alternative. We estimate that there is already 1.5 million tonnes of methanol consumption for industrial boilers in China. The potential size of this market is significant and demand for this application continues to grow. China and other countries also show a growing interest in methanol as a vehicle fuel. A pilot program in five provinces in China is testing the emissions, technology and fuel economy of high-level blends of 85% or 100% methanol, with further expansion expected in I want to thank all team members throughout the organization and the Methanex Board of Directors for their energy and commitment over the past year. Together we celebrated 25 years, achieved record production and sales levels, and made progress on a number of initiatives that have made a strong company even stronger. On behalf of the Board and our team members, I want to thank you, our shareholders, for your continued support. Here’s to the next 25 years. John Floren President & Chief Executive Officer 4 2017 Methanex Corporation Annual Report Chairman’s Message to Shareholders DEAR FELLOW SHAREHOLDERS, What a difference a year makes. In 2016, the Company’s focus Methanex has never decreased its dividend or missed paying a was on ensuring a strong balance sheet and prudent cash dividend, even during the 2008 global financial crisis and management. In 2017, Methanex set records for both annual during low methanol price cycles such as those in 2016. Since sales and production and demonstrated its ability to generate 2013, Methanex has returned $685 million to shareholders significant cash flows with record Adjusted EBITDA. The through share buybacks and reduced the number of shares Company’s committed and disciplined approach to financial outstanding from 96 million to 84 million. management over the years underpins these impressive achievements. Company Strategy and Capital Allocation Policy We know that in any commodity business, there are inevitable business cycles and the best strategy for managing these cycles is to be fiscally prudent and ensure a competitive cost structure at the low end of the price cycle. At the higher end of the price cycle, decisions must be made about how to spend the “excess” cash. This is where Methanex’s capital allocation policy – a policy the Methanex Board directly oversees – plays a key role. Throughout the year, the Board spends considerable time and effort considering the Company’s strategy. These efforts culminate when members of the Board and management spend a full day together discussing strategy and the future direction of the Company. This sets the framework that guides all decisions made throughout the year. The appropriate allocation of capital is always part of the annual strategy In 2017, the Company completed a 10% normal course issuer bid and returned just over $286 million to shareholders through this share buyback. We also announced in March 2018 that our Board of Directors has approved a new 10% share repurchase program, through a normal course issuer bid. To facilitate growth and create sustainable value for shareholders, evaluating new growth opportunities is an important part of our strategy discussions. All potential growth projects must meet strict rate-of-return targets and risk characteristics before the Board approves an investment to spend growth capital. The Board fully supports the Company’s decision to pursue its near-term growth opportunities, including the intent to restart the Chile IV plant and, if additional gas supply can be secured, refurbishing Chile I in order to restore Chile to a two-plant operation at a very low capital cost. The Board is also fully supportive of management’s efforts to progress its advantaged projects which will not require any major capital spending over the next 18 months as this gives the Company the flexibility to execute review and is addressed regularly by the Board throughout the when the timing is right. year. The Board and management are fully aligned on Methanex’s strategy and, in particular, its decision to remain 100% focused on the methanol industry and its approach to capital allocation. The Company has three primary uses of capital. First, it must meet its financial commitments for essential expenditures such as plant maintenance and debt service. Second, the Company aims to pay a regular dividend that is intended to be meaningful, sustainable and growing over time. Over the longer term, we aspire to profitably grow the Company and return excess cash to shareholders through share buybacks. Methanex has consistently demonstrated its commitment to its approach to capital allocation. The dividend has been raised seven times over the past 10 years, including most recently in January 2018 when the dividend was increased by 10%. I would like to take this opportunity to thank Mr. Terry Poole, who will not be standing for re-election to the Board this year. Terry is Methanex’s longest-serving director, having joined the Board in 1994. He has been instrumental as Chair of the Audit, Finance and Risk Committee since 2006 and his contributions have been nothing short of outstanding. I want to thank Terry for his valuable contributions over the past 24 years and wish him the best in the future. Tom Hamilton Chairman of the Board 2017 Methanex Corporation Annual Report 5 Management’s Discussion and Analysis Index Overview of the Business Financial Results Supplemental Non-GAAP Measures Our Strategy Financial Highlights Production Summary Liquidity and Capital Resources Quarterly Financial Data (Unaudited) Risk Factors and Risk Management Selected Annual Information Critical Accounting Estimates Controls and Procedures How We Analyze Our Business Anticipated Changes to International Forward-Looking Statements Financial Reporting Standards This Management’s Discussion and Analysis (“MD&A”) is dated March 5, 2018 and should be read in conjunction with our consolidated financial statements and the accompanying notes for the year ended December 31, 2017. 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. As at March 5, 2018, we had 83,783,704 common shares issued and outstanding and stock options exercisable for 1,497,296 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.sedar.com 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 predominantly produced from natural gas and is also produced from coal, particularly in China. Approximately 55% of all 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 large number of chemical derivatives for which demand is influenced by levels of global economic activity. The remaining 45% of methanol demand comes from a range of energy- related applications. These include methanol-to-olefins (“MTO”), methyl tertiary-butyl ether (“MTBE”), direct blending of methanol into gasoline (primarily in China), di-methyl ether (“DME”), biodiesel, methanol-to-gasoline (“MTG”), industrial boilers and marine fuel. We are the world’s largest producer and supplier of methanol to the major international markets in Asia Pacific, North America, Europe and South America. Our total annual production capacity, including Methanex interests in jointly owned plants, is currently 9.4 million tonnes and is located in New Zealand, the United States, Trinidad, Egypt, Canada and Chile. 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 plants in Trinidad and Egypt, which provides us with an additional 1.3 million tonnes per year of methanol offtake supply when the plants are operating at full capacity. Refer to the Production Summary section on page 11 for more information. 2017 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. Demand for methanol is driven primarily by levels of industrial production, energy prices and the strength of the global economy. 6 2017 Methanex Corporation Annual Report Demand Demand for methanol grew by approximately 4% or 3 million tonnes in 2017, resulting in total demand of 78 million tonnes in 2017, excluding demand from integrated coal-to-olefins (“CTO”) facilities. Energy-related demand, which represented approximately 45% of total demand, grew by approximately 8% in 2017. Included in that sector, MTO represented approximately 15% of total methanol demand, and led demand growth as MTO units operated at high rates when they were not experiencing technical issues. This demand segment is anticipated to grow further as three additional MTO units are currently under construction, with the combined capacity to consume over three million tonnes of methanol annually at full operating rates, and we expect these plants to be completed in 2018. The future operating rates and methanol consumption from MTO facilities 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 and the impact of the olefin industry feedstock costs, including naptha, on relative competitiveness. Global regulations to promote the use of clean-burning fuels support long-term demand growth for a number of emerging energy applications for methanol. In China, stricter air quality emissions regulations are leading to a phase-out of coal-fueled industrial boilers in favour of cleaner fuels, creating a growing market for methanol as an alternative fuel. We estimate that this growing demand segment already represents over 1.5 million tonnes of methanol demand. Demand for other fuel applications in China remains healthy with interest from other countries growing. China’s high blend (M85-M100) methanol vehicle pilot program staged by the Ministry of Industry and Information Technology has achieved positive results during the official review in 2017 with further expansion planned for 2018. Blending continues to gain momentum outside of China. Several other countries are in the assessment or near-commercial stage for low-level methanol fuel blending. Regulatory changes are playing an increasing role in encouraging new applications for methanol due to its emissions benefits as a fuel. As a result of the International Maritime Organization’s expansion of future sulphur limits from ocean-going vessels, methanol has emerged as a promising competitive alternative. A number of projects are underway with cruise ships, ferries as well as tug boats and barges. In China, Methanex is partnering with the Ministry of Agriculture to initiate a marine fuel pilot and working with the Ministry of Transport and relevant stakeholders to support the development of methanol marine fuel guidelines. Demand from traditional applications for methanol grew by approximately 2% in 2017 and we estimate that traditional chemical derivatives consume approximately 55% of methanol globally. Supply There were no significant new industry capacity additions outside of China in 2017. In China, we estimate that approximately two million tonnes of new production capacity was added in 2017, excluding methanol production that is integrated with production of other downstream products and not sold on the merchant market. Over the next few years, the majority of large-scale capacity additions outside of China are expected to be in North America and the Middle East. OCI N.V. and Consolidated Energy Limited (through its subsidiary G2X Energy) continue to advance their jointly owned Natgasoline project, a 1.8 million tonne plant under construction in Beaumont, Texas with methanol production expected in 2018. There are a number of other large-scale projects under discussion in the United States; however, we believe that there has been limited committed capital to date. In Iran, there are a number of plants at various stages of construction. We expect just over four million tonnes of capacity to come onstream in Iran over the next two years; however, the start-up timing and future operating rates at these facilities will be dependent on various factors. Caribbean Gas Chemical Limited (“CGCL”) is constructing a 1.0 million tonne plant in Trinidad with announced production towards the end of the decade. To the end of 2018, we expect approximately two million tonnes of new capacity additions in China. Beyond 2018, we anticipate that new capacity additions in China will be modest due to increasing restrictions placed by the Chinese government on new coal-based capacity additions. We expect that production from new capacity in China will be consumed in that country. 2017 Methanex Corporation Annual Report 7 Price Methanex’s average realized price in 2017 increased to $337 per tonne from $242 per tonne in 2016. Although methanol pricing was volatile in 2017, the stronger average methanol price was supported by a number of factors. Demand for methanol in traditional and energy applications continued to grow, led by methanol-to-olefins demand in China. Higher energy prices also supported the affordability of methanol into energy applications. Rising coal and natural gas prices increased the relative cost of production and increased the cost curve support for methanol prices. In addition, a number of planned and unplanned outages throughout the year impacted global production, particularly towards the end of 2017 when methanol prices significantly exceeded the cost curve due to a shortage of supply. Methanol prices continued to move higher in the first quarter of 2018. Future methanol prices will ultimately depend on the strength of the global economy, industry operating rates, global energy prices, new supply additions and the strength of global demand. OUR STRATEGY Our primary objective is to create value by maintaining and enhancing our leadership in the global production, marketing and delivery of methanol to customers. To achieve this objective we have a simple, clearly defined strategy: global leadership, low cost and operational excellence. We also pride ourselves in being a leader in Responsible Care. 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. Global Leadership Global leadership is a key element of our strategy. We are focused on maintaining and enhancing our position as the major producer and supplier in the global methanol industry, improving our ability to 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 the major international markets in Asia Pacific, North America, Europe and South America. Our 2017 sales volume of 10.7 million tonnes of methanol represented approximately 14% of global methanol demand. Our leadership position has enabled us to play an important role in the industry, which includes publishing Methanex reference prices that are used in each major market as the basis of pricing for our customer contracts. The geographically diverse locations of our production sites allow us to deliver methanol cost-effectively to customers in all major global markets, while investments in global distribution and supply infrastructure, which include a fleet of ocean-going vessels and terminal capacity within all major international markets, enable us to enhance value to customers by providing reliable and secure supply. A key component of our global leadership strategy is the strength of our asset position with over 8.5 million tonnes of operating capacity in 2017. We achieved record production in 2017 of 7.2 million tonnes, exceeding our previous record of 7.0 million tonnes set in 2016. Our Chile operations are currently operating at less than full production capacity and provide further potential to increase production. 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. The Asia Pacific region continues to lead global methanol demand growth and we have invested in and developed our presence in this important region. We have storage capacity in China, South Korea and Japan that allows us to cost-effectively manage supply to customers and we have offices in Hong Kong, Shanghai, Tokyo, Seoul and Beijing to enhance customer service and industry positioning in the region. This enables us to participate in and improve our knowledge of the rapidly evolving and high growth methanol markets in China and other Asian countries. Our expanding presence in Asia Pacific has also helped us identify several opportunities to support the development of applications for methanol in the energy-related sector. 8 2017 Methanex Corporation Annual Report 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. Our cost structure per tonne continues to benefit from significant leverage on our fixed costs as production increases. The New Zealand, Trinidad and Egypt facilities are underpinned by natural gas purchase agreements where the natural gas price varies with methanol prices. This pricing relationship enables these facilities to be competitive throughout the methanol price cycle. We have a fixed price contract to supply substantially all our Geismar 1 facility and forward contracts to hedge natural gas prices for approximately 40% of the natural gas requirements of our Geismar 2 facility through 2025 with the remainder of natural gas requirements at Geismar purchased in the spot market. We have entered into fixed price contracts to supply the majority of our natural gas requirements for our Medicine Hat facility through 2031. Our production facilities are well located to supply global methanol markets. Still, 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 are focused on identifying initiatives to reduce these costs, including optimizing the use of our shipping fleet and taking advantage of prevailing conditions in the shipping market by varying the type and length of term of ocean vessel contracts. 2017 was our first full year with seven vessels equipped with flex-fuel engines that can run on conventional fuel or methanol, which provides us with further flexibility in our supply chain. We also look for opportunities to leverage our global asset position by entering into geographic product exchanges with other methanol producers to reduce distribution 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, human resources, corporate governance practices and financial management. To differentiate ourselves from competitors, we strive to be the best operator in all aspects of our business and to be 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 reliably and cost-effectively. We have a commitment to Responsible Care (an operating ethic and set of principles developed by the Chemistry Industry Association of Canada) and we use it as the umbrella under which we manage issues related to employee health and safety, environmental protection, community involvement, social responsibility, sustainability, security and emergency preparedness at each of our facilities and locations. Through the International Council of Chemical Associations, over 60 countries have adopted the Responsible Care Ethic and Principles for Sustainability. We believe a commitment to Responsible Care helps us achieve an excellent overall environmental and safety record. 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, logistics providers and industry associations in the methanol and methanol applications marketplace through active participation in local and international industry associations, seminars and conferences and online education initiatives. As a natural extension of the Responsible Care ethic, we have a Social Responsibility policy that aligns corporate governance, employee engagement and development, community involvement and social investment strategies with our core values and corporate strategy. Our strategy of operational excellence also includes the financial management of the Company. We operate in a highly competitive commodity industry. Accordingly, we believe it is important to maintain financial flexibility and we have adopted a prudent approach to financial management. We have an undrawn $300 million credit facility provided by highly rated financial institutions that expires 2017 Methanex Corporation Annual Report 9 in December 2022. As at December 31, 2017, we had a strong balance sheet and a cash balance of $375 million. We believe we are well-positioned to meet our financial commitments, pursue our near-term growth opportunities in Chile and deliver on our commitment to return excess cash to shareholders through dividends and share repurchases. FINANCIAL HIGHLIGHTS ($ Millions, except as noted) Production (thousands of tonnes) (attributable to Methanex shareholders) Sales volume (thousands of tonnes) Methanex-produced methanol Purchased methanol Commission sales Total sales volume1 Methanex average non-discounted posted price ($ per tonne)2 Average realized price ($ per tonne)3 Revenue Adjusted revenue4 Adjusted EBITDA4 Cash flows from operating activities Adjusted net income (loss)4 Net income (loss) (attributable to Methanex shareholders) Adjusted net income (loss) per common share ($ per share)4 Basic net income (loss) per common share ($ per share) Diluted net income (loss) per common share ($ per share) Common share information (millions of shares) Weighted average number of common shares Diluted weighted average number of common shares Number of common shares outstanding, end of period 2017 7,187 7,229 2,289 1,151 10,669 396 337 3,061 3,227 838 788 409 316 4.71 3.64 3.64 87 87 84 2016 7,017 6,828 1,892 758 9,478 279 242 1,998 2,118 287 227 (15) (13) (0.17) (0.14) (0.14) 90 90 90 1 Methanex-produced methanol represents our equity share of volume produced at our facilities and excludes volume marketed on a commission basis related to 36.9% of the Atlas facility and 50% of the Egypt facility that we do not own. Methanex-produced methanol includes any volume produced in Chile using natural gas supplied from Argentina under a tolling arrangement (“Tolling Volume”). There has been no Tolling Volume produced in the periods presented. 2 Methanex average non-discounted posted price represents the average of our non-discounted posted prices in North America, Europe and Asia Pacific weighted by sales volume. Current and historical pricing information is available at www.methanex.com. 3 Average realized price is calculated as revenue, excluding commissions earned and the Egypt non-controlling interest share of revenue, but including an amount representing our share of Atlas revenue, divided by the total sales volume of Methanex-produced and purchased methanol, but excluding Tolling Volume. 4 The Company has used the terms Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share, Adjusted revenue, and Operating income throughout this document. These items are non-GAAP measures 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 Supplemental Non-GAAP Measures section on page 36 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures. 10 2017 Methanex Corporation Annual Report PRODUCTION SUMMARY The following table details the annual production capacity and actual production of our facilities in 2017 and 2016: (Thousands of tonnes) New Zealand3 Geismar (USA) Trinidad (Methanex interest)4 Egypt (50% interest) Medicine Hat (Canada) Chile5 Annual production capacity1 Annual operating capacity2 2017 Production 2016 Production 2,430 2,000 2,000 630 600 1,720 9,380 2,430 2,000 2,000 630 600 880 1,943 1,935 1,768 534 593 414 2,181 2,055 1,605 293 488 395 8,540 7,187 7,017 1 Annual production capacity reflects, among other things, average expected plant outages, turnarounds and average age of the facility’s catalyst. As a result, the actual production of a facility may be higher or lower than the stated annual production capacity. 2 Annual operating capacity includes only those facilities which are currently capable of operating, but excludes any portion of an asset that is underutilized due to a lack of natural gas feedstock over a prolonged period of time. Our current annual operating capacity is 8.5 million tonnes, including 0.9 million tonnes related to our Chile operations. The operating capacity of our production facilities may be higher 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 composition or the age of the facility’s catalyst. 3 The operating capacity of New Zealand is made up of the two Motunui facilities and the Waitara Valley facility (refer to the New Zealand section below). 4 The operating capacity of Trinidad is made up of the Titan (100% interest) and Atlas (63.1% interest) facilities (refer to the Trinidad section below). 5 The production capacity of our Chile I and IV facilities is 1.7 million tonnes annually assuming access to natural gas feedstock. New Zealand In New Zealand, we produced 1.9 million tonnes of methanol in 2017 compared with 2.2 million tonnes in 2016. A planned turnaround and repairs at the Motunui facilities impacted production in 2017. The plants are able to produce at an annual production capacity of up to 2.4 million tonnes of methanol, depending on natural gas composition. Our New Zealand facilities are ideally situated to supply the growing Asia Pacific market. Refer to the Risk Factors and Risk Management – New Zealand section on page 26 for more information. United States The Geismar facilities produced 1.9 million tonnes of methanol in 2017 compared with 2.1 million tonnes in 2016. Lower production in 2017 compared with 2016 was a result of planned maintenance activities undertaken at both Geismar plants in the year. Refer to the Risk Factors and Risk Management – United States section on page 26 for more information. Trinidad Our ownership interest in the methanol facilities in Trinidad represents 2.0 million tonnes of annual capacity. The Titan and Atlas facilities in Trinidad are well located to supply global methanol markets and are underpinned by natural gas purchase agreements where the natural gas price varies with methanol prices. The Trinidad facilities produced a total of 1.8 million tonnes of methanol (Methanex share) in 2017 compared with 1.6 million tonnes in 2016. Our results in 2016 reflected a turnaround performed at the Atlas facility. During 2016 and 2017, we continued to experience natural gas curtailments to our Trinidad facilities due to a mismatch between upstream supply to the National Gas Company of Trinidad and Tobago Limited (“NGC”) and downstream demand from NGC’s customers. We are engaged with key stakeholders to find a solution to this issue, but expect to continue to experience gas curtailments to the Trinidad site. Refer to the Risk Factors and Risk Management – Trinidad section on page 27 for more information. 2017 Methanex Corporation Annual Report 11 Egypt We operate a 1.26 million tonne per year methanol facility in Egypt and have marketing rights for 100% of the production. The Egypt methanol facility is well located to supply European and Asia Pacific methanol markets. We produced 1,068,000 tonnes of methanol (Methanex share of 534,000) at the plant during 2017, compared to 586,000 tonnes (Methanex share of 293,000) in 2016. Production in 2017 was impacted by a planned turnaround in the third quarter. Following the turnaround, the plant restarted and ran at high rates for the remainder of the year. The Egypt facility has experienced periodic natural gas supply restrictions since mid-2012 and gas restrictions worsened through 2014 and 2015. Gas deliveries for the year ended December 31, 2017 have improved significantly compared to the same period in 2016. We are optimistic that the strong efforts by Egyptian governmental entities to fast-track existing and new upstream gas supply in Egypt are leading to improved gas deliveries and an improved outlook for gas deliveries in the medium term. Refer to the Risk Factors and Risk Management – Egypt section on page 27 for more information. Canada The Medicine Hat facility produced 593,000 tonnes of methanol in 2017 compared to 488,000 tonnes in 2016. A mechanical issue at the Medicine Hat facility impacted production in 2016 and early 2017. Repairs to address the issue were completed early in 2017 with the plant running at high rates for the remainder of the year. Refer to the Risk Factors and Risk Management – Canada section on page 27 for more information. Chile The Chile facility produced 414,000 tonnes of methanol in 2017 compared to 395,000 tonnes in 2016. Production increased for 2017 as compared to 2016 as a result of improved natural gas availability from Chilean suppliers. For the second consecutive year, we produced methanol throughout the southern hemisphere winter months, which are a period of typically lower gas deliveries. The future of our Chile operations is primarily dependent on the level of natural gas exploration and development in southern Chile and our ability to secure a sustainable natural gas supply to our facilities on economic terms from Chile and Argentina. We are optimistic that our underutilized 1.7 million tonne Chile facilities represent a very low capital cost growth opportunity for Methanex due to significant progress in developing natural gas reserves in the area. Project work has commenced for the restart of our Chile IV plant and, if additional gas supply can be secured, will be followed by the refurbishment of our Chile I plant in order to restore Chile to a two-plant operation at a very low capital cost. Refer to the Risk Factors and Risk Management – Chile section on page 28 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, Argentina gas settlement, finance costs, finance income and other expenses, and income taxes. The Company has used the terms Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share, Adjusted revenue and Operating income throughout this document. These items are non-GAAP measures 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 Supplemental Non-GAAP Measures section on page 36 for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures. 12 2017 Methanex Corporation Annual Report 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 CASH COSTS SALES VOLUME 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 and Tolling Volume, plus the difference from period to period in commission revenue. 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 and Tolling 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. 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 and Tolling 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 market the remaining 36.9% of its production through a commission offtake agreement. 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 (loss), respectively. For purposes of analyzing our business, Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share and Adjusted revenue include an amount representing our 63.1% equity share in Atlas. Our analysis of depreciation and amortization, finance costs, finance income and other expenses, and income taxes is consistent with the presentation of our consolidated statements of income (loss) and excludes amounts related to Atlas. We own 50% of the 1.26 million tonne per year Egypt methanol facility and market the remaining 50% of its production through a commission offtake agreement. We account for this investment using consolidation accounting, which results in 100% of the revenues and expenses being included in our financial statements. We also consolidate less then wholly-owned entities for which we have a controlling interest. 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 any entity where we have control. For purposes of analyzing our business, Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share and Adjusted revenue exclude the amounts associated with non-controlling interests. FINANCIAL RESULTS For the year ended December 31, 2017, we reported net income attributable to Methanex shareholders of $316 million ($3.64 income per common share on a diluted basis), compared with net loss attributable to Methanex shareholders of $13 million ($0.14 loss per common share on a diluted basis) for the year ended December 31, 2016. For the year ended December 31, 2017, we reported Adjusted EBITDA of $838 million and Adjusted net income of $409 million ($4.71 Adjusted net income per common share), compared with Adjusted EBITDA of $287 million and Adjusted net loss of $15 million ($0.17 Adjusted net loss per common share) for the year ended December 31, 2016. 2017 Methanex Corporation Annual Report 13 We calculate Adjusted EBITDA and Adjusted net income (loss) 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 and the impact of certain items associated with specific identified events. In 2017, we recorded a non-cash charge of $37 million to net income from the revaluation of a net deferred tax asset as a result of tax reform in the United States. In 2016, we recorded a gain of $32.5 million ($21 million after-tax) after reaching a settlement with Petrobras Energía S.A. (“Petrobras”) of Argentina to terminate Petrobras’ natural gas delivery obligations pursuant to a long-term natural gas supply agreement in Chile (the “Argentina gas settlement”). A reconciliation from net income (loss) attributable to Methanex shareholders to Adjusted net income (loss) and the calculation of Adjusted diluted net income (loss) per common share is as follows: ($ Millions, except number of shares and per share amounts) Net income (loss) attributable to Methanex shareholders U.S. tax reform charge Mark-to-market impact of share-based compensation, net of tax Argentina gas settlement, net of tax Adjusted net income (loss) Diluted weighted average shares outstanding (millions) Adjusted net income (loss) per common share A summary of our consolidated statements of income (loss) for 2017 and 2016 is as follows: ($ Millions) Consolidated statements of income: Revenue Cost of sales and operating expenses Mark-to-market impact of share-based compensation Adjusted EBITDA (attributable to associate) Amounts excluded from Adjusted EBITDA attributable to non-controlling interests Adjusted EBITDA (attributable to Methanex shareholders) U.S. tax reform charge Mark-to-market impact of share-based compensation Argentina gas settlement Depreciation and amortization Finance costs Finance income and other expenses Income tax recovery (expense) Earnings of associate adjustment1 Non-controlling interests adjustment1 Net income (loss) attributable to Methanex shareholders Net income (loss) 2017 2016 $ 316 $ (13) 37 56 – 409 87 4.71 $ $ – 19 (21) (15) 90 (0.17) $ $ 2017 2016 $ 3,061 $ 1,998 (2,352) (1,774) 68 148 (87) 838 (37) (68) – (232) (95) 13 (59) (72) 28 316 375 $ $ 22 63 (22) 287 – (22) 33 (228) (90) 4 9 (43) 37 (13) (28) $ $ 1 These adjustments represent depreciation and amortization, finance costs, finance income and other expenses 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 levels. The methanol business is a global commodity industry affected by supply and demand fundamentals. Due to the diversity of the end products in which methanol is used, demand for methanol largely depends upon levels of industrial production, energy prices and changes in general economic conditions, which can vary across the major international methanol markets. Revenue increased to $3.1 billion in 2017 from $2.0 billion in 2016. The higher revenue reflects an increase in our average realized price and higher sales volume in 2017. 14 2017 Methanex Corporation Annual Report We publish regional non-discounted reference prices for each major methanol market 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 2017 was $396 per tonne compared with $279 per tonne in 2016. Our average realized price in 2017 increased to $337 per tonne from $242 per tonne in 2016. Distribution of Revenue The geographic distribution of revenue by customer location for 2017 was similar to 2016. Details are as follows: ($ Millions, except where noted) China Europe United States South Korea South America Canada Other Asia $ 802 609 570 348 279 168 285 2017 26% $ 20% 19% 11% 9% 6% 9% 518 404 359 258 179 110 170 2016 26% 20% 18% 13% 9% 6% 8% $ 3,061 100% $ 1,998 100% Adjusted EBITDA (Attributable to Methanex Shareholders) 2017 Adjusted EBITDA was $838 million compared with 2016 Adjusted EBITDA of $287 million, an increase of $551 million. The key drivers of change in our Adjusted EBITDA are average realized price, sales volume and cash costs as described below (refer to the How We Analyze Our Business section on page 12 for more information). ($ Millions) Average realized price Sales volume Total cash costs Increase in Adjusted EBITDA Average Realized Price 2017 vs. 2016 $ 910 43 (402) $ 551 Our average realized price for the year ended December 31, 2017 increased to $337 per tonne from $242 per tonne for 2016, and this increased Adjusted EBITDA by $910 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, 2017 increased by 798,000 tonnes to 9.5 million tonnes from 8.7 million tonnes in 2016, and this increased Adjusted EBITDA by $43 million. Including commission sales volume from the Atlas and Egypt facilities, our total methanol sales volume was 10.7 million tonnes in 2017 compared with 9.5 million tonnes in 2016. Total Cash Costs The primary drivers of change in our total cash costs are changes in the cost of Methanex-produced methanol and changes in the cost of methanol we purchase from others (“purchased methanol”). We supplement our production with methanol produced by others through methanol offtake contracts and purchases on the spot market to meet customer needs and support our marketing efforts within the major global markets. We have adopted the first-in, first-out method of accounting for inventories and it generally takes between 30 and 60 days to sell the methanol we produce or purchase. Accordingly, the changes in Adjusted EBITDA as a result of changes in Methanex-produced and purchased methanol costs primarily depend on changes in methanol pricing and the timing of inventory flows. 2017 Methanex Corporation Annual Report 15 In a rising price environment, our margins at a given price are higher than in a stable price environment as a result of methanol purchases and production versus sales. Generally, the opposite applies when methanol prices are decreasing. The changes in Adjusted EBITDA due to changes in total cash costs for 2017 compared with 2016 were due to the following: ($ Millions) Methanex-produced methanol costs Proportion of Methanex-produced methanol sales Purchased methanol costs Other, net Decrease in Adjusted EBITDA due to changes in total cash costs Methanex-Produced Methanol Costs 2017 vs. 2016 $ (154) (13) (238) 3 $ (402) Natural gas is the primary feedstock at our methanol facilities and is the most significant component of Methanex-produced methanol costs. We purchase 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 the price of methanol to reduce our commodity price risk exposure. The variable price component of each gas contract is adjusted by a formula related to methanol prices above a certain level. Methanex-produced methanol costs were higher in 2017 compared with 2016 by $154 million, primarily due to the impact of changes in realized methanol prices on the variable portion of our natural gas costs 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. The proportion of Methanex-produced methanol sales decreased in 2017 due to total sales volume increasing more than production volume and this decreased Adjusted EBITDA by $13 million for 2017 compared with 2016. 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 major global markets 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 the major global markets. 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. As a result of changes in methanol prices in 2017 and the timing of inventory flows and purchases, the cost of purchased methanol per tonne increased and this decreased Adjusted EBITDA by $238 million compared with 2016. Other, Net Our investment in global distribution and supply infrastructure includes a dedicated fleet of ocean-going vessels. We utilize these vessels to enhance value to customers by providing reliable and secure supply and to optimize supply chain costs overall, including through third-party backhaul arrangements when available. Logistics costs can also vary from period to period depending on the levels of production from each of our production facilities and the resulting impact on our supply chain. Other, net relates to logistics costs, selling, general and administrative expenses and other operational charges. 16 2017 Methanex Corporation Annual Report Mark-to-Market Impact of Share-Based Compensation We grant share-based awards as an element of compensation. Share-based awards granted include stock options, share appreciation rights, tandem share appreciation rights, deferred share units, restricted share units and performance share units. For all share- based awards, share-based compensation is recognized over the related vesting period for the proportion of the service that has been rendered at each reporting date. Share-based compensation includes an amount related to the grant-date value and a mark-to-market impact as a result of subsequent changes in the Company’s share price. The grant-date value amount is included in Adjusted EBITDA and Adjusted net income (loss). The mark-to-market impact of share-based compensation as a result of changes in our share price is excluded from Adjusted EBITDA and Adjusted net income (loss) and analyzed separately. ($ Millions, except share price) Methanex Corporation share price1 Grant-date fair value expense included in Adjusted EBITDA and Adjusted net income (loss) Mark-to-market impact due to change in share price Total share-based compensation expense, before tax 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. 2017 2016 $ 60.55 $ 43.80 11 68 79 $ 11 22 33 $ For stock options, the cost is measured based on an estimate of the fair value at the date of grant 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 in fair value. Accordingly, share-based compensation expense associated with stock options will not vary significantly from period to period. 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. The fair values 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 have an additional feature where the ultimate number of units that vest will be determined by the Company’s total shareholder return in relation to a predetermined target over the period to vesting. The number of performance share units that will ultimately vest will be in the range of 25% to 150% based on the weighted-average closing share price for the 90 calendar days on the NASDAQ Global Select Market immediately preceding the year end date that the performance share units vest. For deferred, restricted and performance share units, the value is initially measured at the grant date and subsequently re-measured based on the market value of the Company’s common shares on the last trading day of each quarter. The price of the Company’s common shares as quoted on the NASDAQ Global Select Market increased from $43.80 per share at December 31, 2016 to $60.55 per share at December 31, 2017. 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 $68 million mark-to-market expense related to share-based compensation during 2017. Depreciation and Amortization Depreciation and amortization was $232 million for the year ended December 31, 2017 compared with $228 million for the year ended December, 31 2016. The increase in depreciation and amortization in 2017 compared with 2016 is primarily the result of higher sales volume of Methanex-produced methanol. U.S. Tax Reform In 2017, we recorded a non-cash charge of $37 million to net income related to the revaluation of a net deferred tax asset as a result of tax reform in the United States (refer to the Financial Results – Income Taxes section on page 18 for more information). Argentina Gas Settlement In 2016, we recorded a gain of $32.5 million ($21 million after-tax) after reaching a settlement with Petrobras to terminate Petrobras’ natural gas delivery obligations pursuant to a long-term natural gas supply agreement in Chile. The Company received the settlement amount in 2016. 2017 Methanex Corporation Annual Report 17 Finance Costs Finance costs are primarily comprised of interest on borrowings and finance lease obligations and were $95 million for the year ended December 31, 2017 compared to $90 million for the year ended December 31, 2016. The increase in finance costs for the year ended December 31, 2017 compared to the same period in 2016 is primarily due to interest incurred relating to new ocean going vessels treated as finance leases put in use part way through 2016. Finance Income and Other Expenses Finance income and other expenses was a gain of $13 million for the year ended December 31, 2017 compared to a gain of $4 million for the year ended December 31, 2016. The change in finance income and other expenses in 2017 compared with 2016 is primarily related to the impact of changes in foreign exchange rates. Income Taxes A summary of our income taxes for 2017 compared with 2016 is as follows: ($ Millions, except where noted) Amount before income tax U.S. tax reform charge Income tax recovery (expense) Amount after income tax Effective tax rate 2017 Adjusted Net Income 2016 Adjusted Net Loss Net Loss Net Income $ 471 $ 524 $ (37) $ (26) (37) (59) – (115) – 9 – 11 $ 375 $ 409 $ (28) $ (15) 20% 22% 25% 44% We earn the majority of our income in New Zealand, Trinidad, the United States, Egypt, Canada and Chile. In Trinidad and Chile, the statutory tax rate is 35%. The statutory rates in Canada and New Zealand are 27% and 28%, respectively. The United States statutory tax rate applicable to Methanex was 36% in 2017 and is 23% starting in 2018 and the Egypt statutory tax rate is 22.5%. 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. In December 2017, the United States passed the Tax Cuts and Jobs Act of 2017 (“U.S. tax reform” or “the Act”) which reduced the US federal corporate tax rate from 35% to 21% effective from January 1, 2018. The Act includes a number of other provisions related to corporate taxation that will impact Methanex. The decrease in the corporate tax rate and these other provisions will impact taxes payable on our income earned in the United States going forward. Up to December 31, 2017, Methanex had claimed certain interest deductions in the United States on debt instruments. There are provisions in the Act that going forward will reduce the value of these interest deductions. The impact of the passing of the U.S. tax reform recorded in the fourth quarter of 2017 is a non-cash tax charge recorded to net income of $37 million and to other comprehensive income of $9 million associated with the revaluation of net deferred tax assets. These charges have resulted in a total decrease of $46 million to net deferred tax assets and reflect our initial estimate and may be refined in the future as additional guidance emerges. The effective tax rate related to Adjusted net income was 22% for the year ended December 31, 2017 compared with 44% on an Adjusted net loss for the year ended December 31, 2016. Adjusted net income (loss) represents the amount that is attributable to Methanex shareholders and excludes the mark-to-market impact of share-based compensation and the impact of certain items associated with specific identified events. The effective tax rate differs from period to period depending on the source of earnings and the impact of foreign exchange fluctuations against the United States dollar on our tax balances. In periods with low income levels, the distribution of income and loss between jurisdictions can result in income tax rates that are not indicative of the longer term corporate tax rate. In addition, the effective tax rate is impacted by changes in tax legislation in the jurisdictions in which we operate. For additional information regarding income taxes, refer to note 15 of our 2017 consolidated financial statements. 18 2017 Methanex Corporation Annual Report LIQUIDITY AND CAPITAL RESOURCES A summary of our consolidated statements of cash flows is as follows: ($ Millions) Cash flows from / (used in) operating activities: 2017 2016 Cash flows from operating activities before changes in non-cash working capital $ 837 $ 314 Changes in non-cash working capital Cash flows from / (used in) financing activities: Dividend payments Interest paid Repayment of long-term debt Payments for the repurchase of shares Net proceeds on issue of long-term debt Other Cash flows from / (used in) investing activities: Property, plant and equipment Changes in non-cash working capital relating to investing activities Increase (decrease) in cash and cash equivalents Cash and cash equivalents, end of year Cash Flow Highlights Cash Flows from Operating Activities (49) 788 (101) (86) (57) (286) – (1) (531) (103) (3) (106) 151 375 $ (87) 227 (99) (83) (48) – 66 (6) (170) (100) 12 (88) (31) $ 224 Cash flows from operating activities for the year ended December 31, 2017 were $788 million compared with $227 million for the year ended December 31, 2016. The increase in cash flows from operating activities is primarily due to higher net income resulting from a higher realized methanol price. The following table provides a summary of these items for 2017 and 2016: ($ Millions) Net income (loss) Deduct earnings of associate Add dividends received from associate Add (deduct) non-cash items: Depreciation and amortization Income tax expense (recovery) Share-based compensation expense Finance costs Other Cash flows from operating activities before changes in non-cash working capital Changes in non-cash working capital: Trade and other receivables Inventories Prepaid expenses Accounts payable and accrued liabilities, including long-term payables 2017 2016 $ 375 $ (76) 85 232 96 79 95 (49) 837 (49) (20) (6) 26 (49) (28) (20) 47 228 (9) 33 90 (27) 314 (14) (28) (1) (44) (87) Cash flows from operating activities $ 788 $ 227 For a discussion of the changes in net income (loss), depreciation and amortization, share-based compensation recovery and finance costs, refer to the Financial Results section on page 13. 2017 Methanex Corporation Annual Report 19 Changes in non-cash working capital decreased cash flows from operating activities by $49 million for the year ended December 31, 2017, compared with a decrease of $87 million for the year ended December 31, 2016. Trade and other receivables increased in 2017 and this decreased cash flows from operating activities by $49 million, primarily due to the impact of trade receivables related to higher sales in 2017 compared to 2016. Inventories increased primarily due to the impact of higher methanol prices which decreased cash flows from operating activities by $20 million. Cash Flows from Financing Activities During 2017, we increased our regular quarterly dividend to $0.30 per common share from $0.275 per common share. Total dividend payments in 2017 were $101 million compared with $99 million in 2016 and total interest payments in 2017 were $86 million compared with $83 million in 2016. In October 2017, we completed a 10% normal course issuer bid initiated in March 2017, repurchasing the maximum 6,152,358 common shares for approximately $286 million. In 2017, we repaid $57 million of other limited recourse debt compared to $48 million of other limited recourse debt repayments in 2016. Cash Flows from Investing Activities During 2017, we incurred capital expenditures relating to our consolidated operations of $103 million primarily related to sustaining projects in New Zealand, Geismar, Egypt and Trinidad and project work for the restart of our Chile IV plant. The restart of the Chile IV plant is targeted for the third quarter of 2018 and the project is budgeted for $55 million. Liquidity and Capitalization Our objectives in managing liquidity and capital are to provide financial capacity and flexibility to meet our strategic objectives, to provide an adequate return to shareholders commensurate with the level of risk and to return excess cash through a combination of dividends and share repurchases. The following table provides information on our liquidity and capitalization position as at December 31, 2017 and December 31, 2016: ($ Millions, except where noted) Liquidity: Cash and cash equivalents Undrawn credit facilities Total liquidity Capitalization: Unsecured notes Limited recourse debt facilities, including current portion Total debt Non-controlling interests Shareholders’ equity Total capitalization Total debt to capitalization1 Net debt to capitalization2 2017 2016 $ $ 375 300 675 $ $ 224 300 524 $ 1,188 $ 1,186 314 1,502 244 1,501 370 1,556 209 1,597 $ 3,247 $ 3,362 46% 39% 46% 42% 1 Defined as total debt (including 100% of Egypt limited recourse debt facilities) divided by total capitalization. 2 Defined as total debt (including 100% of Egypt limited recourse debt facilities) less cash and cash equivalents divided by total capitalization less cash and cash equivalents. We manage our liquidity and capital structure and make adjustments to it in light of changes to economic conditions, the underlying risks inherent in our operations and the capital requirements to maintain and grow our business. The strategies we have employed 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. 20 2017 Methanex Corporation Annual Report We operate in a highly competitive commodity industry and believe that it is appropriate to maintain a strong balance sheet and retain financial flexibility. As at December 31, 2017, we had a cash balance of $375 million, access to a $300 million undrawn credit facility and no significant debt maturities until 2019 other than normal course obligations for principal repayments related to our limited recourse debt facilities. 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. We have covenant and default provisions under our long-term debt obligations and we also have certain covenants that could restrict access to the credit facility. The covenants governing the unsecured notes, which are specified in an indenture, apply to the Company and its subsidiaries, excluding the Egypt 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 indenture also contains customary default provisions. The significant covenants and default provisions under the credit facility include: a) the obligation to maintain an EBITDA to interest coverage ratio of greater than 2:1 calculated on a four-quarter trailing basis and a debt to capitalization ratio of less than or equal to 55%, both ratios calculated in accordance with definitions in the credit agreement that include adjustments related to the 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 the 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 the limited recourse subsidiaries. The Egypt limited recourse debt facilities have covenants and default provisions that apply only to the Egypt entity, including restrictions on the incurrence of additional indebtedness and requirement to fulfill certain conditions before the payment of cash or other shareholder distributions. Certain conditions had not been met, resulting in a restriction on shareholder distributions from the Egypt entity to December 31, 2017. Under amended terms reached in 2017, shareholder distributions are permitted if the average gas deliveries over the prior 12 months are greater than 70% of gas requirements. The first $100 million of shareholder distributions must be matched with $100 million of principal repayments on the Egypt limited recourse debt facilities. As at December 31, 2017, the Egypt cash balance on a 100% ownership basis was $131 million. The Egypt entity continues to be able to fully utilize its funds for operating, capital and financing needs, including the repayment of the Egypt limited recourse debt facilities and over the last 12 months has received all gas requirements. As at December 31, 2017, management believes the Company was in compliance with all significant terms and default provisions related to its long-term debt obligations. In 2017, we reached agreement with Empresa Nacional del Petróleo (“ENAP”) for additional gas supply in Chile and remain optimistic that our underutilized 1.7 million tonne Chile facilities represent a very low capital cost growth opportunity for Methanex due to the significant progress in developing natural gas reserves in the area. Project work has commenced for the restart of our Chile IV plant and remains targeted for the third quarter of 2018 and is budgeted for $55 million. If additional gas supply can be secured in Chile, the Chile IV project will be followed by the refurbishment of our Chile I plant in order to restore Chile to a two-plant operation at a very low capital cost. Our planned capital maintenance expenditure program directed towards maintenance, turnarounds and catalyst changes for existing operations is currently estimated to be in the range of $90 to $135 million to the end of 2018, dependent on the timing of turnarounds. In January 2018, we announced a 10% increase in the quarterly dividend to $0.33 per share from $0.30 per share for the dividend payable March 31, 2018. We also announced in March 2018 that our Board of Directors has approved a new 10% share repurchase program, through a normal course issuer bid. We believe we are well positioned to meet our financial commitments, pursue our near-term growth opportunities in Chile and deliver on our commitment to return excess cash to shareholders through dividends and share repurchases. 2017 Methanex Corporation Annual Report 21 Summary of Contractual Obligations and Commercial Commitments A summary of the amount and estimated timing of cash flows related to our contractual obligations and minimum commercial commitments as at December 31, 2017 is as follows: ($ Millions) Long-term debt repayments Long-term debt interest obligations Repayments of other long-term liabilities Natural gas and other Operating lease commitments 2018 2019-2020 2021-2022 After 2022 Total $ 57 65 52 474 91 $ 472 114 101 678 147 $ 391 $ 81 69 554 77 600 398 248 1,301 164 $ 1,520 658 470 3,007 479 $ 739 $ 1,512 $ 1,172 $ 2,711 $ 6,134 Long-Term Debt Repayments and Interest Obligations We have $350 million of unsecured notes that mature in 2019, $250 million of unsecured notes that mature in 2022, $300 million of unsecured notes that mature in 2024 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. Interest obligations related to variable interest rate long-term debt were estimated using current interest rates in effect as at December 31, 2017. For additional information, refer to note 8 of our 2017 consolidated financial statements. 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. 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 Egypt are take-or-pay contracts denominated in United States dollars and include base and variable price components to reduce our commodity price risk exposure. The variable price component of each natural gas contract is adjusted by a formula related to methanol prices above a certain level. 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. We also have multi-year fixed price natural gas contracts to supply one production facility in Geismar and Medicine Hat, and natural gas hedges in Geismar and Medicine Hat to manage exposure to natural gas price risk. We believe that the long-term natural gas dynamics in North America will support the long-term operation of these facilities. In the above table, we have included natural gas commitments in North America for Geismar and Medicine Hat at the contractual volume and prices. The above table does not include costs for planned capital maintenance or expansion expenditures or any obligations with original maturities of less than one year. Since June 2007, the Company’s natural gas suppliers from Argentina have curtailed all gas supply to the Company’s plants in Chile pursuant to long-term gas supply agreements. The Company has not received natural gas under these long-term agreements since 2007 and therefore potential future purchase obligations have been excluded from the table above. We have marketing rights for 100% of the production from our jointly owned Atlas and Egypt plants which results in purchase commitments of an additional 1.3 million tonnes per year of methanol offtake supply when these plants operate at capacity. As at December 31, 2017, the Company also had commitments to purchase methanol from other suppliers for approximately 0.8 million tonnes for 2018 and 1.5 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. 22 2017 Methanex Corporation Annual Report Operating Lease Commitments We have future minimum lease payments under operating leases relating primarily to vessel charter, terminal facilities, office space and equipment. For additional information refer to the Anticipated Changes to International Financial Reporting Standards section on page 35 and Note 21 of our 2017 consolidated financial statements. Off-Balance Sheet Arrangements As at December 31, 2017, 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 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 when the underlying hedged transaction is recognized in earnings. 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 the derivative financial instruments will fluctuate based on changes in commodity prices or foreign currency exchange rates. The following table shows the carrying value of each of our categories of financial assets and liabilities and the related balance sheet item as at December 31, 2017 and December 31, 2016: ($ Millions) Financial assets: Financial assets measured at fair value: Derivative instruments designated as cash flow hedges1 Financial assets not measured at fair value: Cash and cash equivalents Trade and other receivables, excluding tax receivable Project financing reserve accounts included in other assets Total financial assets2 Financial liabilities: Financial liabilities measured at fair value: Derivative instruments designated as cash flow hedges1 Financial liabilities not measured at fair value: Trade, other payables and accrued liabilities, excluding tax payable Long-term debt, including current portion Total financial liabilities 2017 2016 $ – $ 7 $ $ 375 527 28 930 91 528 1,502 $ $ 224 479 35 745 69 449 1,556 $ 2,121 $ 2,074 1 The Geismar 2 and Medicine Hat 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 carrying amount of the financial assets represents the maximum exposure to credit risk at the respective reporting periods. As at December 31, 2017, 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 are recorded at fair value unless exempted. 2017 Methanex Corporation Annual Report 23 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. The fair value of all the Company’s derivative contracts includes an adjustment 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 separately in other comprehensive income as the forward element excluded from hedging relationships. The Company has elected to manage its exposure to changes in natural gas prices for the Geismar 2 and Medicine Hat facilities by executing a number of forward contracts which it has designated as cash flow hedges for its highly probable forecast natural gas purchases in North America. The Company also designates as cash flow hedges forward exchange contracts to sell certain foreign currencies at a fixed U.S. dollar exchange rate to hedge its exposure to exchange rate fluctuations on certain foreign currency denominated 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 33, to be among the most important for understanding the issues that face our business and our approach to risk management. Methanol Price The methanol business is a highly competitive commodity industry and prices are affected by supply and demand fundamentals. Methanol prices have historically been, and are expected to continue to be, characterized by cyclicality. Factors influencing supply and demand for methanol and related risks are found below. We are not able to predict future methanol supply and demand balances, global economic activity, methanol prices or energy prices, all of which are affected by numerous factors 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 Demand for methanol largely depends upon the level of energy prices, global economic growth rates and government regulations and policies. Energy Prices Approximately 45% of methanol demand is from energy-related applications. Over the past number of years, methanol demand growth has been led by strong demand from these applications, as relatively high oil prices generated an economic incentive to substitute lower cost methanol for petroleum products or as a feedstock in energy-related products. The fastest growing application where methanol serves as a substitute for an energy product is MTO, where methanol is an alternative feedstock in the production of olefins. Olefins have historically been made from ethane and naptha which are energy based feedstocks. Methanol can be blended directly with gasoline, and DME (a methanol derivative) 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 growth, which could have an adverse effect on our results of operations and financial condition. Global Economic Growth Rates Approximately 55% of methanol demand is from traditional chemical applications. As these applications manufacture products used in a wide variety of industrial products and consumer goods, the rate of growth in demand for methanol from these applications tends to be correlated with overall global economic growth. Any slowdown in the global or regional economies can negatively impact demand for methanol and have a detrimental impact on methanol prices. 24 2017 Methanex Corporation Annual Report Government Regulations and Policies Changes in environmental, health and safety laws, regulations or requirements could impact methanol demand. The United States Environmental Protection Agency (“EPA”) is currently evaluating the human health effects of methanol as part of a standard review of chemicals under its Integrated Risk Information System (“IRIS”), a database of chemical health effects. No authoritative body has classified methanol as a carcinogen. A draft assessment for methanol was released by the EPA in 2010 classifying methanol as “Likely to be Carcinogenic to Humans.” In 2011, the EPA divided the draft assessment for methanol into cancer and non-cancer assessments. In September 2013, the EPA released the final non-cancer assessment, in which it established the maximum ingestion and inhalation levels for methanol that it claims will not result in adverse health impacts. The timeline for the final cancer assessment remains unknown, and no activity on the cancer assessment for methanol is currently contained on the EPA’s work plan. We are unable to determine whether the current draft classification will be maintained in the final cancer assessment or if this will lead other government agencies to reclassify methanol. Any reclassification could reduce future methanol demand, which could have an adverse effect on our results of operations and financial condition. In 2017, methanol demand for the production of formaldehyde represented approximately 30% of global demand. 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. The current EPA IRIS carcinogenicity classification for formaldehyde is “Likely to be Carcinogenic to Humans;” however, the EPA is reviewing this classification for formaldehyde as part of a standard review of chemicals. There is no firm time-line for the final assessment. In 2010, the EPA released its draft formaldehyde assessment, proposing formaldehyde as “Known to be Carcinogenic to Humans.” The National Toxicology Program (“NTP”) lists formaldehyde as “Known to be a Human Carcinogen” under the NTP Report on Carcinogens. EPA uses IRIS assessments as a basis for regulatory actions such as restricting emissions from products containing formaldehyde. The EPA continues to develop a revised IRIS assessment of formaldehyde. In 2009, the US National Cancer Institute (“NCI”) published a report on the health effects of occupational exposure to formaldehyde and a possible link to leukemia, multiple myeloma and Hodgkin’s disease. The NCI report concluded that there may be an increased risk of cancers of the blood and bone marrow related to a measure of peak formaldehyde exposure. The NCI report was the first part of an update of the 2004 NCI study that indicated possible links between formaldehyde exposure and nasopharyngeal cancer and leukemia. The International Agency for Research on Cancer also concluded that there is sufficient evidence in humans of a causal association of formaldehyde with leukemia. In 2011, the U.S. Department of Health and Human Services’ National Toxicology Program released its 12th Report on Carcinogens, modifying its listing of formaldehyde from “Reasonably Anticipated to be a Human Carcinogen” to “Known to be a Human Carcinogen.” We are unable to determine at this time if the EPA or other governments or government agencies will reclassify formaldehyde or what limits could be imposed related to formaldehyde emissions in the United States or elsewhere. Any such actions could reduce future methanol demand for use in producing formaldehyde, which could have an adverse effect on our results of operations and financial condition. Methanol Supply An increase in competitively priced methanol supply, all else equal, can displace supply from higher cost producers and have a negative impact on methanol price. Methanol supply is influenced by the cost of production including the availability and cost of raw materials, freight costs, capital costs and government policies. Methanol supply can become available from the construction of new methanol plants, by restarting idle methanol plants, by carrying out major expansions of existing plants or by debottlenecking existing plants to increase their production capacity. There was no significant new industry capacity additions outside of China in 2017. In China, we estimate that approximately two million tonnes of new production capacity was added in 2017. Over the next few years, the majority of large-scale capacity additions outside of China are expected to be in North America and the Middle East. OCI N.V. and Consolidated Energy Limited (through its subsidiary G2X Energy) continue to advance their jointly owned 2017 Methanex Corporation Annual Report 25 Natgasoline project, a 1.8 million tonne plant under construction in Beaumont, Texas with methanol production expected in 2018. There are a number of other large-scale projects under discussion in the United States; however, we believe that there has been limited committed capital to date. In Iran, there are a number of plants at various stages of construction. We expect just over four million tonnes of capacity to come onstream in Iran over the next two years; however, the start-up timing and future operating rates at these facilities will be dependent on various factors. Caribbean Gas Chemical Limited (“CGCL”) is constructing a 1.0 million tonne plant in Trinidad with announced production towards the end of the decade. To the end of 2018, we expect approximately two million tonnes of new capacity additions in China. Beyond 2018, we anticipate that new capacity additions in China will be modest due to increasing restrictions placed by the Chinese government on new coal-based capacity additions. We expect that production from new capacity in China will be consumed in that country. We cannot provide assurance that new supply additions will not outpace the level of future demand growth thereby contributing to negative pressure on methanol price. 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 close such plants, which could have an adverse effect on our results of operations and financial condition. New Zealand We have three plants in New Zealand with a total production capacity of up to 2.4 million tonnes of methanol per year, depending on natural gas composition. Two plants are located at Motunui and the third is located at nearby Waitara Valley. We have entered into several agreements with various natural gas suppliers to underpin our New Zealand operations with terms that range in length up to 2022. All 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 related to methanol prices above a certain level. We believe this pricing relationship enables these facilities to be competitive at all points in the methanol price cycle and provides gas suppliers with attractive returns. Certain of these 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. We continue to pursue opportunities to contract additional natural gas to supply our plants in New Zealand. 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 their ongoing exploration and development activities in New Zealand will be successful to enable our operations to operate at capacity. We cannot provide assurance that we will be able to obtain natural gas with the optimum composition. These factors could have an adverse impact on our results of operations and financial condition. United States We have two plants in Geismar, Louisiana with a total production capacity of 2.0 million tonnes. The Geismar facilities commenced first methanol production in 2015. We have a long-term fixed price agreement for the supply of substantially all of the natural gas requirements for the Geismar 1 facility that expires in 2025. During 2015, we entered into forward contracts to hedge natural gas prices for the Geismar 2 facility through 2025. We have hedged approximately 40% of the natural gas requirements with the remainder of natural gas requirements at Geismar purchased in the spot market. 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. 26 2017 Methanex Corporation Annual Report Trinidad Natural gas for our two methanol production facilities in Trinidad, with our share of total production capacity being 2.0 million tonnes per year, is supplied under take-or-pay contracts with the National Gas Company of Trinidad and Tobago Limited (“NGC”), which purchases the natural gas from upstream gas producers. Gas paid for, but not taken, in any year may be received in subsequent years subject to limitations. The contracts for Titan and Atlas have U.S. dollar base and variable price components, where the variable portion is adjusted by a formula related to methanol prices above a certain level. The contract for Atlas expires in 2024 and the contract for Titan expires in 2019. We believe the supply and demand fundamentals for natural gas in Trinidad will support the continued operation of these facilities. Since 2011, large industrial consumers in Trinidad, including our Titan and Atlas facilities, have experienced curtailments of natural gas supply due to a mismatch between upstream supply to NGC and downstream demand from NGC’s customers. Although Trinidad’s gas supply has stabilized in 2017 as a result of commissioning certain upstream facilities, we expect that gas curtailments to our facilities will continue in 2018. We cannot provide assurance that our contracted gas suppliers will be able to fully meet their commitments, that we will not experience longer or greater than anticipated curtailments due to upstream outages or other issues in Trinidad and that these curtailments will not be material. These factors could have an adverse impact on our results of operations and financial condition. Egypt We have a 25-year, take-or-pay natural gas supply agreement expiring in 2036 for the 1.26 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 related 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. Gas paid for, but not taken, in any year may be received in subsequent years subject to limitations. 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. Since the plant commenced operations in 2011, Egypt has experienced significant social unrest, including acts of sabotage and government transitions resulting in an adverse impact on the country’s economy and our operations in Egypt. We believe that these factors have contributed to constraints in the development of new supplies of natural gas coming to market and to natural gas supply becoming constrained between mid-2012 and late-2016, resulting in our Egypt plant operating below full capacity. Since late-2016, gas deliveries have improved significantly and we have received 100% of contracted gas supply. This is largely a result of the Egyptian government’s significant efforts to improve the gas supply situation in the country by encouraging natural gas exploration and establishing LNG import infrastructure. These efforts coupled with continuing natural gas discoveries have further strengthened the natural gas supply and demand balance and outlook for gas deliveries in Egypt. In spite of these positive developments in Egypt, the restrictions experienced in recent years may persist in the future. We cannot provide assurance that we will not experience natural gas restrictions and that this would not have an adverse impact on our results of operations and financial condition. Canada We have entered into fixed price contracts to supply substantially all of our natural gas requirements for our Medicine Hat facility through 2031. In addition to existing hedges in place through 2022, we entered into a long-term, fixed price physical supply contract in 2017 with a progressively growing supply commitment starting in 2018 and growing to 80-90% of the plant’s natural gas requirements from 2023 through 2031. We cannot provide assurance that our contracted suppliers will be able to meet their commitments or that we will be able to continue to secure sufficient natural gas for our Medicine Hat facility on commercially acceptable terms and that this will not have an adverse impact on our results of operations and financial condition. 2017 Methanex Corporation Annual Report 27 Chile In June 2007, our natural gas suppliers from Argentina curtailed all gas supplied to our plants in Chile pursuant to long-term gas supply agreements. In 2018, we do not expect to receive any further natural gas supply from Argentina under such long-term gas supply agreements. In November 2016, we executed a tolling agreement with YPF S.A. pursuant to which we receive natural gas from Argentina and convert the natural gas received into methanol and then re-deliver the methanol to Argentina. In January 2018, we started receiving some natural gas from Argentina under this arrangement. Since 2015, Empresa Nacional del Petróleo (“ENAP”) has made significant investments in the development of natural gas from unconventional reservoirs in Chile and this effort has resulted in increased gas deliveries from ENAP to our facilities. In January 2016, the U.S. Geological Survey assessed a technically recoverable mean resource of 8.3 trillion cubic feet of unconventional tight gas in the Chilean Magallanes Province. However, the potential for a sustained increase in gas deliveries to our plants will depend on the economics of the development of gas discoveries and, ultimately, the price at which we can obtain gas. In November 2017, Methanex reached a new agreement with ENAP for additional gas supply through December 31, 2019. We are continuing to work with gas suppliers in Chile and Argentina to secure sufficient natural gas to sustain our Chile operations beyond December 2019 and into the future. The future of our Chile operations is primarily dependent on the level of exploration and development of natural gas in southern Chile and our ability to secure a sustainable natural gas supply to our facilities on economic terms from Chile and Argentina. We cannot provide assurance that we will be able to continue to secure a sustainable natural gas supply to our facilities on economic terms and that this will not have an adverse impact on our results of operations or financial condition. Global Economic Conditions In addition to the potential influence of global economic activity levels on methanol demand and price, changing global economic conditions can result in changes in capital markets. A deterioration in economic conditions could have a negative impact on our investments, diminish our ability to access existing or future credit and increase the risk of defaults by customers, suppliers, insurers and other counterparties. Foreign Operations A significant portion of our operations and investments are located outside of North America, in New Zealand, Trinidad, Egypt, Chile, Europe and Asia. We are subject to risks inherent in foreign operations 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, 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. Many of the foregoing risks related to foreign operations may also exist for our domestic operations in North America. 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. We have organized our foreign operations in part based on certain assumptions about various tax laws (including capital gains and withholding taxes), 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. 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 and the Chinese yuan. 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 28 2017 Methanex Corporation Annual Report and capital expenditures. A portion of our revenue is earned in Euros, Canadian dollars and Chinese yuan. 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. Trade in methanol is subject to duty in a number of jurisdictions. Methanol sold in China from any of our producing regions is currently subject to duties ranging from 0% to 5.5%. There can be no assurance that the duties will not increase, that duties will not be levied in other jurisdictions in the future or that we will be able to mitigate the impact of future duties, if levied, or that future duties will not have a significant negative effect. Methanol is a globally traded commodity that is produced by many producers at facilities located around the world. Some producers and marketers 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”). 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. Liquidity Risk As at December 31, 2017, we had a cash balance of $375 million, including $131 million of cash relating to our Egypt entity consolidated on a 100% basis and $25 million of cash related to our 50% equity interest in multiple ocean going vessels consolidated on a 100% basis. We have an undrawn $300 million revolving credit facility with a syndicate of banks that expires in December 2022 and our ability to maintain access to the facility is subject to meeting certain financial covenants, including an EBITDA to interest coverage ratio and a debt to capitalization ratio, both ratios calculated in accordance with definitions in the credit agreement that include adjustments related to the Company’s limited recourse subsidiaries. As previously described in the Liquidity and Capital Resources – Liquidity and Capitalization section on page 20, certain conditions had not been met under the Egypt limited recourse debt facilities, which resulted in a restriction on shareholder distributions from the Egypt entity to December 31, 2017. Under amended terms reached in 2017, shareholder distributions are permitted if the average gas deliveries over the prior 12 months are greater than 70% of gas requirements. The first $100 million of shareholder distributions must be matched with $100 million of principal repayments on the Egypt limited recourse debt facilities. As at December 31, 2017, our long-term debt obligations include $1,200 million in unsecured notes, $241 million related to the Egypt limited recourse debt facilities (100% basis) and $73 million related to other limited recourse debt. The covenants governing the unsecured notes, which are specified in an indenture, apply to the Company and its subsidiaries, excluding the Egypt 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 indenture also contains customary default provisions. The Egypt limited recourse debt facilities are described as limited recourse as they are secured only by the assets of the Egypt entity. Accordingly, the lenders to the limited recourse debt facilities have no recourse to the Company or its other subsidiaries. The Egypt limited recourse debt facilities have covenants and default provisions that apply only to the Egypt entity, including restrictions on the incurrence of additional indebtedness and a requirement to fulfill certain conditions before the payment of cash or other distributions. For additional information regarding long-term debt, refer to note 8 of our 2017 consolidated financial statements. We cannot provide assurance that we will be able to access new financing in the future on commercially acceptable terms or at all, or that the financial institutions providing the credit facility 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. 2017 Methanex Corporation Annual Report 29 Customer Credit Risk Our customers are large global or regional petrochemical manufacturers or distributors and a number are highly leveraged. 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. Credit losses have not been significant in the past. Operational Risks Production Risks Most of our earnings are derived from the sale of methanol produced at our plants. Our business is subject to the risks of operating methanol production facilities, such as equipment breakdowns, interruptions in the supply of natural gas and other feedstocks, 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 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. 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. Distribution 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. 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. Chile IV Project We believe that our estimate for budgeted project costs and targeted completion date for our Chile IV restart project is reasonable. However, as we could be impacted by potential cost increases including the impact of costs due to labour shortages, we cannot provide any assurance that the cost estimates will not be exceeded or that the facility will begin commercial production within the targeted schedule, if at all, or that the facility will operate at its designed capacity or on a sustained basis. Any changes to the targeted timing of completion or estimated cost to complete the project or future ability to operate at production capacity could have an adverse impact on our results of operations and financial condition. 30 2017 Methanex Corporation Annual Report New Capital Projects As part of our strategy to strengthen our position as the global leader in the production and marketing of methanol, we intend to continue pursuing new opportunities to enhance our strategic position in the methanol industry. Our ability to successfully identify, develop and complete new 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 and completing the projects within the contemplated budgets and schedules and other risks commonly associated with the design, construction and start-up of large complex industrial projects. We cannot provide assurance that we will be able to identify or develop new methanol projects. Environmental Regulation The countries in which we operate all have 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. 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 protecting the environment have become more stringent in recent years 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. Management of Emissions Carbon dioxide (“CO2”) is a by-product of the methanol production process. The amount of CO2 generated by the methanol production process depends on the production technology, plant age, feedstock and any export of the by-product hydrogen. CO2 emissions are also generated from our marine operations when fuel is consumed during the global transport of methanol. We monitor and manage our CO2 emissions intensity, defined as the quantity of CO2 released per unit of production or transported tonne, relating to both methanol production and marine operations. Our CO2 emissions intensity has decreased over time due to newer technology and higher efficiency at our plants and in our vessel fleet. Plant efficiency, and thus CO2 emissions, is highly dependent on the design of the methanol plant, and accordingly the CO2 emission figure may vary from year to year depending on the mix of production assets and vessels in operation. Under the United Nations Framework Convention on Climate Change through the Kyoto Protocol and more recently the Paris Agreement (in effect from 2020), many of the countries we operate in have agreed to put forth efforts to reduce GHG emissions. We are currently subject to GHG regulations in New Zealand, Canada and Chile, but our production in the United States, Trinidad and Egypt are not subject to such regulations. In New Zealand, an Emissions Trading Scheme (“ETS”) imposes a carbon price on producers of fossil fuels, including natural gas, which is passed on to Methanex, increasing the cost of gas that Methanex purchases in New Zealand. However, as a trade-exposed company, Methanex is entitled to a free allocation of emissions units to partially offset those increased costs. Recent reviews of the ETS and a newly elected government led by the Labour Party in New Zealand may make changes to climate change policies that might impact the price of carbon in New Zealand or industry entitlements to free allocations. In December 2017, the newly appointed Minister for Climate Change announced plans to introduce a Zero Carbon Act by October 2018, following public consultation during 2018. At this stage there is no meaningful detail as to the content of the proposed Act. We do not expect the changes that have been implemented to date to have a material impact on our New Zealand business. Methanex has no information to believe that the new government will implement rapid or drastic revisions to current policy settings that would adversely affect our operations in New Zealand. Nevertheless, we cannot provide assurance that unanticipated changes to the ETS will not have a material impact on our business beyond 2018. 2017 Methanex Corporation Annual Report 31 Our Medicine Hat facility is located in the Canadian province of Alberta, which has an established GHG reduction regulation that applies to our plant. In 2017, the emissions reduction target was increased from 15% to 20%. To the extent Methanex cannot meet these emissions reduction targets we will incur additional cost to purchase offset credits. The cost of purchasing offset credits, based on the plant’s 2017 emissions intensity and its established GHG baseline intensity, was not material in 2017. Starting in 2018, a new regulation in Alberta, the Carbon Competitiveness Incentive Regulation, (“CCIR”) will come into effect and will impact our compliance obligations. The CCIR sets a benchmark of 80% of baseline emissions. The total regulated emissions calculation incorporates indirect emissions (e.g., electricity consumption), but also provides a deduction to our facility emissions calculation recognizing the benefit of the injection of CO2. Although certain regulations under the CCIR are still being drafted, we do not believe that the cost of compliance will be material. Nevertheless, we cannot provide assurance that unanticipated changes to the CCIR will not have a material impact on our business beyond 2018. Chile has imposed a carbon tax of $5/tonne from 2017 on certain CO2 emissions. The cost to our business of this tax was not material in 2017. However, the cost could increase if the scope of the legislation changes. 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. 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, health or safety matters), whether true or not. 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 investor confidence, an impediment to our overall ability to advance our projects or increased challenges in maintaining our social license to operate, which could have an adverse impact on our results of operations and financial condition. Cyber Security Our business processes rely on Information Technology (“IT”) systems that are interconnected with external networks, which increases the threat of cyber attack and the importance of cyber security. In particular, if a cyber attack was targeted at our production facilities or our ability to transport methanol, the result could harm our plants, 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 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 to protect our assets, detect an intrusion and respond in the event of a cyber security incident. As the cyber threat landscape continues to evolve, we implement continuous mitigation efforts, including: cyber education for our staff, risk prioritized controls to protect against known and emerging threats; tools to provide automated monitoring and alerting; and backup and recovery systems 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 cyber attacks. Methanex collects, uses and stores sensitive data in the normal course of business, including intellectual property, proprietary business information and personal information of Methanex’s employees and third parties. Despite our security measures in place, our IT systems may be vulnerable to cyber attacks or breaches. 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 Methanex’s reputation, which could have an adverse impact on our results of operations and financial condition. 32 2017 Methanex Corporation Annual Report Legal Proceedings The Board of Inland Revenue of Trinidad and Tobago has issued assessments against our 63.1% owned joint venture, Atlas, in respect of the 2005 to 2011 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 from 2005 to 2019 related to methanol produced by Atlas. Atlas had partial relief from corporation income tax until 2014. We have lodged objections to the assessments. Although there can be no assurance that these tax assessments will not have a material adverse impact, based on the merits of the cases and legal interpretation, we believe our position should be sustained. 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 and income taxes require us to make assumptions 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 26. See note 2 to our 2017 consolidated financial statements for our significant 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, 2017, the net book value of our property, plant and equipment was $3.0 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, 2017, we had accrued $34 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, excluding costs related to turnarounds, range from 10 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. 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. 2017 Methanex Corporation Annual Report 33 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 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 or idle the asset; 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. 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. 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, 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, 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 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. The two methanol facilities at the Company’s Chile site are considered as a single cash-generating unit (“Chile cash-generating unit”). The current carrying value of the Chile cash-generating unit is approximately $110 million. We recorded an impairment charge in the year ended December 31, 2012 to reduce the carrying value of our Chile assets to their estimated recoverable amount. We believe that there have been significant investments in the development of natural gas resources in Chile since 2015 that provide positive indications of gas availability in the region in the medium term; however, there is still uncertainty of our ability to access sufficient natural gas supply to our two plants economically. We do not believe that there are significant changes in events or circumstances that would support the reversal of the impairment charge recorded in the year ended December 31, 2012. Income Taxes We calculate current and deferred tax provisions for each of the jurisdictions in which we operate. Actual amounts of income tax expense are not final until tax returns are filed and accepted by the relevant tax authorities. This occurs subsequent to the issuance 34 2017 Methanex Corporation Annual Report 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. 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. Judgment is required in the application of income tax legislation. We are subject to assessments by various taxation authorities who may interpret tax legislation differently. These differences may affect the final amount or timing of the payment of taxes. 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, 2017, we had recognized deferred tax assets of $102 million relating to non-capital loss carryforwards in the United States, $384 million of unrecognized deductible temporary differences in the United States and $110 million of unrecognized non-capital loss carryforwards in Egypt that expire in 2020 and 2021. 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 The Company uses derivatives as part of its risk management program to mitigate variability associated with changing market values. Changes in 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 when the underlying hedged transaction is recognized in earnings. 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, 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 the complex nature of these products and the potential impact on our financial statements. ANTICIPATED CHANGES TO INTERNATIONAL FINANCIAL REPORTING STANDARDS In May 2014, the IASB issued IFRS 15, Revenue from Contracts with Customers (“IFRS 15”) establishing a comprehensive framework for revenue recognition. The standard replaces IAS 18, Revenue and IAS 11, Construction Contracts and related interpretations and is effective for annual periods beginning on or after January 1, 2018, with early adoption permitted. The Company has performed its assessment of the impact of the new standard and anticipates no impact on its consolidated financial statements. In January 2016, the IASB issued IFRS 16, Leases (“IFRS 16”), which eliminates the current operating/finance lease dual accounting model for lessees and replaces it with a single, on-balance sheet accounting model, similar to the current finance lease accounting. The standard replaces IAS 17, Leases (“IAS 17”) and related interpretations and is effective for annual periods beginning on or after January 1, 2019, with early application permitted. The Company plans to apply this standard at the date it becomes effective. The Company is currently assessing the impact of the new standard including the optional exemptions available. The recognition of all leases on balance sheet is expected to increase the assets and liabilities on the Consolidated Statement of Financial Position upon adoption. The increase primarily relates to ocean vessels, terminal facilities and other right of use assets currently accounted for as operating leases. In addition, the nature and timing of certain expenses related to leases previously classified as operating and presented in cost of sales and operating expenses will now change and be presented in depreciation and amortization and finance costs. As a result, the Company expects that adoption of IFRS 16 will significantly impact the consolidated financial statements. The Company has not yet decided whether it will use the optional exemptions available under the standard. Refer to note 21, commitments and contingencies, for operating lease commitments as at December 31, 2017 disclosed under IAS 17. 2017 Methanex Corporation Annual Report 35 The Company does not expect that any other new or amended standards or interpretations that are effective as of January 1, 2018 will have a significant impact on the Company’s results of operations or financial position. SUPPLEMENTAL 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). These are Adjusted EBITDA, Adjusted net income (loss), Adjusted net income (loss) per common share, Adjusted revenue, cash flow from operating activities before changes in non-cash working capital, and Operating income. These measures do not have any standardized meaning prescribed by IFRS and therefore are unlikely to be comparable to similar measures presented by other companies. We believe these measures are useful in assessing the operating performance and liquidity of the Company’s ongoing business. We also believe Adjusted EBITDA is frequently used by securities analysts and investors when comparing our results with those of other companies. These measures should be considered in addition to, and not as a substitute for, net income (loss), cash flows and other measures of financial performance and liquidity reported in accordance with IFRS. Adjusted EBITDA (attributable to Methanex shareholders) Adjusted EBITDA differs from the most comparable GAAP measure, net income (loss) attributable to Methanex shareholders, because it excludes finance costs, finance income and other expenses, income tax expense, depreciation and amortization, mark-to-market impact of share-based compensation and the Argentina gas settlement. 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 (loss) 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 (loss) 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 (loss) may differ from the total settlement cost. The following table shows a reconciliation from net income (loss) attributable to Methanex shareholders to Adjusted EBITDA: ($ Millions) Net income (loss) attributable to Methanex shareholders U.S. tax reform charge Mark-to-market impact of share-based compensation Depreciation and amortization Argentina gas settlement Finance costs Finance income and other expenses Income tax expense (recovery) Earnings of associate adjustment1 Non-controlling interests adjustment1 2017 2016 $ 316 $ (13) 37 68 232 – 95 (13) 59 72 (28) – 22 228 (33) 90 (4) (9) 43 (37) Adjusted EBITDA (attributable to Methanex shareholders) $ 838 $ 287 1 These adjustments represent finance costs, finance income and other expenses, income tax expense, and depreciation and amortization associated with our 63.1% interest in the Atlas methanol facility and the non-controlling interests. 36 2017 Methanex Corporation Annual Report Adjusted Net Income (Loss) and Adjusted Net Income (Loss) per Common Share Adjusted net income (loss) and Adjusted net income (loss) per common share are non-GAAP measures because they exclude the mark-to-market impact of share-based compensation and the impact of certain items associated with specific identified events, including the U.S. tax reform charge and the Argentina gas settlement. The following table shows a reconciliation from net income (loss) attributable to Methanex shareholders to Adjusted net income (loss) and the calculation of Adjusted diluted net income (loss) per common share: ($ Millions, except number of shares and per share amounts) Net income (loss) attributable to Methanex shareholders U.S. tax reform charge Mark-to-market impact of share-based compensation, net of tax Argentina gas settlement, net of tax Adjusted net income (loss) Diluted weighted average shares outstanding (millions) Adjusted net income (loss) per common share 2017 2016 $ 316 $ (13) 37 56 – 409 87 4.71 $ $ – 19 (21) (15) 90 (0.17) $ $ Adjusted Revenue (attributable to Methanex shareholders) Adjusted revenue differs from the most comparable GAAP measure, revenue, because it excludes the non-controlling interests’ share of revenue, but includes an amount representing our 63.1% share of Atlas revenue and revenue on volume marketed on a commission basis related to 36.9% of the Atlas methanol facility and 50% of the Egypt methanol facility that we do not own. A reconciliation from revenue to Adjusted revenue is as follows: ($ Millions) Revenue Methanex share of Atlas revenue1 Non-controlling interests’ share of revenue1 Other adjustments Adjusted revenue (attributable to Methanex shareholders) 1 Excludes intercompany transactions with the Company. 2017 2016 $ 3,061 $ 1,998 347 (175) (6) 190 (67) (3) $ 3,227 $ 2,118 Operating Income and Cash Flows from Operating Activities before Changes in Non-Cash Working Capital Operating income and cash flows from operating activities before changes in non-cash working capital are reconciled to GAAP measures in our consolidated statements of income and consolidated statements of cash flows, respectively. 2017 Methanex Corporation Annual Report 37 QUARTERLY FINANCIAL DATA (UNAUDITED) ($ Millions, except per share amounts) 2017 Revenue Adjusted EBITDA Adjusted net income Net income (attributable to Methanex shareholders) Adjusted net income per common share Basic net income per common share Diluted net income per common share 2016 Revenue Adjusted EBITDA Adjusted net income (loss) Net income (loss) (attributable to Methanex shareholders) Adjusted net income (loss) per common share Basic net income (loss) per common share Diluted net income (loss) per common share Three months ended Dec 31 Sep 30 Jun 30 Mar 31 $ $ 861 254 143 68 1.70 0.81 0.81 585 139 41 24 0.46 0.28 0.28 $ 720 143 52 32 0.60 0.38 0.38 $ 669 174 74 84 0.85 0.96 0.89 $ 810 267 140 132 1.56 1.47 1.46 $ 510 $ 468 $ 435 74 (1) (11) (0.01) (0.12) (0.12) 38 (31) (3) (0.34) (0.03) (0.08) 36 (24) (23) (0.27) (0.26) (0.26) A discussion and analysis of our results for the fourth quarter of 2017 is set out in our fourth quarter of 2017 Management’s Discussion and Analysis filed with the Canadian Securities Administrators on SEDAR at www.sedar.com 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) Revenue Adjusted EBITDA Adjusted net income (loss) Net income (loss) (attributable to Methanex shareholders) Adjusted net income (loss) per common share Basic net income (loss) per common share Diluted net income (loss) per common share Cash dividends declared per common share Total assets Total long-term financial liabilities 2017 2016 2015 $ 3,061 $ 1,998 $ 2,226 838 409 316 4.71 3.64 3.64 1.175 4,611 1,851 287 (15) (13) (0.17) (0.14) (0.14) 1.100 4,557 1,853 401 110 201 1.20 2.21 2.01 1.075 4,556 1,720 38 2017 Methanex Corporation Annual Report CONTROLS AND PROCEDURES Disclosure Controls and Procedures Disclosure controls and procedures 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, 2017, 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 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. The design of any system of controls and procedures is based in part upon certain assumptions about the likelihood of future events. There can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote. 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, 2017, based on the framework set forth in Internal Control – Integrated Framework issued in 2013 by the Committee of Sponsoring Organizations of the Treadway Commission. 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, 2017. The attestation report is included in our consolidated financial statements on page 44. Changes in Internal Control over Financial Reporting There have been no changes during the year ended December 31, 2017 to internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, internal control over financial reporting. 2017 Methanex Corporation Annual Report 39 FORWARD-LOOKING STATEMENTS This 2017 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” 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: (cid:2) expected demand for methanol and its derivatives, (cid:2) availability of committed credit facilities and other financing, (cid:2) expected new methanol supply or restart of idled capacity and timing for start-up of the same, (cid:2) 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, (cid:2) expected methanol and energy prices, (cid:2) expected levels of methanol purchases from traders or other third parties, (cid:2) expected levels, timing and availability of economically priced natural gas supply to each of our plants, (cid:2) capital committed by third parties towards future natural gas exploration and development in the vicinity of our plants, (cid:2) our expected capital expenditures, (cid:2) anticipated operating rates of our plants, (cid:2) our ability to meet covenants or obtain or continue to obtain waivers associated with our long-term debt obligations, including, without limitation, the Egypt limited recourse debt facilities that have conditions associated with the payment of cash or other distributions and the finalization of certain land title registrations and related mortgages which require actions by Egyptian governmental entities, (cid:2) expected impact on our results of operations in Egypt or our financial condition as a consequence of civil unrest or actions taken or inaction by Egyptian governmental entities, (cid:2) our shareholder distribution strategy and anticipated distributions to shareholders, (cid:2) commercial viability and timing of, or our ability to execute, future projects, plant restarts, capacity expansions, plant relocations or other business initiatives or opportunities, (cid:2) our financial strength and ability to meet future financial commitments, (cid:2) expected operating costs, including natural gas feedstock (cid:2) expected global or regional economic activity (including costs and logistics costs, industrial production levels), (cid:2) expected tax rates or resolutions to tax disputes, (cid:2) expected outcomes of litigation or other disputes, claims (cid:2) expected cash flows, earnings capability and share price, and assessments, and (cid:2) 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: (cid:2) the supply of, demand for and price of methanol, methanol (cid:2) receipt or issuance of third-party consents or approvals, derivatives, natural gas, coal, oil and oil derivatives, including, without limitation, governmental registrations of (cid:2) our ability to procure natural gas feedstock on commercially acceptable terms, (cid:2) operating rates of our facilities, land title and related mortgages in Egypt and governmental approvals related to rights to purchase natural gas, (cid:2) the establishment of new fuel standards, 40 2017 Methanex Corporation Annual Report (cid:2) operating costs, including natural gas feedstock and logistics costs, capital costs, tax rates, cash flows, foreign exchange rates and interest rates, (cid:2) the availability of committed credit facilities and other financing, (cid:2) absence of a material negative impact from changes in laws or regulations, (cid:2) absence of a material negative impact from political instability in the countries in which we operate, and (cid:2) enforcement of contractual arrangements and ability to (cid:2) global and regional economic activity (including industrial perform contractual obligations by customers, natural gas production levels), and other suppliers and other third parties. (cid:2) absence of a material negative impact from major natural disasters, 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: (cid:2) conditions in the methanol and other industries including fluctuations in the supply, demand and price for methanol (cid:2) competing demand for natural gas, especially with respect to domestic needs for gas and electricity in Chile and Egypt, and its derivatives, including demand for methanol for energy uses, (cid:2) the price of natural gas, coal, oil and oil derivatives, (cid:2) actions of governments and governmental authorities, including, without limitation, implementation of policies or other measures that could impact the supply of or demand (cid:2) our ability to obtain natural gas feedstock on commercially acceptable terms to underpin current operations and future for methanol or its derivatives, (cid:2) changes in laws or regulations, production growth opportunities, (cid:2) the ability to carry out corporate initiatives and strategies, (cid:2) actions of competitors, suppliers and financial institutions, (cid:2) conditions within the natural gas delivery systems that may prevent delivery of our natural gas supply requirements, (cid:2) 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, (cid:2) worldwide economic conditions, and (cid:2) other risks described in this 2017 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. 2017 Methanex Corporation Annual Report 41 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 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, 2017. 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 four 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, news releases and securities filings; the financial reporting process; the systems of internal accounting and financial controls; the professional qualifications and independence of the external auditor; the performance of the external auditors; risk management processes; financing plans; pension 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 has full and unrestricted access to the Committee. KPMG audited the consolidated financial statements and the effectiveness of internal controls over financial reporting. Their opinions are included in the annual report. A. Terence Poole Chairman of the Audit, Finance and Risk Committee March 5, 2018 John Floren Ian Cameron President and Chief Executive Officer Senior Vice President, Finance and Chief Financial Officer 42 2017 Methanex Corporation Annual Report Report of Independent Registered Public Accounting Firm To the Shareholders and Board of Directors of Methanex Corporation: Opinion on the Financial Statements We have audited the accompanying consolidated statements of financial position of Methanex Corporation (the “Company”) as of December 31, 2017, and 2016, the related consolidated statements of income (loss), comprehensive income (loss), changes in equity and cash flows for the years then ended, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017, and 2016, and its financial performance and its cash flows for the years then ended, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board. Report on Internal Control over Financial Reporting We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2017, based on the criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated March 5, 2018, expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting. Basis for Opinion These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“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 and in accordance with the ethical requirements that are relevant to our audit of the financial statements in Canada. We conducted our audits in accordance with Canadian generally accepted auditing standards and the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the 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 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 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 financial statements. We believe that our audits provide a reasonable basis for our opinion. Chartered Professional Accountants We have served as the Company’s auditor since 1992. Vancouver, Canada March 5, 2018 2017 Methanex Corporation Annual Report 43 Report of Independent Registered Public Accounting Firm The Shareholders and Board of Directors of Methanex Corporation: Opinion on Internal Control Over Financial Reporting We have audited Methanex Corporation’s (the “Company”) internal control over financial reporting as of December 31, 2017, based on the criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2017, based on the criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Report on the Financial Statements We also have audited, in accordance with Canadian generally accepted auditing standards and 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, 2017, and 2016, the related consolidated statements of income (loss), comprehensive income (loss), changes in equity and cash flows for the years then ended, and the related notes (collectively referred to as the “financial statements”) and our report dated March 5, 2018 expressed an unqualified opinion on those financial statements. Basis for Opinion The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying “Management’s Annual Report on Internal Control Over Financial Reporting”. 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 and in accordance with the ethical requirements that are relevant to our audit of the financial statements in Canada. 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. 44 2017 Methanex Corporation Annual Report 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. Chartered Professional Accountants Vancouver, Canada March 5, 2018 2017 Methanex Corporation Annual Report 45 Consolidated Statements of Financial Position (thousands of U.S. dollars, except number of common shares) As at ASSETS Current assets: Cash and cash equivalents Trade and other receivables (note 3) Inventories (note 4) Prepaid expenses Non-current assets: Property, plant and equipment (note 5) Investment in associate (note 6) Deferred income tax assets (note 15) 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 other long-term liabilities (note 9) Non-current liabilities: Long-term debt (note 8) Other long-term liabilities (note 9) Deferred income tax liabilities (note 15) Equity: Capital stock 25,000,000 authorized preferred shares without nominal or par value Unlimited authorization of common shares without nominal or par value Issued and outstanding common shares at December 31, 2017 were 83,770,254 (2016 – 89,824,338) Contributed surplus Retained earnings Accumulated other comprehensive loss Shareholders’ equity Non-controlling interests Total equity Commitments and contingencies (notes 6 and 21) Subsequent events (note 8) See accompanying notes to consolidated financial statements. Approved by the Board: Dec 31 2017 Dec 31 2016 $ 375,479 $ 223,890 536,636 304,464 26,548 499,603 281,328 20,846 1,243,127 1,025,667 2,998,326 3,117,469 188,922 102,341 78,026 197,402 137,341 78,784 3,367,615 3,530,996 $ 4,610,742 $ 4,556,663 $ 626,817 $ 523,216 55,905 65,226 747,948 53,997 29,720 606,933 1,446,366 1,502,209 404,885 266,432 351,191 290,980 2,117,683 2,144,380 480,331 2,124 511,465 2,568 1,088,150 1,124,104 (69,841) (41,302) 1,500,764 244,347 1,745,111 1,596,835 208,515 1,805,350 $ 4,610,742 $ 4,556,663 A. Terence Poole (Director) John Floren (Director) 46 2017 Methanex Corporation Annual Report Consolidated Statements of Income (Loss) (thousands of U.S. dollars, except number of common shares and per share amounts) For the years ended December 31 Revenue Cost of sales and operating expenses (note 10) Depreciation and amortization (note 10) Argentina gas settlement Operating income Earnings of associate (note 6) Finance costs (note 11) Finance income and other expenses Income (loss) before income taxes Income tax recovery (expense) (note 15): Current Deferred Net income (loss) Attributable to: Methanex Corporation shareholders Non-controlling interests (note 23) Income (loss) per common share for the period attributable to Methanex Corporation shareholders: Basic net income (loss) per common share (note 12) Diluted net income (loss) per common share (note 12) Weighted average number of common shares outstanding Diluted weighted average number of common shares outstanding See accompanying notes to consolidated financial statements. 2017 2016 $ 3,060,642 $ 1,998,429 (2,351,949) (232,225) (1,774,429) (228,054) – 476,468 75,995 (94,955) 13,377 470,885 (85,504) (10,284) (95,788) 375,097 316,135 58,962 375,097 3.64 3.64 86,768,589 86,824,948 $ $ $ $ $ 32,500 28,446 19,930 (90,060) 4,180 (37,504) (54,677) 63,956 9,279 (28,225) (12,545) (15,680) (28,225) (0.14) (0.14) 89,783,883 89,783,883 $ $ $ $ $ 2017 Methanex Corporation Annual Report 47 Consolidated Statements of Comprehensive Income (Loss) (thousands of U.S. dollars) For the years ended December 31 Net income (loss) Other comprehensive income (loss): Items that may be reclassified to income: Change in fair value of cash flow hedges (note 18) Forward elements excluded from hedging relationship (note 18) Items that will not be reclassified to income: Actuarial gains (losses) on defined benefit pension plans (note 20(a)) Taxes on above items Comprehensive income (loss) Attributable to: Methanex Corporation shareholders Non-controlling interests (note 23) See accompanying notes to consolidated financial statements. 2017 2016 $ 375,097 $ (28,225) (74,790) 45,416 564 674 (28,136) 346,961 287,999 58,962 346,961 $ $ $ 153,863 (174,078) (77) 6,597 (13,695) (41,920) (26,240) (15,680) (41,920) $ $ $ 48 2017 Methanex Corporation Annual Report 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 loss Shareholders’ equity Non-controlling interests Total equity Balance, December 31, 2015 89,671,198 $ 509,464 $ 2,426 $ 1,235,615 $ (27,776) $ 1,719,729 $ 248,844 $ 1,968,573 Net loss Other comprehensive loss Compensation expense recorded for stock options Issue of shares on exercise – – – – – – of stock options 153,140 1,506 – – 637 – Reclassification of grant- date fair value on exercise of stock options Dividend payments to Methanex Corporation shareholders ($1.10 per common share) Distributions made and accrued to non-controlling interests Equity contributions by non-controlling interests – – – – (12,545) – (169) (13,526) (12,545) (13,695) – – – 495 (495) – – – – – – (98,797) – – – – – – – – 637 1,506 – (98,797) – – Net income Other comprehensive income (loss) Compensation expense recorded for stock options Issue of shares on exercise – – – – – – of stock options 98,274 3,059 – – 488 – Reclassification of grant- date fair value on exercise of stock options Payment for shares repurchased Dividend payments to Methanex Corporation shareholders ($1.175 per common share) Distributions made and accrued to non-controlling interests Equity contributions by non-controlling interests – 932 (932) (6,152,358) (35,125) – – – – – – – – – – 488 3,059 – (286,120) (101,497) – – – (250,995) (101,497) – – – – – – – – – (15,680) – – – – – (28,225) (13,695) 637 1,506 – (98,797) (24,674) (24,674) 25 25 – – – – – – (28,136) 488 3,059 – (286,120) (101,497) Balance, December 31, 2016 89,824,338 $ 511,465 $ 2,568 $ 1,124,104 $ (41,302) $ 1,596,835 $ 208,515 $ 1,805,350 316,135 – 316,135 58,962 375,097 403 (28,539) (28,136) – – (31,300) (31,300) 8,170 8,170 Balance, December 31, 2017 83,770,254 $ 480,331 $ 2,124 $ 1,088,150 $ (69,841) $ 1,500,764 $ 244,347 $ 1,745,111 See accompanying notes to consolidated financial statements. 2017 Methanex Corporation Annual Report 49 Consolidated Statements of Cash Flows (thousands of U.S. dollars) For the years ended December 31 CASH FLOWS FROM / (USED IN) OPERATING ACTIVITIES Net income (loss) Deduct earnings of associate Dividends received from associate Add (deduct) non-cash items: Depreciation and amortization Income tax expense (recovery) Share-based compensation expense Finance costs Other Income taxes paid Other cash payments, including share-based compensation Cash flows from operating activities before undernoted Changes in non-cash working capital (note 16(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 Finance leases Equity contributions by non-controlling interests Cash distributions to non-controlling interests Proceeds on issue of shares on exercise of stock options CASH FLOWS FROM / (USED IN) INVESTING ACTIVITIES Property, plant and equipment Other assets Changes in non-cash working capital related to investing activities (note 16(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. 2017 2016 $ 375,097 $ (28,225) (75,995) 84,553 232,225 95,788 78,821 94,955 4,033 (35,890) (16,477) 837,110 (49,368) 787,742 (286,120) (101,497) (86,041) – (56,997) (6,880) 8,170 (4,330) 3,059 (19,930) 47,325 228,054 (9,279) 33,493 90,060 1,559 (5,241) (23,505) 314,311 (87,644) 226,667 – (98,797) (82,965) 65,700 (48,417) (5,144) 25 (1,410) 1,506 (530,636) (169,502) (103,170) – (2,347) (105,517) 151,589 223,890 (99,881) (66) 11,738 (88,209) (31,044) 254,934 $ 375,479 $ 223,890 50 2017 Methanex Corporation Annual Report Notes to Consolidated Financial Statements (Tabular dollar amounts are shown in thousands of U.S. dollars, except where noted) Year ended December 31, 2017 1. Nature of operations: Methanex Corporation (“the Company”) is an incorporated entity with corporate offices in Vancouver, Canada. The Company’s operations consist of the production and sale of methanol, a commodity chemical. The Company is the world’s largest producer and supplier of methanol to the major international markets of Asia Pacific, North America, Europe and South America. 2. Significant accounting policies: a) Statement of compliance: These consolidated financial statements are prepared in accordance with International Financial Reporting Standards (“IFRS”), as issued by the International Accounting Standards Board (“IASB”). These consolidated financial statements were approved and authorized for issue by the Board of Directors on March 5, 2018. b) Basis of presentation and consolidation: These consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries, less than wholly-owned entities for which it has a controlling interest and its equity-accounted joint venture. Wholly-owned subsidiaries are entities in which the Company has control, directly or indirectly, where control is defined as the power to govern the financial and operating policies of an enterprise so as to obtain benefits from its activities. For less than wholly-owned entities for which the Company has a controlling interest, a non-controlling interest is included in the Company’s consolidated financial statements and represents the non-controlling shareholders’ interest in the net assets of the entity. The Company also consolidates any special purpose entity where the substance of the relationship indicates the Company has control. All significant intercompany transactions and balances have been eliminated. Preparation of these consolidated financial statements requires estimates, judgments and assumptions that affect the amounts reported and disclosed in the financial statements and related notes. The areas of estimation and judgment that management considers most significant are property, plant and equipment (note 2(g)), financial instruments (note 2(o)), fair value measurements (note 2(p)) and income taxes (note 2(q)). Actual results could differ from those estimates. c) Reporting currency and foreign currency translation: Functional currency is the currency of the primary economic environment in which an entity operates. The majority of the Company’s business in all jurisdictions is transacted in United States dollars and, accordingly, these consolidated financial statements have been measured and expressed in that currency. The Company translates foreign currency denominated monetary items at the period-end exchange rates, foreign currency denominated non-monetary items at historic rates and revenues and expenditures at the exchange rates at the dates of the transactions. Foreign exchange gains and losses are included in earnings. d) Cash and cash equivalents: Cash and cash equivalents include securities with maturities of three months or less when purchased. e) Receivables: The Company provides credit to its customers in the normal course of business. The Company performs ongoing credit evaluations of its customers and maintains reserves for potential credit losses. The Company records an allowance for doubtful accounts or writes down the receivable to estimated net realizable value if not collectible in full. Credit losses have historically been within the range of management’s expectations. f) Inventories: Inventories are valued at the lower of cost and estimated net realizable value. Cost is determined on a first-in, first-out basis and includes direct purchase costs, cost of production, allocation of production overhead and depreciation based on normal operating capacity and transportation. 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 2017 Methanex Corporation Annual Report 51 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. 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, excluding costs related to turnarounds, ranges from 10 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 the various production facilities. 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. Assets under finance lease are depreciated to their estimated residual value based on the shorter of their useful lives and the lease term. Impairment The Company reviews the carrying value of long-lived assets for impairment whenever events or changes in circumstances indicate an asset’s carrying value may not be recoverable. Examples of such events or changes in circumstances 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 significant change in the long-term methanol price 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. 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 cost to sell or its value in use. Value in use is determined by estimating the pre-tax cash flows expected to be generated from the asset or cash-generating unit over its estimated useful life discounted by a pre-tax discount rate. An impairment writedown is recorded for the difference that 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 purposes of recognition and measurement of an impairment writedown, the Company groups 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 methanol facilities in a particular location are interdependent as a result of common infrastructure and/or feedstock from sources that can be shared within a facility location, the Company groups assets based on site locations for the purpose of determining impairment. h) Other assets: Intangible assets are capitalized to other assets and amortized to depreciation and amortization expense on an appropriate basis to charge the cost of the assets against earnings. 52 2017 Methanex Corporation Annual Report Financing fees related to undrawn credit facilities are capitalized to other assets and amortized to finance costs over the term of the credit facility. i) Leases: Leasing contracts are classified as either finance or operating leases based on the substance of the contractual arrangement at inception date. A lease is classified as a finance lease if it transfers substantially all of the risks and rewards of ownership of the leased asset. Where the contracts are classified as finance leases, upon initial recognition, the asset and liability are recorded at the lower of fair value and the present value of the minimum lease payments, net of executory costs. Finance lease payments are apportioned between interest expense and repayments of the liability. Where the contracts are classified as operating leases, they are not recognized in the Company’s consolidated statements of financial position and lease payments are charged to income as they are incurred on a straight line basis over the lease term. j) Site restoration costs: The Company recognizes a liability to dismantle and remove assets or to restore a site upon which the assets are located. The Company estimates the present value of the expenditures required to settle the liability by determining the current market cost required to settle the site restoration costs, adjusts for inflation through to the expected date of the expenditures and then discounts this amount back to the date when the obligation was originally incurred. As the liability is initially recorded on a discounted basis, it is increased each period until the estimated date of settlement. The resulting expense is referred to as accretion expense and is included in finance costs. The Company reviews asset retirement obligations and adjusts the liability and corresponding asset as necessary to reflect changes in the estimated future cash flows, timing, inflation and discount rates underlying the measurement of the obligation. 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 actuarial assumptions including inflation rates, mortality, plan expenses, salary growth and discount rates. The present value of the net defined benefit obligation (asset) is determined by discounting the net estimated future cash flows using current market bond yields that have terms to maturity approximating the terms of the net obligation. Actuarial gains and losses arising from differences between these assumptions and actual results are recognized in other comprehensive income and recorded in retained earnings. The Company recognizes gains and losses on the settlement of a defined benefit plan in income when the settlement occurs. The cost for defined contribution benefit plans is recognized in net income (loss) as earned by the employees. 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 2017 Methanex Corporation Annual Report 53 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 have an additional feature where the ultimate number of units that vest will be determined by the Company’s total shareholder return in relation to a predetermined target over the period to vesting. The number of units that will ultimately vest will be in the range of 50% to 120% of the original grant for grants prior to 2014 and in the range of 25% to 150% for subsequent grants based on the weighted-average closing share price for the 90 calendar days on the NASDAQ Global Select Market immediately preceding the year end date that the performance share units 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. Additional information related to the stock option plan, TSARs, SARs and the deferred, restricted and performance share units is described in note 13. 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. Outstanding TSARs may be settled in cash or common shares at the holder’s option. For the purposes of calculating diluted net income (loss) per common share, the more dilutive of the cash-settled or 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 and denominator if the equity-settled method is determined to have a dilutive effect on diluted net income (loss) per common share. 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 12. n) Revenue recognition: Revenue is recognized based on individual contract terms when the risk of loss to 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 Company retains risk of loss during shipment. For methanol sold on a consignment basis, revenue is recognized when the customer consumes the methanol. For methanol sold on a commission basis, the commission income is included in revenue when earned. 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 54 2017 Methanex Corporation Annual Report 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. p) Fair value measurements: Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements within the scope of IFRS 13 are categorized into Level 1, 2 or 3 based on the degree to which the inputs are observable and the significance of the inputs to the fair value measurement in its entirety. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the entity can access at the measurement date. Level 2 inputs are inputs, other than quoted prices included within Level 1, that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. Financial instruments measured at fair value and categorized within the fair value hierarchy are disclosed in note 18. 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. The Company accrues for taxes that will be incurred upon distributions from its subsidiaries when it is probable that the earnings will be repatriated. r) Provisions: Provisions are recognized where a legal or constructive obligation has been incurred as a result of past events, it is probable that an outflow of resources will be required to settle the obligation, and a reliable estimate of the amount of the obligation can be made. Provisions are measured at the present value of the expenditures expected to be required to settle the obligation. s) Segmented information: The Company’s operations consist of the production and sale of methanol, which constitutes a single operating segment. t) Application of new and revised accounting standards: The Company has adopted the amendments to IAS 7, Statement of Cash Flows, which were effective for annual periods beginning on or after January 1, 2017. As a result of applying the amendment, the Company presented new disclosures relating to change in financial liabilities arising from financing activities (note 16(b)). u) Anticipated changes to International Financial Reporting Standards: In May 2014, the IASB issued IFRS 15, Revenue from Contracts with Customers (“IFRS 15”) establishing a comprehensive framework for revenue recognition. The standard replaces IAS 18, Revenue and IAS 11, Construction Contracts and related interpretations and is effective for annual periods beginning on or after January 1, 2018, with early adoption permitted. The Company has performed its assessment of the impact of the new standard and anticipates no impact on its consolidated financial statements. In January 2016, the IASB issued IFRS 16, Leases (“IFRS 16”), which eliminates the current operating/finance lease dual accounting model for lessees and replaces it with a single, on-balance sheet accounting model, similar to the current finance lease accounting. The standard replaces IAS 17, Leases (“IAS 17”) and related interpretations and is effective for annual periods beginning on or after January 1, 2019, with early application permitted. The Company plans to apply this standard at the date it becomes effective. The Company is currently assessing the impact of the new standard including the optional exemptions available. The recognition of all leases on balance sheet is expected to increase the assets and liabilities on the Consolidated Statement of Financial Position upon 2017 Methanex Corporation Annual Report 55 adoption. The increase primarily relates to ocean vessels, terminal facilities and other right of use assets currently accounted for as operating leases. In addition, the nature and timing of certain expenses related to leases previously classified as operating and presented in cost of sales and operating expenses will now change and be presented in depreciation and amortization and finance costs. As a result, the Company expects that adoption of IFRS 16 will significantly impact the consolidated financial statements. The Company has not yet decided whether it will use the optional exemptions available under the standard. Refer to note 21, commitments and contingencies, for operating lease commitments as at December 31, 2017 disclosed under IAS 17. The Company does not expect that any other new or amended standards or interpretations that are effective as of January 1, 2018 will have a significant impact on the Company’s results of operations or financial position. 3. Trade and other receivables: As at Trade Value-added and other tax receivables Egypt gas contract recoveries(a) Other Dec 31 2017 Dec 31 2016 $ 429,582 $ 335,606 36,584 24,466 46,004 63,738 41,578 58,681 $ 536,636 $ 499,603 a) Egypt gas contract recoveries: The natural gas supply agreement in Egypt has a mechanism whereby the Company is partially compensated when gas delivery shortfalls exceed a certain threshold. The receivable is secured by a combination of funds held in escrow and a bank guarantee. 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, 2017 is $2,219 million (2016 – $1,704 million). 5. Property, plant and equipment: Cost at January 1, 2017 Additions Disposals and other Cost at December 31, 2017 Accumulated depreciation at January 1, 2017 Disposals and other Depreciation Accumulated depreciation at December 31, 2017 Net book value at December 31, 2017 Cost at January 1, 2016 Additions Disposals and other Cost at December 31, 2016 Accumulated depreciation at January 1, 2016 Disposals and other Depreciation Accumulated depreciation at December 31, 2016 Net book value at December 31, 2016 56 2017 Methanex Corporation Annual Report Buildings, plant installations and machinery Finance leases Other TOTAL $ 4,549,816 $ 206,260 $ 272,878 $ 5,028,954 98,780 328 4,648,924 1,752,540 (2,066) 205,843 1,956,317 7,667 1,846 215,773 18,557 – 15,370 33,927 5,001 (2,386) 275,493 140,388 (673) 11,905 151,620 111,448 (212) 5,140,190 1,911,485 (2,739) 233,118 2,141,864 $ 2,692,607 $ 181,846 $ 123,873 $ 2,998,326 Buildings, plant installations and machinery Finance leases Other TOTAL $ 4,521,835 $ 121,849 $ 204,483 $ 4,848,167 35,644 (7,663) 4,549,816 1,545,834 (945) 207,651 1,752,540 87,800 (3,389) 206,260 6,853 – 11,704 18,557 74,303 (5,908) 272,878 136,698 (5,908) 9,598 197,747 (16,960) 5,028,954 1,689,385 (6,853) 228,953 140,388 1,911,485 $ 2,797,276 $ 187,703 $ 132,490 $ 3,117,469 Included in finance leases as at December 31, 2017 are capitalized costs related to a methanol terminal and storage tanks in Geismar, Louisiana, an oxygen production facility in Trinidad, and two ocean going vessels. 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. 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 Cash and cash equivalents Other current assets1 Non-current assets Current liabilities1 Other long-term liabilities, including current maturities Net assets at 100% Net assets at 63.1% Long-term receivable from Atlas1 Investment in associate Consolidated statements of income for the years ended December 31 Revenue1 Cost of sales and depreciation and amortization Operating income Finance costs, finance income and other expenses Income tax expense Net earnings at 100% Earnings of associate at 63.1% Dividends received from associate 1 Includes related party transactions between Atlas and the Company (see note 22). Dec 31 2017 $ 8,361 $ 79,738 289,671 (41,388) (157,935) 178,447 112,600 76,322 Dec 31 2016 15,530 45,219 324,297 (24,783) (168,253) 192,010 121,158 76,244 $ 188,922 $ 197,402 2017 2016 $ 459,367 $ 213,533 (261,121) (145,126) 198,246 (11,170) (66,640) 120,436 75,995 84,553 $ 68,407 (12,771) (24,052) 31,584 19,930 47,325 $ b) Contingent liability: The Board of Inland Revenue of Trinidad and Tobago has issued assessments against Atlas in respect of the 2005 to 2011 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 from 2005 to 2019 related to methanol produced by Atlas. Atlas had partial relief from corporation income tax until late July 2014. The Company has lodged objections to the assessments. Based on the merits of the cases and legal interpretation, management believes its position should be sustained. 7. Other assets: As at Restricted cash Chile VAT receivable Investment in Carbon Recycling International Defined benefit pension plans (note 20) Other Dec 31 2017 27,863 25,456 4,502 6,650 13,555 78,026 Dec 31 2016 $ 35,386 23,406 4,502 5,862 9,628 $ 78,784 $ $ 2017 Methanex Corporation Annual Report 57 8. Long-term debt: As at Unsecured notes (i) 3.25% due December 15, 2019 (ii) 5.25% due March 1, 2022 (iii) 4.25% due December 1, 2024 (iv) 5.65% due December 1, 2044 Egypt limited recourse debt facilities Other limited recourse debt facilities Total long-term debt1 Less current maturities1 Dec 31 2017 Dec 31 2016 $ 348,060 $ 347,126 248,072 296,873 295,158 247,685 296,529 295,084 1,188,163 1,186,424 241,190 72,918 288,515 81,267 1,502,271 1,556,206 (55,905) (53,997) $ 1,446,366 $ 1,502,209 1 Long-term debt and current maturities are presented net of discounts and deferred financing fees of $17.8 million as at December 31, 2017 (2016 – $17.8 million). The Egypt limited recourse debt facilities have interest payable semi-annually with rates based on LIBOR plus a spread ranging from 0.9% to 1.6% per annum. Principal is paid in 24 semi-annual payments, which commenced in September 2010. 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. Other limited recourse debt facilities have remaining terms of two to four years with principal and interest payable quarterly with rates based on LIBOR plus a spread ranging from 0.75% to 2.5% per annum. Subsequent to the year ended December 31, 2017, the Company, through a 50% owned entity, issued other limited recourse debt for $86 million ($43 million Methanex share) bearing an interest rate of 5.35% due September 2033. The debt will be used to acquire two ocean going vessels. For the year ended December 31, 2017, non-cash accretion, on an effective interest basis, of deferred financing costs included in finance costs was $3.1 million (2016 – $3.0 million). The minimum principal payments for long-term debt in aggregate and for each of the five succeeding years are as follows: 2018 2019 2020 2021 2022 Thereafter Limited recourse debt facilities Unsecured notes $ 57,072 $ – $ 60,100 62,115 109,462 31,279 – 350,000 – – 250,000 600,000 Total 57,072 410,100 62,115 109,462 281,279 600,000 $ 320,028 $ 1,200,000 $ 1,520,028 The covenants governing the Company’s unsecured notes, which are specified in an indenture, apply to the Company and its subsidiaries, excluding entities which we control but do not fully own, 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 indenture also contains customary default provisions. The Company maintains a $300 million committed revolving credit facility with a syndicate of highly rated financial institutions that expires in December 2022. Significant covenants and default provisions under this facility include: i) ii) iii) the obligation to maintain an EBITDA to interest coverage ratio of greater than 2:1 calculated on a four-quarter trailing basis and a debt to capitalization ratio of less than or equal to 55%, both ratios calculated in accordance with definitions in the credit agreement that include adjustments related to the limited recourse subsidiaries, 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 the limited recourse subsidiaries, and 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 the limited recourse subsidiaries. 58 2017 Methanex Corporation Annual Report 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. The Egypt limited recourse debt facilities have covenants and default provisions that apply only to the Egypt entity, including restrictions on the incurrence of additional indebtedness and a requirement to fulfill certain conditions before the payment of cash or other shareholder distributions. Certain conditions had not been met, resulting in a restriction on shareholder distributions from the Egypt entity to December 31, 2017. Under amended terms reached in 2017, shareholder distributions are permitted starting in 2018 if the average gas deliveries over the prior 12 months are greater than 70% of gas requirements. The first $100 million of shareholder distributions must be matched with $100 million of principal repayments on the Egypt limited recourse debt facilities. As of December 31, 2017, the Egypt cash balance on a 100% ownership basis was $131 million. 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, 2017, management believes the Company was in compliance with all significant terms and default provisions related to long-term debt obligations. 9. Other long-term liabilities: As at Site restoration costs(a) Finance lease obligations(b) Share-based compensation liability (note 13) Cash flow hedges (note 18) Defined benefit pension plans (note 20) Other Less current maturities Dec 31 2017 Dec 31 2016 $ 33,975 $ 30,512 204,242 111,405 90,199 25,076 5,214 470,111 (65,226) 201,268 53,725 68,664 22,403 4,339 380,911 (29,720) $ 404,885 $ 351,191 a) 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, 2017, the total undiscounted amount of estimated cash flows required to settle the liabilities was $44.9 million (2016 – $41.1 million). The movement in the provision during the year is explained as follows: Balance at January 1 New or revised provisions Accretion expense Balance at December 31 2017 2016 $ 30,512 $ 29,892 2,823 640 51 569 $ 33,975 $ 30,512 b) Finance lease obligations: As at December 31, 2017, the Company has finance lease obligations related to a methanol terminal and storage tanks in Geismar, Louisiana, an oxygen production facility in Trinidad, and two ocean-going vessels. Total finance lease payments for 2017 of $30.6 million include an interest component of $23.7 million. 2017 Methanex Corporation Annual Report 59 Finance lease obligations are payable as follows: 2018 2019 2020 2021 2022 Thereafter 10. Expenses: For the years ended December 31 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 Lease payments Interest component Finance lease obligations $ 31,447 $ 31,826 32,213 32,608 33,010 236,772 23,549 22,727 21,756 20,612 19,271 85,719 $ 7,898 9,099 10,457 11,996 13,739 151,053 $ 397,876 $ 193,634 $ 204,242 2017 2016 $ 2,035,545 $ 1,533,915 $ $ 449,593 99,036 2,584,174 1,637,085 374,717 243,707 96,440 2,351,949 232,225 $ $ 408,893 59,675 2,002,483 1,140,551 351,609 204,762 77,507 1,774,429 228,054 $ 2,584,174 $ 2,002,483 For the year ended December 31, 2017 we recorded a share-based compensation expense of $78.8 million (2016 – $33.5 million), the majority of which is included in administrative expenses for the total expenses by function presentation above. 11. Finance costs: Finance costs are primarily comprised of interest on borrowings and finance lease obligations, amortization of deferred financing fees and accretion expense associated with site restoration costs. Finance costs were $95.0 million for the year ended December 31, 2017 (2016 – $90.1 million). 12. Net income (loss) per common share: 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. Outstanding TSARs may be settled in cash or common shares at the holder’s option and for purposes of calculating diluted net income (loss) 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 and denominator if the equity-settled method is determined to have a dilutive effect on diluted net income (loss) per common share as compared to the cash-settled method. The cash-settled method was more dilutive for the years ended December 31, 2017 and 2016, and no adjustment was required for the numerator or the denominator for TSARs. 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, 2017, stock options were considered dilutive resulting in an adjustment to the denominator. For the year ended December 31, 2016, the Company incurred a net loss attributable to Methanex shareholders and therefore exclusion of the stock options was more dilutive. 60 2017 Methanex Corporation Annual Report Basic and diluted net income (loss) per common share for the year ended December 31, 2017 was calculated using basic and diluted net income of $316.1 million (2016 – basic and diluted net loss of $12.5 million). A reconciliation of the denominator used for the purposes of calculating basic and diluted net income (loss) per common share is as follows: For the years ended December 31 Denominator for basic net income (loss) per common share Effect of dilutive stock options Denominator for diluted net income (loss) per common share 2017 2016 86,768,589 89,783,883 56,359 – 86,824,948 89,783,883 For the years ended December 31, 2017 and 2016, basic and diluted net income (loss) per common share attributable to Methanex shareholders were as follows: For the years ended December 31 Basic net income (loss) per common share Diluted net income (loss) per common share 2017 3.64 3.64 $ $ $ $ 2016 (0.14) (0.14) 13. 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, 2017, the Company had 3,953,471 common shares reserved for future grants of stock options and tandem share appreciation rights under the Company’s stock option plan. 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 after the date of grant. SARs and TSARs units outstanding at December 31, 2017 are as follows: SARs TSARs Number of units Exercise price USD Number of units Exercise price USD Outstanding at December 31, 2015 Granted Exercised Cancelled Outstanding at December 31, 2016 Granted Exercised Cancelled Expired 1,259,208 $ 375,500 (73,291) (49,932) 1,511,485 $ 167,600 (213,207) (10,801) (5,000) Outstanding at December 31, 2017 1,450,077 $ 44.48 34.59 27.43 49.77 42.68 50.15 32.03 50.18 25.22 45.11 2,108,965 $ 574,600 (212,505) (54,949) 2,416,111 $ 340,200 (710,616) (2,200) – 42.73 34.59 25.38 52.55 42.10 50.17 32.98 34.59 – 2,043,495 $ 46.62 2017 Methanex Corporation Annual Report 61 Information regarding the SARs and TSARs outstanding as at December 31, 2017 is as follows: Range of exercise prices SARs $25.97 to $35.51 $38.24 to $73.13 TSARs $25.97 to $35.51 $38.24 to $73.13 Units outstanding at December 31, 2017 Units exercisable at December 31, 2017 Weighted average remaining contractual life (years) Number of units outstanding Weighted average exercise price Number of units exercisable Weighted average exercise price 3.36 3.77 3.61 3.94 4.09 4.03 585,317 864,760 1,450,077 779,194 1,264,301 2,043,495 $ $ $ $ 32.94 53.35 45.11 33.67 54.60 46.62 345,629 609,687 955,316 401,049 794,658 1,195,707 $ $ $ $ 31.79 53.94 45.93 32.80 56.33 48.44 The fair value of each outstanding SARs and TSARs grant was estimated on December 31, 2017 using the Black-Scholes option pricing model with the following weighted average assumptions: Risk-free interest rate Expected dividend yield Expected life of SARs and TSARs (years) Expected volatility Expected forfeitures Weighted average fair value (USD per share) 2017 1.8% 2.0% 1.2 31% 0.2% 2016 1.0% 2.5% 1.4 41% 0.2% $ 19.02 $ 10.19 Compensation expense for SARs and TSARs is measured based on their fair value and is recognized over the vesting period. Changes in fair value in each period are recognized in net income (loss) for the proportion of the service that has been rendered at each reporting date. The fair value as at December 31, 2017 was $69.8 million compared with the recorded liability of $65.2 million. The difference between the fair value and the recorded liability of $4.6 million will be recognized over the weighted average remaining vesting period of approximately 1.5 years. For the year ended December 31, 2017, compensation expense related to SARs and TSARs included an expense in cost of sales and operating expenses of $45.1 million (2016 – $26.9 million). This included an expense of $37.8 million (2016 – $20.0 million) related to the effect of the change in the Company’s share price. 62 2017 Methanex Corporation Annual Report b) Deferred, restricted and performance share units: Deferred, restricted and performance share units outstanding as at December 31, 2017 are as follows: Outstanding at December 31, 2015 Granted Granted performance factor1 Granted in lieu of dividends Redeemed Cancelled Outstanding at December 31, 2016 Granted Performance factor impact on redemption1 Granted in lieu of dividends Redeemed Cancelled Outstanding at December 31, 2017 Number of deferred share units Number of restricted share units Number of performance share units 285,816 8,269 – 8,430 (51,498) – 251,017 10,452 – 5,669 (42,292) – 224,846 13,864 11,500 – 773 (7,488) – 18,649 8,100 – 613 (6,907) – 20,455 610,578 261,760 55,592 18,082 (355,415) (18,325) 572,272 163,500 (102,557) 14,383 (34,186) (8,517) 604,895 1 Performance share units have a feature where the ultimate number of units that vest are adjusted by a performance factor of the original grant as determined by the Company’s total shareholder return in relation to a predetermined target over the period to vesting. The performance factor is measured based on the weighted-average closing share price for the 90 calendar days on the NASDAQ Global Select Market immediately preceding the year end date that the performance share units vest. 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 (loss) for the proportion of the service that has been rendered at each reporting date. The fair value of deferred, restricted and performance share units as at December 31, 2017 was $55.9 million compared with the recorded liability of $46.1 million. The difference between the fair value and the recorded liability of $9.8 million will be recognized over the weighted average remaining vesting period of approximately 1.5 years. For the year ended December 31, 2017, compensation expense related to deferred, restricted and performance share units included in cost of sales and operating expenses was an expense of $33.0 million (2016 – $6.0 million). This included an expense of $29.9 million (2016 – $2.8 million) related to the effect of the change in the Company’s share price. c) Stock options: The exercise price of each stock option is equal to the quoted market price of the Company’s common shares at the date of the grant. Options granted have a maximum term of seven years with one-third of the options vesting each year after the date of grant. Common shares reserved for outstanding incentive stock options as at December 31, 2017 and 2016 are as follows: Outstanding at December 31, 2015 Granted Exercised Cancelled Expired Outstanding at December 31, 2016 Granted Exercised Cancelled Outstanding at December 31, 2017 Number of stock options Weighted average exercise price 448,507 75,500 (153,140) (14,100) (12,000) 344,767 31,400 (98,274) (15,358) 262,535 $ $ $ 30.52 34.59 9.80 44.04 6.33 40.91 50.17 30.90 52.43 45.09 2017 Methanex Corporation Annual Report 63 Information regarding the stock options outstanding as at December 31, 2017 is as follows: Options outstanding at December 31, 2017 Options exercisable at December 31, 2017 Weighted average remaining contractual life (years) 3.40 3.69 3.58 Number of stock options outstanding 103,850 158,685 262,535 Weighted average exercise price $ $ 33.08 52.95 45.09 Number of stock options exercisable 60,980 114,380 175,360 Weighted average exercise price $ $ 32.02 53.28 45.88 Range of exercise prices Options $25.97 to $35.51 $38.24 to $73.13 For the year ended December 31, 2017, compensation expense related to stock options was $0.5 million (2016 – $0.6 million). 14. 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, 2017 and 2016, revenues attributed to geographic regions, based on the location of customers, were as follows: Revenue 2017 2016 China Europe United States South Korea South America Canada Other Asia TOTAL $ 801,838 $ 608,668 $ 570,482 $ 347,896 $ 279,270 $ 167,436 $ 285,052 $ 3,060,642 $ 518,499 $ 403,879 $ 359,476 $ 257,658 $ 179,287 $ 109,706 $ 169,924 $ 1,998,429 As at December 31, 2017 and 2016, the net book value of property, plant and equipment by country was as follows: Property, plant and equipment United States Egypt New Zealand Trinidad Canada Chile Other TOTAL 2017 2016 $ 1,412,394 $ 720,397 $ 265,153 $ 155,525 $ 148,420 $ 107,495 $ 188,942 $2,998,326 $ 1,468,283 $ 742,446 $ 261,482 $ 176,256 $ 154,982 $ 108,065 $ 205,955 $ 3,117,469 15. Income and other taxes: a) Income tax expense: For the years ended December 31 Current tax recovery (expense): Current period before undernoted items Impact of Argentina gas settlement Adjustments to prior years Deferred tax recovery (expense): Origination and reversal of temporary differences Impact of Argentina gas settlement Derecognition of non-capital loss carryforwards Adjustments to prior years Change in U.S. tax rate Change in other jurisdictions tax rates Other 2017 2016 $ (85,287) $ (44,743) – (217) (85,504) 23,310 – – 200 (36,567) 734 2,039 (10,284) (7,800) (2,134) (54,677) 82,838 (3,575) (17,861) 1,667 – – 887 63,956 9,279 Total income tax recovery (expense) $ (95,788) $ 64 2017 Methanex Corporation Annual Report 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 (loss) before income taxes as follows: For the years ended December 31 Income (loss) before income taxes Deduct earnings of associate Canadian statutory tax rate Income tax recovery (expense) calculated at Canadian statutory tax rate Increase (decrease) in income tax recovery resulting from: Impact of income and losses taxed in foreign jurisdictions Derecognition of non-capital loss carryforwards Unrecognised loss carryforwards and temporary differences Impact of tax rate changes in the U.S. Impact of tax rate changes in other jurisdictions Impact of foreign exchange Other business taxes Adjustments to prior years Other Total income tax recovery (expense) 2017 2016 $ 470,885 $ (37,504) (75,995) 394,890 26.5% (104,646) 30,223 – 20,468 (36,567) 734 3,104 (4,105) (17) (4,982) (19,930) (57,434) 26.5% 15,220 34,857 (17,861) (6,468) – – (4,332) (5,404) (467) (6,266) $ (95,788) $ 9,279 c) Net deferred income tax liabilities: (i) The tax effect of temporary differences that give rise to deferred income tax liabilities and deferred income tax assets are as follows: As at Dec 31 2017 Dec 31 2016 Property, plant and equipment $ (403,705) $ (189,368) $ (214,337) $ (419,982) $ (197,931) $ (222,051) Net Deferred tax assets Deferred tax liabilities Net Deferred tax assets Deferred tax liabilities Repatriation taxes Other Non-capital loss carryforwards Share-based compensation Other (87,239) (11,670) – (3,740) (87,239) (7,930) (85,364) (19,956) – (4,981) (85,364) (14,975) (502,614) (193,108) (309,506) (525,302) (202,912) (322,390) 244,576 244,576 19,920 74,027 2,946 47,927 338,523 295,449 – 16,974 26,100 43,074 280,931 280,931 8,590 82,142 371,663 935 58,387 340,253 – 7,655 23,755 31,410 Net deferred income tax assets (liabilities) $ (164,091) $ 102,341 $ (266,432) $ (153,639) $ 137,341 $ (290,980) The Company recognizes deferred income tax assets to the extent that it is probable that the benefit of these assets will be realized. As at December 31, 2017, the Company had $110 million (2016 – $153 million) of unrecognized non-capital loss carryforwards in Egypt that expire in 2020 and 2021 and $384 million (2016 – $ 415 million) of deductible temporary differences in the United States that have not been recognized. 2017 Methanex Corporation Annual Report 65 (ii) Analysis of the change in deferred income tax assets and liabilities: Balance, January 1 $ (153,639) $ 137,341 $ (290,980) $ (223,757) $ 61,881 $ (285,638) 2017 2016 Net Deferred tax assets Deferred tax liabilities Net Deferred tax assets Deferred tax liabilities Deferred income tax recovery (expense) included in net income (loss) Impact of U.S. tax rate change in other comprehensive income Deferred income tax recovery (expense) included in other comprehensive income (loss) Other Balance, December 31 16. Supplemental cash flow information: (10,284) (34,517) 24,233 63,956 69,110 (5,154) (8,621) (8,621) 9,295 (842) 8,398 (260) – 897 (582) – – 6,597 (435) 6,364 (14) – 233 (421) $ (164,091) $ 102,341 $ (266,432) $ (153,639) $ 137,341 $ (290,980) a) Changes in non-cash working capital: Changes in non-cash working capital for the years ended December 31, 2017 and 2016 are as follows: For the years ended December 31 Changes in non-cash working capital: Trade and other receivables Inventories Prepaid expenses Trade, other payables and accrued liabilities, including long-term payables included in other long-term liabilities Adjustments for items not having a cash effect and working capital changes relating to taxes and interest paid Changes in non-cash working capital These changes relate to the following activities: Operating Financing Investing 2017 2016 $ (37,033) $ 4,747 (23,136) (5,702) 103,601 37,730 (89,445) (51,715) (49,368) – (2,347) $ $ (28,094) (1,286) 14,577 (10,056) (65,850) (75,906) (87,644) – 11,738 $ $ Changes in non-cash working capital $ (51,715) $ (75,906) The Company has reclassified the presentation of amounts relating to accrued distributions to non-controlling interests in Changes in non-cash working capital from Operating activities to Financing activities. The reclassification has been reflected in the comparative figures. b) Reconciliation of movements in liabilities to cash flows arising from financing activities: Balance at December 31, 2016 Changes from financing cash flows Repayment of long-term debt and financing fees Payment of finance lease liabilities Total changes from financing cash flows Liability-related other changes Finance costs New finance leases Other Total liability-related other changes Balance at December 31, 2017 66 2017 Methanex Corporation Annual Report Long term debt (note 8) Finance lease obligations (note 9) $ 1,556,206 $ 201,268 (56,997) – (56,997) 3,062 – – 3,062 1,502,271 $ $ $ $ – (6,880) (6,880) – 9,512 342 9,854 204,242 $ $ $ $ 17. Capital disclosures: The Company’s objectives in managing its liquidity and capital are to safeguard the Company’s ability to continue as a going concern, to provide financial capacity and flexibility to meet its strategic objectives, to provide an adequate return to shareholders commensurate with the level of risk and to return excess cash through a combination of dividends and share repurchases. As at Liquidity: Cash and cash equivalents Undrawn credit facilities Total liquidity Capitalization: Unsecured notes Limited recourse debt facilities, including current portion Total debt Non-controlling interests Shareholders’ equity Total capitalization Total debt to capitalization1 Net debt to capitalization2 $ $ $ Dec 31 2017 375,479 300,000 675,479 1,188,163 314,108 1,502,271 244,347 1,500,764 $ $ $ Dec 31 2016 223,890 300,000 523,890 1,186,424 369,782 1,556,206 208,515 1,596,835 $ 3,247,382 $ 3,361,556 46% 39% 46% 42% 1 Total debt (including 100% of Egypt limited recourse debt facilities) divided by total capitalization. 2 Total debt (including 100% of Egypt limited recourse debt facilities) less cash and cash equivalents divided by total capitalization less cash and cash equivalents. 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, 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. During the year, the Company renewed and extended a $300 million revolving credit facility for a five year term to December 2022. The undrawn credit facility is provided by highly rated financial institutions and is subject to certain financial covenants (note 8). 18. 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 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 when the underlying hedged transaction is recognized in earnings. 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. 2017 Methanex Corporation Annual Report 67 The following table provides the carrying value of each category of financial assets and liabilities and the related balance sheet item: As at Financial assets: Financial assets measured at fair value: Derivative instruments designated as cash flow hedges1 Financial assets not measured at fair value: Cash and cash equivalents Trade and other receivables, excluding tax receivable Project financing reserve accounts included in other assets Total financial assets2 Financial liabilities: Financial liabilities measured at fair value: Derivative instruments designated as cash flow hedges1 Financial liabilities not measured at fair value: Trade, other payables and accrued liabilities, excluding tax payable Long-term debt, including current portion Total financial liabilities Dec 31 2017 Dec 31 2016 $ $ $ – $ 7,024 375,479 527,084 27,863 223,890 479,272 35,386 930,426 $ 745,572 91,014 $ 68,664 528,182 1,502,271 449,213 1,556,206 $ 2,121,467 $ 2,074,083 1 The Geismar 2 and Medicine Hat 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 carrying amount of the financial assets represents the maximum exposure to credit risk at the respective reporting periods. As at December 31, 2017, 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 are 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. The fair value of all the Company’s derivative contracts includes an adjustment 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 separately in other comprehensive income as the forward element excluded from hedging relationships. Until settled, the fair value of the derivative financial instruments will fluctuate based on changes in commodity prices or foreign currency exchange rates. Natural gas forward contracts The Company has elected to manage 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. The Company has entered into forward contracts to manage its exposure to changes in natural gas prices for the Geismar 2 facility for 40% of its gas requirements to 2025, which it has designated as cash flow hedges. The Company has also entered into physical forward contracts to manage its exposure to changes in natural gas prices for the Medicine Hat facility over the period 2017 to 2022. The Company has designated contracts for the 2021 and 2022 periods as cash flow hedges for its highly probable forecast natural gas purchases in Medicine Hat. Other costs incurred to transport natural gas from the contracted delivery point, either Henry Hub or AECO, to the relevant production facility represent an insignificant portion of the overall underlying risk and are recognized as incurred outside of the hedging relationship. 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 hedge ineffectiveness has been recognized in 2017. 68 2017 Methanex Corporation Annual Report As at December 31, 2017, the Company had outstanding forward contracts designated as cash flow hedges with a notional amount of $473 million (2016 – $484 million) and a net negative fair value of $90.2 million (2016 – $ 61.9 million) included in other long-term liabilities. As at December 31, 2017, the forward contracts for the Geismar 2 facility had an average contract price of $3.74 per mmbtu (2016 – $3.68 per mmbtu) over the remaining eight year term, and for the forward contracts for the Medicine Hat facility has an average contract price of $1.96 per mmbtu. Forward exchange contracts The Company also designates as cash flow hedges forward exchange contracts to sell certain foreign currencies at a fixed U.S. dollar exchange rate to hedge its exposure to exchange rate fluctuations on certain foreign currency denominated transactions. 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 hedge ineffectiveness has been recognized in 2017. As at December 31, 2017, the Company had outstanding forward exchange contracts designated as cash flow hedges to sell euros at a fixed U.S. dollar exchange rate with a notional amount of 109 million euros (2016 – 92 million euros) and a negative fair value of $0.8 million included in current liabilities (2016 – positive fair value of $0.3 million included in current assets) . Fair value liabilities The table below shows net cash outflows for derivative hedging instruments including natural gas forward contracts and forward exchange contracts, excluding credit risk adjustments, based upon contracted payment dates. The amounts reflect the maturity profile of the fair value liabilities 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. As at Within one year 1-3 years 3-5 years More than 5 years $ Dec 31 2017 7,114 17,057 28,864 52,085 Dec 31 2016 $ – 8,481 18,962 56,029 $ 105,120 $ 83,472 The fair value of the Company’s derivative financial instruments as disclosed above are determined based on Bloomberg quoted market prices and confirmations received from counterparties, 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 counterparties, normally major financial institutions. 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 nil as at December 31, 2017 (2016 – $7.0 million). The carrying values of the Company’s financial instruments approximate their fair values, except as follows: As at December 31, 2017 December 31, 2016 Long-term debt excluding deferred financing fees $ 1,515,544 $ 1,561,392 $ 1,568,822 $ 1,538,543 Carrying value Fair value Carrying value Fair value 2017 Methanex Corporation Annual Report 69 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. 19. 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 related 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, 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 hedges in Geismar and Medicine Hat to manage its exposure to natural gas price risk. 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 long-term debt obligations. As at Fixed interest rate debt: Unsecured notes Variable interest rate debt: Egypt limited recourse debt facilities Other limited recourse debt facilities Dec 31 2017 Dec 31 2016 $ $ $ $ 1,188,163 1,188,163 241,190 72,918 314,108 $ $ $ $ 1,186,424 1,186,424 288,515 81,267 369,782 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 18) of approximately $84.0 million as of December 31, 2017 (2016 – $80.2 million). The fair value of variable interest rate debt fluctuates primarily with changes in credit spreads. For the variable interest rate debt, a 1% change in LIBOR would result in a change in annual interest payments of $3.2 million as of December 31, 2017 (2016 – $3.7 million). 70 2017 Methanex Corporation Annual Report 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 Canadian dollars, euros, Chinese yuan 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, 2017, the Company had a net working capital asset of $85.3 million in non U.S. dollar currencies (2016 – $75.3 million). Each 10% strengthening (weakening) of the U.S. dollar against these currencies would decrease (increase) the value of net working capital and pre-tax cash flows and earnings by approximately $8.5 million (2016 – $7.5 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, 2017, the Company had $375 million of cash and cash equivalents. In addition, the Company has an undrawn credit facility of $300 million provided by highly rated financial institutions that expires in December 2022. 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, 2017 Trade and other payables1 Finance lease obligations Long-term debt2 Cash flow hedges 1 Excludes tax and accrued interest. Carrying amount Contractual cash flows 1 year or less 1-3 years 3-5 years More than 5 years $ 519,352 $ 519,352 $ 519,352 $ – $ – $ – 204,242 397,876 1,502,271 2,178,011 91,014 105,120 31,447 121,689 7,114 64,039 586,091 17,057 65,618 471,831 28,864 236,772 998,400 52,085 $ 2,316,879 $ 3,200,359 $ 679,602 $ 667,187 $ 566,313 $ 1,287,257 2 Contractual cash flows include contractual interest payments related to debt obligations. Interest rates on variable rate debt are based on prevailing rates as at December 31, 2017. 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 2017 Methanex Corporation Annual Report 71 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, 2017 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. 20. 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 Accrued benefit obligations: Balance, beginning of year Current service cost Past service cost Interest cost on accrued benefit obligations Benefit payments Settlements Actuarial loss Foreign exchange 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 Dec 31 2017 Dec 31 2016 $ 60,771 $ 55,966 1,879 812 2,242 (5,280) – 166 4,803 65,393 44,230 1,522 1,970 (5,280) – 1,330 3,219 46,991 18,402 – 1,677 – 2,269 (2,570) – 2,393 1,036 60,771 40,286 1,553 2,722 (2,570) – 2,345 (106) 44,230 16,541 – $ 18,402 $ 16,541 The Company has an unfunded retirement obligation of $25.1 million as at December 31, 2017 (2016 – $22.4 million) for its employees in Chile that will be funded at retirement in accordance with Chilean law. The accrued benefit for the unfunded retirement arrangement in Chile is paid when an employee leaves the Company in accordance with plan terms and Chilean regulations. The Company estimates that it may make benefit payments based on actuarial assumptions related to the unfunded retirement obligation in Chile of $5.1 million in 2018. Actual benefit payments in future periods will fluctuate based on employee retirements. 72 2017 Methanex Corporation Annual Report The Company has a net funded retirement asset of $6.6 million as at December 31, 2017 (2016 – $5.7 million) for certain employees and retirees in Canada and a net funded retirement asset of $0.1 million as at December 31, 2017 (2016 – $0.2 million) in Europe. The Company estimates that it will make additional contributions relating to its defined benefit pension plan in Canada of $0.6 million in 2018. 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 and Chile, 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 10 years. The Company’s net defined benefit pension plan expense charged to the consolidated statements of income for the years ended December 31, 2017 and 2016 is as follows: For the years ended December 31 Net defined benefit pension plan expense: Current service cost Past service cost Net interest cost Cost of settlement 2017 2016 $ 1,879 $ 1,677 812 720 – – 715 – $ 3,411 $ 2,392 The Company’s current year actuarial gains (losses), recognized in the consolidated statements of comprehensive income (loss) for the years ended December 31, 2017 and 2016, are as follows: For the years ended December 31 Actuarial gain (loss) Minimum funding requirement Actuarial gain (loss), net 2017 564 – 564 $ $ 2016 (77) – (77) $ $ 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, 2016 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, 2019. The discount rate is the most significant actuarial assumption used in accounting for the defined benefit pension plans. As at December 31, 2017, the weighted average discount rate for the defined benefit obligation was 3.7% (2016 - 3.7%). A decrease of 1% in the weighted average discount rate at the end of the reporting period, while holding all other assumptions constant, would result in an increase to the defined benefit obligation of approximately $6.3 million. The asset allocation for the defined benefit pension plan assets as at December 31, 2017 and 2016 is as follows: As at Equity securities Debt securities Cash and other short-term securities Total Dec 31 2017 Dec 31 2016 46% 29% 25% 100% 49% 27% 24% 100% The fair values of the above equity and debt instruments are determined based on quoted market prices in active markets whereas the fair values 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: The Company has defined contribution pension plans. The Company’s funding obligations under the defined contribution pension plans are limited to making regular payments to the plans, based on a percentage of employee earnings. Total net pension expense for the defined contribution pension plans charged to operations during the year ended December 31, 2017 was $8.1 million (2016 - $7.6 million). 2017 Methanex Corporation Annual Report 73 21. 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 up to 2035. The minimum estimated commitment under these contracts, except as noted below, is as follows: As at December 31, 2017 2018 2019 2020 2021 2022 Thereafter $ 473,927 $ 371,167 $ 306,400 $ 308,338 $ 245,989 $ 1,300,609 In the above table, the Company has included natural gas commitments at the contractual volume and prices. b) Argentina natural gas supply contracts: Since June 2007, the Company’s natural gas suppliers from Argentina have curtailed all gas supply to the Company’s plants in Chile pursuant to long-term gas supply agreements. The Company has not received natural gas under these long-term agreements since 2007 and therefore potential future purchase obligations have been excluded from the table above. c) Operating lease commitments: The Company has future minimum lease payments under operating leases relating primarily to vessel charter, terminal facilities, office space, equipment and other operating lease commitments as follows: As at December 31, 2017 2018 $ 90,820 2019 $ 90,035 2020 $ 56,973 2021 $ 38,982 2022 $ 37,858 Thereafter $ 163,822 The minimum lease payments relate to the right of use of the leased asset and exclude non-lease elements such as the reimbursement of operating costs. For the year ended December 31, 2017, the Company recognized as an expense $181.4 million (2016 – expense of $165.1 million) relating to operating lease payments. The expense recognized includes amounts related to leased assets and the reimbursement of operating costs for time charter vessels. d) Leased assets not yet in service: The Company has future minimum lease payments under operating leases related to two time charter agreements for vessels which are currently under construction and expected to be delivered in 2019. The minimum lease payments under these leases have been excluded from the operating lease commitments table above as the contracts contain certain cancellation features which are dependent on the delivery of the vessels. Once delivered, these vessels will have a total minimum commitment of approximately $80 million per vessel over a 15 year life. e) Purchased methanol: The Company has marketing rights for 100% of the production from its jointly owned plants (the Atlas plant in Trinidad in which it has a 63.1% interest and the plant in Egypt in which it has a 50% interest), which results in purchase commitments of an additional 1.3 million tonnes per year of methanol offtake supply when these plants operate at capacity. As at December 31, 2017, the Company also had commitments to purchase methanol from other suppliers for approximately 0.8 million tonnes for 2018 and 1.5 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. 74 2017 Methanex Corporation Annual Report 22. Related parties: The Company has interests in significant subsidiaries and joint ventures as follows: Name Significant subsidiaries: Methanex Asia Pacific Limited Methanex Europe NV Methanex Methanol Company, LLC Egyptian Methanex Methanol Company S.A.E. (“Methanex Egypt”) Methanex Chile S.A. Methanex New Zealand Limited Methanex Trinidad (Titan) Unlimited Methanex U.S.A. LLC Methanex Louisiana LLC Waterfront Shipping Company Limited2 Significant joint ventures: Atlas Methanol Company Unlimited1 Country of incorporation Principal activities Interest% Dec 31 2017 Dec 31 2016 Hong Kong Marketing & distribution Belgium Marketing & distribution United States Marketing & distribution Egypt Chile Production Production New Zealand Production Trinidad Production United States Production United States Production Cayman Islands Shipping 100% 100% 100% 50% 100% 100% 100% 100% 100% 100% 100% 100% 100% 50% 100% 100% 100% 100% 100% 100% Trinidad Production 63.1% 63.1% 1 Summarized financial information for the group’s investment in Atlas is disclosed in note 6. 2 Waterfront Shipping Company Limited has a controlling interest in multiple ocean going vessels owned through less than wholly-owned entities as disclosed in note 23. 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, 2017 of $459 million (2016 – $214 million) is a related party transaction as the Company has marketing rights for 100% of the methanol produced by Atlas. Balances outstanding with Atlas as at December 31, 2017 and provided in the summarized financial information in note 6 include receivables owing from Atlas to the Company of $13 million (2016 – $7 million), and payables to Atlas of $98 million (2016 – $55 million). The Company has total loans outstanding to Atlas as at December 31, 2017 of $76 million (2016 – $76 million) which are unsecured and due at maturity. Remuneration of non-management directors and senior management, which includes the members of the executive leadership team, is as follows: For the years ended December 31 Short-term employee benefits Post-employment benefits Other long-term employee benefits Share-based compensation expense1 Total 1 Balance includes realized and unrealized gains (losses) from share-based compensation awards granted. 2017 2016 $ 5,214 $ 5,315 583 43 650 47 40,668 16,172 $ 46,508 $ 22,184 2017 Methanex Corporation Annual Report 75 23. 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 2017 Dec 31 2016 Current assets Non-current assets Current liabilities Non-current liabilities Net assets Carrying amount of Methanex non-controlling interests Methanex Egypt Other1 Total Methanex Egypt Other1 Total $ 248,032 $ 27,240 $ 275,272 $ 155,422 $ 12,123 $ 167,545 720,356 (231,259) (293,184) 443,945 105,375 (12,489) (76,090) 44,036 825,731 (243,748) (369,274) 487,981 746,202 (177,088) (339,369) 385,167 116,314 (14,622) (84,540) 29,275 862,516 (191,710) (423,909) 414,442 $ 216,599 $ 27,748 $ 244,347 $ 188,099 $ 20,416 $ 208,515 For the years ended December 31 2017 Methanex Egypt Other1 Total Methanex Egypt 2016 Other1 Total Revenue $ 285,017 $ 32,094 $ 317,111 $ 111,728 $ 26,148 $ 137,876 Net and total comprehensive income (loss) 65,241 6,981 72,222 (79,963) 4,781 (75,182) Net and total comprehensive income (loss) allocated to Methanex non-controlling interests Equity contributions by non-controlling interests Distributions paid and accrued to non-controlling interests 55,470 – (26,970) $ $ $ $ 58,962 (18,069) 2,389 (15,680) $ $ 8,170 (31,300) $ $ – (23,264) $ $ 25 (1,410) $ $ 25 (24,674) 3,492 8,170 (4,330) 2017 For the years ended December 31 Cash flows from (used in) operating activities Cash flows from (used in) financing activities Cash flows from (used in) investing activities Methanex Egypt Other1 Total Methanex Egypt 2016 Other1 Total $ 131,175 $ 19,538 $ 150,713 $ (23,992) $ 17,718 $ (6,274) (27,365) (3,250) (30,615) (24,929) 55,891 30,962 $ (18,839) $ (605) $ (19,444) $ (4,637) $ (70,516) $ (75,153) 1 Other is comprised of multiple ocean going vessels controlled by Waterfront Shipping Company Limited through less than wholly-owned entities. The Company has reclassified the presentation of amounts relating to accrued distributions to Methanex Egypt in Changes in non-cash working capital from Operating activities to Financing activities. The reclassification has been reflected in the comparative figures. 76 2017 Methanex Corporation Annual Report Executive Leadership Team John Floren President and Chief Executive Officer Brad Boyd Senior Vice President, Corporate Resources Ian Cameron Senior Vice President, Finance and Chief Financial Officer Kevin Henderson Senior Vice President, Manufacturing Mike Herz Senior Vice President, Corporate Development Vanessa James Senior Vice President, Global Marketing and Logistics Board of Directors Thomas Hamilton Chairman of the Board Board member since May 2007 John Floren President and CEO of Methanex Corporation Board member since January 2013 Bruce Aitken Member of the Public Policy and Responsible Care Committees Board Member since July 2004 Douglas Arnell Chair of the Human Resources Committee Member of the Corporate Governance and Public Policy Committees Board member since October 2016 Howard Balloch Chair of the Public Policy Committee Member of the Audit, Finance & Risk Committee Board member since December 2004 Phillip Cook Chair of the Corporate Governance Committee Member of the Human Resources Committee Board member since May 2006 Robert Kostelnik Chair of the Responsible Care Committee Member of the Corporate Governance Committee Board member since September 2008 Douglas Mahaffy Member of the Corporate Governance and Human Resources Committees Board member since May 2006 A. Terence Poole Chair of the Audit, Finance & Risk Committee Member of the Public Policy Committee Board member since September 2003 and from February 1994 to June 2003 Janice Rennie Member of the Human Resources and Audit, Finance & Risk Committees Board member since May 2006 Margaret Walker Member of the Human Resources and Responsible Care Committees Board member since April 2015 Benita Warmbold Member of the Audit, Finance & Risk and Responsible Care Committees Board member since February 2016 Corporate Information Head Office Methanex Corporation 1800 Waterfront Centre 200 Burrard Street Vancouver, BC V6C 3M1 Tel 604 661 2600 Fax 604 661 2676 Toll Free 1 800 661 8851 Within North America Web Site www.methanex.com Sales Inquiries: sales@methanex.com Transfer Agent AST Trust Company (Canada) acts as transfer agent and registrar for Methanex stock and maintains all primary shareholder records. All inquiries regarding share transfer requirements, lost certificates, changes of address, or the elimination of duplicate mailings should be directed to AST Trust Company (Canada) at: 1 800 387 0825 Toll Free within North America Investor Relations Inquiries Tel 604 661 2600 IR@methanex.com Annual General Meeting The Annual General Meeting will be held at the Vancouver Convention Centre – East Building in Vancouver, British Columbia on Thursday, April 26, 2018 at 10:30 a.m. (Pacific Time). Shares Listed Toronto Stock Exchange – MX NASDAQ Global Select Market – MEOH Annual Information Form (AIF) The corporation’s AIF can be found online at www.sedar.com. A copy of the AIF can also be obtained by contacting our head office.