Methanex Reports Higher EBITDA and Earnings in the Third Quarter

Marketwired

VANCOUVER, BRITISH COLUMBIA--(Marketwired - Oct 30, 2013) - For the third quarter of 2013, Methanex Corporation (MX.TO)(MEOH) reported Adjusted EBITDA1 of $184 million and Adjusted net income1 of $117 million ($1.22 per share on a diluted basis1). This compares with Adjusted EBITDA1 of $157 million and Adjusted net income1 of $99 million ($1.02 per share on a diluted basis1) for the second quarter of 2013.

John Floren, President and CEO of Methanex commented, "During the third quarter, methanol market conditions remained healthy and pricing increased across all regions, contributing to higher EBITDA and earnings. We are making solid progress and remain on track to increase our operating capacity to 8 million tonnes by 2016. We recently announced the completion of a number of key growth initiatives in New Zealand, Canada and Chile that will add up to one million tonnes of annual operating capacity. In addition, our projects to relocate two production facilities from Chile to Louisiana are scheduled to add one million tonnes of operating capacity by the end of 2014 and a further one million tonnes in early 2016."

Mr. Floren added, "We also recently announced the sale of a 10% equity interest in the Egypt methanol facility to Arab Petroleum Investments Corporation (APICORP). This is a win/win transaction that aligns with APICORP's investment strategy and signals confidence in the long term prospects of the Egyptian economy. For us, it generates additional capital to help fund our growth initiatives. In Egypt, we have built a world-class methanol facility, operated by a professional staff of highly qualified Egyptians. We continue to remain optimistic regarding our Egyptian operations and its ability to create value for shareholders today and well into the future.

Mr. Floren concluded, "This is an exciting time for our business. Robust demand for methanol led by energy applications, particularly in the areas of fuel blending and methanol-to-olefins, is continuing to support healthy market conditions. Our existing growth projects have the ability to add capacity when new market supply is limited and offer significant upside to our earnings and cash flows. With almost $700 million of cash on hand, an undrawn credit facility, a robust balance sheet and strong cash flow generation, we are well positioned to grow our business and deliver on our commitment to return excess cash to shareholders."

A conference call is scheduled for October 31, 2013 at 12:00 noon ET (9:00 am PT) to review these third quarter results. To access the call, dial the Conferencing operator ten minutes prior to the start of the call at (416) 340-2218, or toll free at (866) 226-1793. A playback version of the conference call will be available until November 21, 2013 at (905) 694-9451, or toll free at (800) 408-3053. The passcode for the playback version is 4459948. Presentation slides summarizing Q3-13 results and a simultaneous audio-only webcast of the conference call can be accessed from our website at www.methanex.com. The webcast will be available on the website for three weeks following the call.

Methanex is a Vancouver-based, publicly traded company and is the world's largest supplier of methanol to major international markets. Methanex shares are listed for trading on the Toronto Stock Exchange in Canada under the trading symbol "MX" and on the NASDAQ Global Market in the United States under the trading symbol "MEOH".

FORWARD-LOOKING INFORMATION WARNING

This Third Quarter 2013 press release contains forward-looking statements with respect to us and the chemical industry. Refer to Forward-Looking Information Warning in the attached Third Quarter 2013 Management's Discussion and Analysis for more information.

1 Adjusted EBITDA, Adjusted net income and Adjusted net income per common share are non-GAAP measures which do not have any standardized meaning prescribed by GAAP. These measures represent the amounts that are attributable to Methanex Corporation shareholders and are calculated by excluding the mark-to-market impact of share-based compensation as a result of changes in our share price and items considered by management to be non-operational. Refer to the Additional Information - Supplemental Non-GAAP Measures section of the attached Interim Report for the three months ended September 30, 2013 for reconciliations to the most comparable GAAP measures.

Interim Report for the Three Months Ended September 30, 2013

At October 30, 2013 the Company had 95,687,579 common shares issued and outstanding and stock options exercisable for 2,430,984 additional common shares.

Share Information

Methanex Corporation's common shares are listed for trading on the Toronto Stock Exchange under the symbol MX and on the Nasdaq Global Market under the symbol MEOH.

Transfer Agents & Registrars
CIBC Mellon Trust Company
320 Bay Street
Toronto, Ontario Canada M5H 4A6
Toll free in North America: 1-800-387-0825

Investor Information

All financial reports, news releases and corporate information can be accessed on our website at www.methanex.com.

Contact Information
Methanex Investor Relations
1800 - 200 Burrard Street
Vancouver, BC Canada V6C 3M1
E-mail: invest@methanex.com
Methanex Toll-Free: 1-800-661-8851

THIRD QUARTER MANAGEMENT'S DISCUSSION AND ANALYSIS

Except where otherwise noted, all currency amounts are stated in United States dollars.

FINANCIAL AND OPERATIONAL HIGHLIGHTS

  • A reconciliation from net income attributable to Methanex shareholders to Adjusted net income1 and the calculation of Adjusted net income per common share1 is as follows:
Three Months Ended Nine Months Ended
($ millions except number of shares and per share amounts) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Net income (loss) attributable to Methanex shareholders $ 87 $ 54 $ (3 ) $ 201 $ 72
Mark-to-market impact of share-based compensation, net of tax 30 9 - 67 6
Geismar project relocation expenses, net of tax - 22 39 22 41
Write-off of oil and gas rights, net of tax - 14 - 14 -
Adjusted net income 1 $ 117 $ 99 $ 36 $ 304 $ 119
Diluted weighted average shares outstanding (millions) 97 96 94 96 95
Adjusted net income per common share 1 $ 1.22 $ 1.02 $ 0.38 $ 3.16 $ 1.26
  • We recorded Adjusted EBITDA1 of $184 million for the third quarter of 2013 compared with $157 million for the second quarter of 2013. The increase in Adjusted EBITDA1 was primarily due to an increase in average realized price to $438 per tonne for the third quarter of 2013 from $425 per tonne for the second quarter of 2013.

  • Production for the third quarter of 2013 was 1,035,000 tonnes compared with 1,052,000 tonnes for the second quarter of 2013. Refer to the Production Summary section.

  • Sales of Methanex-produced methanol were 1,040,000 tonnes in the third quarter of 2013 compared with 1,021,000 in the second quarter of 2013.

  • We recently restarted the 530,000 tonne Waitara Valley facility and completed a debottlenecking project at the Motunui facilities. After completing a planned major refurbishment at the Motunui 2 facility in the fourth quarter of 2013, we expect our New Zealand operations to be able to produce at the site's full annual production capacity of up to 2.4 million tonnes, depending on natural gas composition. We also completed the project to debottleneck the Medicine Hat facility which increases the site's annual production capacity by 90,000 tonnes.

  • The relocation of two production facilities from Chile to Geismar, Louisiana remains on track with Geismar I scheduled to be operational by the end of 2014 and Geismar II by early 2016.

  • During the third quarter of 2013, we paid a $0.20 per share dividend to shareholders for a total of $19 million.

  • On October 22, 2013, we announced that we had reached an agreement to sell a 10% equity interest in EMethanex for $110 million. Subject to the completion of certain conditions precedent, we expect the sale to be completed in the fourth quarter of 2013.

1 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 Additional Information - Supplemental Non-GAAP Measures section for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.

This Third Quarter 2013 Management's Discussion and Analysis ("MD&A") dated October 30, 2013 for Methanex Corporation ("the Company") should be read in conjunction with the Company's condensed consolidated interim financial statements for the period ended September 30, 2013 as well as the 2012 Annual Consolidated Financial Statements and MD&A included in the Methanex 2012 Annual Report. Unless otherwise indicated, the financial information presented in this interim report is prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB). The Methanex 2012 Annual Report and additional information relating to Methanex is available on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.

Effective January 1, 2013, we adopted new IFRS standards related to consolidation and joint arrangement accounting. Under these new standards, our 63.1% interest in the Atlas entity, which was previously proportionately consolidated in our financial statements, is accounted for using the equity method. This change has been applied retrospectively. As a result, amounts related to Atlas are no longer included in individual line items in our consolidated financial statements and the net assets and net earnings are presented separately. For purposes of analyzing our consolidated financial results in this MD&A, the Adjusted EBITDA from our 63.1% interest in the Atlas entity is included in Adjusted EBITDA.

FINANCIAL AND OPERATIONAL DATA

Three Months Ended Nine Months Ended
($ millions, except per share amounts and where noted) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Production (thousands of tonnes) (attributable to Methanex shareholders) 1,035 1,052 1,025 3,150 3,004
Sales volumes (thousands of tonnes):
Methanex-produced methanol (attributable to Methanex shareholders) 1,040 1,021 1,053 3,085 2,980
Purchased methanol 715 749 641 2,052 1,901
Commission sales 1 237 242 205 698 679
Total sales volumes 1,992 2,012 1,899 5,835 5,560
Methanex average non-discounted posted price ($ per tonne) 2 502 494 433 490 440
Average realized price ($ per tonne) 3 438 425 373 424 380
Adjusted EBITDA (attributable to Methanex shareholders) 4 184 157 104 491 310
Cash flows from operating activities 181 125 122 424 336
Adjusted net income (attributable to Methanex shareholders) 4 117 99 36 304 119
Net income (loss) attributable to Methanex shareholders 87 54 (3 ) 201 72
Adjusted net income per common share (attributable to Methanex shareholders) 4 1.22 1.02 0.38 3.16 1.26
Basic net income (loss) per common share (attributable to Methanex shareholders) 0.91 0.57 (0.03 ) 2.12 0.77
Diluted net income (loss) per common share (attributable to Methanex shareholders) 0.90 0.56 (0.03 ) 2.09 0.76
Common share information (millions of shares):
Weighted average number of common shares 95 95 94 95 94
Diluted weighted average number of common shares 97 96 94 96 95
Number of common shares outstanding, end of period 96 95 94 96 94
1 Commission sales represent volumes marketed on a commission basis related to the 36.9% of the Atlas methanol facility and 40% of the Egypt methanol facility that we do not own.
2 Methanex average non-discounted posted price represents the average of our non-discounted posted prices in North America, Europe and Asia Pacific weighted by sales volume. Current and historical pricing information is available at http://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 volumes of Methanex-produced (attributable to Methanex shareholders) and purchased methanol.
4 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 Additional Information - Supplemental Non-GAAP Measures section for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.

PRODUCTION SUMMARY

Q3 2013 Q2 2013 Q3 2012 YTD
Q3 2013
YTD
Q3 2012
(thousands of tonnes) Capacity 1 Prod-
uction
Prod-
uction
Prod-
uction
Prod-
uction
Prod-
uction
New Zealand 2 608 349 361 346 1,019 730
Atlas (Trinidad) (63.1% interest) 281 254 201 255 703 646
Titan (Trinidad) 218 128 169 186 478 597
Egypt (60% interest) 190 168 163 62 464 428
Medicine Hat (Canada) 3 140 130 129 117 390 349
Chile I and IV 450 6 29 59 96 254
Geismar I and II (Louisiana, USA) 4 - - - - - -
1,887 1,035 1,052 1,025 3,150 3,004
1 The production capacity of our facilities may be higher than original nameplate capacity as, over time, these figures have been adjusted to reflect ongoing operating efficiencies. Actual production for a facility in any given year may be higher or lower than annual production capacity due to a number of factors, including natural gas composition or the age of the facility's catalyst.
2 The annual production capacity of New Zealand represents the two Motunui facilities and the Waitara Valley facility (refer to the New Zealand section below).
3 In September 2013, we completed a debottlenecking project which increased the annual production capacity of the Medicine Hat facility by 90,000 tonnes to 560,000 tonnes.
4 We are relocating two idle Chile facilities to Geismar, Louisiana. The Geismar I facility is scheduled to be operational by the end of 2014 and the Geismar II facility in early 2016.

New Zealand

Our New Zealand methanol facilities produced 349,000 tonnes of methanol in the third quarter of 2013 compared with 361,000 tonnes in the second quarter of 2013. We recently restarted the 530,000 tonne Waitara Valley facility and completed a debottlenecking project at the Motunui facilities. After completing a planned major refurbishment at the Motunui 2 facility in the fourth quarter of 2013, we expect our New Zealand operations to be able to produce at the site's full annual production capacity of up to 2.4 million tonnes, depending on natural gas composition.

Trinidad

In Trinidad, we own 100% of the Titan facility with an annual production capacity of 875,000 tonnes and have a 63.1% interest in the Atlas facility with an annual production capacity of 1,125,000 tonnes (63.1% interest). The Titan facility produced 128,000 tonnes in the third quarter of 2013 compared with 169,000 tonnes in the second quarter of 2013 and the Atlas facility produced 254,000 tonnes in the third quarter of 2013 compared with 201,000 tonnes in the second quarter of 2013. The Titan facility underwent a 30-day planned turnaround during the third quarter of 2013 and returned to normal operation in early October.

We continue to experience some natural gas curtailments to our Trinidad facilities due to a mismatch between upstream commitments to supply the Natural Gas Company of Trinidad and Tobago (NGC) and downstream demand from NGC's customers, which becomes apparent when an upstream supplier has a technical issue or planned maintenance that reduces gas delivery. We are engaged with key stakeholders to find a solution to this issue, but in the meantime expect to continue to experience gas curtailments to the Trinidad site.

Egypt

The Egypt methanol facility produced 168,000 tonnes (60% interest) in the third quarter of 2013 compared with 163,000 tonnes in the second quarter of 2013. The Egypt facility experienced an unplanned outage during the third quarter of 2013 which resulted in lost production of approximately 15,000 tonnes.

The Egypt facility has experienced periodic natural gas supply restrictions since mid-2012 which have resulted in production below full capacity. This situation may persist in the future and become more acute during the summer months when electricity demand is at its peak. Refer to our 2012 Annual Report for further details.

On October 22, 2013, we announced the sale of a 10% equity interest in the Egypt methanol facility to Arab Petroleum Investments Corporation (APICORP) for $110 million. Subject to the completion of certain conditions precedent, we expect the sale to be completed in the fourth quarter of 2013.

Medicine Hat, Canada

During the third quarter of 2013, we produced 130,000 tonnes at our Medicine Hat facility compared with 129,000 tonnes during the second quarter of 2013. In September 2013, we increased the annual production capacity of the Medicine Hat facility by 90,000 tonnes through the completion of a debottlenecking project that added distillation capacity to the site.

Chile

After idling our Chile operations in the second quarter of 2013 as a result of insufficient natural gas feedstock during the southern hemisphere winter, we restarted the Chile I facility in late September 2013. Our Chile operations produced 6,000 tonnes during the third quarter of 2013, supported by natural gas supplies from both Chile and Argentina through a tolling arrangement.

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.

Geismar, Louisiana

We are in the process of relocating two idle Chile facilities to Geismar, Louisiana (Geismar I and Geismar II). The 1.0 million tonne Geismar I facility is scheduled to be operational by the end of 2014 and the 1.0 million tonne Geismar II facility in early 2016. During the third quarter of 2013, we incurred $67 million of capital expenditures related to these projects, excluding capitalized interest. Remaining capital expenditures for these projects are estimated to be $780 million.

FINANCIAL RESULTS

For the third quarter of 2013 we recorded Adjusted EBITDA of $184 million and Adjusted net income of $117 million ($1.22 per share on a diluted basis). This compares with Adjusted EBITDA of $157 million and Adjusted net income of $99 million ($1.02 per share on a diluted basis) for the second quarter of 2013.

For the third quarter of 2013, we reported net income attributable to Methanex shareholders of $87 million ($0.90 per share on a diluted basis) compared with net income attributable to Methanex shareholders for the second quarter of 2013 of $54 million ($0.56 income per share on a diluted basis).

Effective January 1, 2013, we adopted new IFRS standards related to consolidation and joint arrangement accounting. Under these new standards, our 63.1% interest in the Atlas entity, which was previously proportionately consolidated in our financial statements, is accounted for using the equity method. This change has been applied retrospectively. As a result, amounts related to Atlas are no longer included in individual line items in our consolidated financial statements and the net assets and net earnings are presented separately. For purposes of analyzing our consolidated financial results in this MD&A, the Adjusted EBITDA from our 63.1% interest in the Atlas entity is included in Adjusted EBITDA. 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 and excludes amounts related to Atlas.

We calculate Adjusted EBITDA and Adjusted net income by including amounts related to our equity share of the Atlas (63.1% interest) and Egypt (60% interest) facilities and by excluding the mark-to-market impact of share-based compensation as a result of changes in our share price and items which are considered by management to be non-operational. Refer to the Additional Information - Supplemental Non-GAAP Measures section for a further discussion on how we calculate these measures.

A reconciliation from net income attributable to Methanex shareholders to Adjusted net income and the calculation of Adjusted net income per common share is as follows:

Three Months Ended Nine Months Ended
($ millions except number of shares and per share amounts) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Net income (loss) attributable to Methanex shareholders $ 87 $ 54 $ (3 ) $ 201 $ 72
Mark-to-market impact of share-based compensation, net of tax 30 9 - 67 6
Geismar project relocation expenses, net of tax - 22 39 22 41
Write-off of oil and gas rights, net of tax - 14 - 14 -
Adjusted net income 1 $ 117 $ 99 $ 36 $ 304 $ 119
Diluted weighted average shares outstanding (millions) 97 96 94 96 95
Adjusted net income per common share 1 $ 1.22 $ 1.02 $ 0.38 $ 3.16 $ 1.26
1 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 Additional Information - Supplemental Non-GAAP Measures section for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.

We review our financial results by analyzing changes in Adjusted EBITDA, mark-to-market impact of share-based compensation, depreciation and amortization, finance costs, finance income and other expenses and income taxes. A summary of our consolidated statements of income is as follows:

Three Months Ended Nine Months Ended
($ millions) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Consolidated statements of income:
Revenue $ 758 $ 733 $ 608 $ 2,143 $ 1,875
Cost of sales and operating expenses, excluding mark-to-market impact of share-based compensation (565 ) (571 ) (507 ) (1,633 ) (1,528 )
Adjusted EBITDA of associate (Atlas) 1 15 18 15 42 24
208 180 116 552 371
Comprised of:
Adjusted EBITDA (attributable to Methanex shareholders) 2 184 157 104 491 310
Attributable to non-controlling interests 24 23 12 61 61
208 180 116 552 371
Mark-to-market impact of share-based compensation (33 ) (9 ) - (73 ) (7 )
Depreciation and amortization (29 ) (29 ) (40 ) (88 ) (114 )
Geismar project relocation expenses and charges - (34 ) (61 ) (34 ) (65 )
Write-off of oil and gas rights - (17 ) - (17 ) -
Earnings of associate, excluding amount included in Adjusted EBITDA 1 (9 ) (12 ) (9 ) (29 ) (24 )
Finance costs (14 ) (15 ) (15 ) (44 ) (49 )
Finance income and other expenses 2 3 (4 ) 3 (2 )
Income tax expense (24 ) (1 ) 15 (37 ) (9 )
Net income $ 101 $ 66 $ 2 $ 233 $ 101
Net income (loss) attributable to Methanex shareholders $ 87 $ 54 $ (3 ) $ 201 $ 72
1 Earnings of associate has been divided into an amount included in Adjusted EBITDA and an amount excluded from Adjusted EBITDA. The amount excluded from Adjusted EBITDA represents depreciation and amortization, finance costs, finance income and other expenses and income tax expense relating to earnings of associate.
2 This item is a non-GAAP measure that does not have any standardized meaning prescribed by GAAP and therefore is unlikely to be comparable to similar measures presented by other companies. Refer to the Additional Information - Supplemental Non-GAAP Measures section for a description of the non-GAAP measure and reconciliation to the most comparable GAAP measure.

Adjusted EBITDA (Attributable to Methanex Shareholders)

Our operations consist of a single operating segment - the production and sale of methanol. We review the results of operations by analyzing changes in the components of Adjusted EBITDA. For a discussion of the definitions used in our Adjusted EBITDA analysis, refer to the How We Analyze Our Business section.

The changes in Adjusted EBITDA resulted from changes in the following:

($ millions) Q3 2013
compared with
Q2 2013
Q3 2013
compared with
Q3 2012
YTD Q3 2013
compared with
YTD Q3 2012
Average realized price $ 24 $ 115 $ 236
Sales volume (2 ) 6 26
Total cash costs 5 (41 ) (81 )
Increase in Adjusted EBITDA $ 27 $ 80 $ 181

Average realized price

Three Months Ended Nine Months Ended
($ per tonne) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Methanex average non-discounted posted price 502 494 433 490 440
Methanex average realized price 438 425 373 424 380

Methanol market conditions remained healthy and pricing increased across all regions during the third quarter of 2013 (refer to the Supply/Demand Fundamentals section for more information). Our average non-discounted posted price for the third quarter of 2013 was $502 per tonne compared with $494 per tonne for the second quarter of 2013 and $433 per tonne for the third quarter of 2012. Our average realized price for the third quarter of 2013 was $438 per tonne compared with $425 per tonne for the second quarter of 2013 and $373 per tonne for the third quarter of 2012. The change in average realized price for the third quarter of 2013 increased Adjusted EBITDA by $24 million compared with the second quarter of 2013 and increased Adjusted EBITDA by $115 million compared with the third quarter of 2012. Our average realized price for the nine months ended September 30, 2013 was $424 per tonne compared with $380 per tonne for the same period in 2012 and this increased Adjusted EBITDA by $236 million.

Sales volume

Methanol sales volumes excluding commission sales for the three and nine month periods ended September 30, 2013 were higher than comparable periods in 2012 by 61,000 tonnes and 256,000 tonnes and this resulted in higher Adjusted EBITDA by $6 million and $26 million, respectively.

Total cash costs

The primary drivers of changes in our total cash costs are changes in the cost of methanol we produce at our facilities (Methanex-produced methanol) and changes in the cost of methanol we purchase from others (purchased methanol). All of our production facilities except Medicine Hat are underpinned by natural gas purchase agreements with pricing terms that include base and variable price components. 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.

The impact on Adjusted EBITDA from changes in our cash costs are explained below:

($ millions) Q3 2013
compared with
Q2 2013
Q3 2013
compared with
Q3 2012
YTD Q3 2013
compared with
YTD Q3 2012
Methanex-produced methanol costs $ 3 $ (5 ) $ (38 )
Proportion of Methanex-produced methanol sales 5 (8 ) (9 )
Purchased methanol costs (3 ) (32 ) (70 )
Logistics costs - 4 25
Other, net - - 11
$ 5 $ (41 ) $ (81 )

Methanex-produced methanol costs

We purchase natural gas for the New Zealand, Trinidad, Egypt and Chile methanol facilities 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. For the third quarter of 2013 compared with the second quarter of 2013, Methanex-produced methanol costs were lower by $3 million primarily due to a change in the mix of production sold from inventory. For the third quarter of 2013 and nine month period ended September 30, 2013 compared with the same periods in 2012, Methanex-produced methanol costs were higher by $5 million and $38 million, respectively, primarily due to the impact of higher realized methanol prices on the variable portion of our natural gas costs and changes in the mix of production sold from inventory.

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. For the third quarter of 2013 compared with the second quarter of 2013, a higher proportion of Methanex-produced methanol sales increased Adjusted EBITDA by $5 million. For the third quarter of 2013 and nine month period ended September 30, 2013 compared with the same periods in 2012, a lower proportion of Methanex-produced methanol sales decreased Adjusted EBITDA by $8 million and $9 million, respectively.

Purchased methanol costs

Changes in purchased methanol costs for all periods presented are primarily as a result of changes in methanol pricing.

Logistics costs

Logistics costs 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. Over the past year, we have completed several initiatives that have reduced logistics costs and improved the efficiency of our supply chain. Logistics costs in the third quarter of 2013 were $4 million lower than the third quarter of 2012 and logistics costs for the nine month period were $25 million lower than in the same period in 2012.

Other, net

We have commenced the process of building a manufacturing organization in Geismar, Louisiana. Under IFRS, costs incurred related to organizational build-up are not eligible for capitalization and are charged directly to earnings as incurred. During the third quarter of 2013, we incurred approximately $3 million of Geismar organizational build-up costs and the remaining organizational build-up costs are estimated to be approximately $25 million.

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 the 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. The mark-to-market impact of share-based compensation as a result of changes in our share price is excluded from Adjusted EBITDA and Adjusted net income and analyzed separately.

Three Months Ended Nine Months Ended
($ millions except share price) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Methanex Corporation share price 1 $ 51.27 $ 42.84 $ 28.54 $ 51.27 $ 28.54
Grant-date fair value expense included in Adjusted EBITDA and Adjusted net income $ 5 $ 6 $ 3 $ 17 $ 17
Mark-to-market impact due to change in share price 33 9 - 73 7
Total share-based compensation expense $ 38 $ 15 $ 3 $ 90 $ 24
1 US dollar share price of Methanex Corporation as quoted on NASDAQ Global Market on the last trading day of the respective period.

The Methanex Corporation share price increased from $42.84 per share at June 30, 2013 to $51.27 per share at September 30, 2013. 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 $33 million mark-to-market expense on share-based compensation in the third quarter of 2013. For the nine month period ended September 30, 2013, we recorded a $73 million mark-to-market share-based compensation expense as a result of the increase in the share price from $31.87 at December 31, 2012 to $51.27 at September 30, 2013.

Depreciation and Amortization

Depreciation and amortization was $29 million for the third quarter of 2013 compared with $29 million for the second quarter of 2013 and $41 million for the third quarter of 2012. Depreciation and amortization for the nine month period ended September 30, 2013 was $88 million compared with $115 million for the same period in 2012. Depreciation and amortization is lower in 2013 compared with 2012 primarily as a result of the lower carrying value of our Chile assets due to the asset impairment charge recorded in the fourth quarter of 2012.

Finance Costs

Three Months Ended Nine Months Ended
($ millions) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Finance costs before capitalized interest $ 16 $ 17 $ 16 $ 49 $ 50
Less capitalized interest (2 ) (2 ) (1 ) (5 ) (1 )
Finance costs $ 14 $ 15 $ 15 $ 44 $ 49

Finance costs before capitalized interest primarily relate to interest expense on the unsecured notes and limited recourse debt facilities. Capitalized interest relates to interest costs capitalized for the Geismar projects.

Finance Income and Other Expenses

Three Months Ended Nine Months Ended
($ millions) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Finance income and other expenses $ 2 $ 3 $ (4 ) $ 3 $ (2 )

The change in finance income and other expenses for all periods presented was primarily due to the impact of changes in foreign exchange rates.

Income Taxes

A summary of our income taxes for the third quarter of 2013 compared with the second quarter of 2013 is as follows:

Three Months Ended
September 30, 2013
Three Months Ended
June 30, 2013
($ millions, except where noted) Net Income Adjusted Net
Income
1
Net Income Adjusted Net
Income
1
Amount before income tax $ 124 $ 143 $ 67 $ 114
Income tax expense (23 ) (26 ) (1 ) (15 )
Amount after income tax $ 101 $ 117 $ 66 $ 99
Effective tax rate 19 % 18 % 2 % 14 %
1 This item is a non-GAAP measure that does not have any standardized meaning prescribed by GAAP and therefore is unlikely to be comparable to similar measures presented by other companies. Refer to the Additional Information - Supplemental Non-GAAP Measures section for a description of the non-GAAP measure and reconciliation to the most comparable GAAP measure.

For the third quarter of 2013, the effective tax rate was 19% compared with 2% for the second quarter of 2013. Adjusted net income represents the amount that is attributable to Methanex shareholders and excludes the mark-to-market impact of share-based compensation and items that are considered by management to be non-operational. The effective tax rate related to Adjusted net income was 18% for the third quarter of 2013 compared with 14% for the second quarter of 2013.

We earn the majority of our pre-tax earnings in Trinidad, Egypt, Chile, Canada and New Zealand. In Trinidad and Chile, the statutory tax rate is 35% and in Egypt, the statutory tax rate is 25%. We have loss carryforwards in Canada and New Zealand which have not been recognized for accounting purposes. In addition, 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.

SUPPLY/DEMAND FUNDAMENTALS

We estimate that methanol demand, excluding methanol demand from integrated methanol to olefins facilities, is currently approximately 55 million tonnes on an annualized basis.

The outlook for methanol demand growth continues to be strong. Traditional chemical derivatives consume about two-thirds of global methanol demand and growth is correlated to industrial production.

Energy-related applications consume the remaining one-third of global methanol demand, and the wide disparity between the price of crude oil and that of natural gas and coal has resulted in an increased use of methanol in energy-related applications, such as direct methanol blending into gasoline and DME and biodiesel production. Growth of direct methanol blending into gasoline in China has been particularly strong and we believe that future growth in this application is supported by numerous provincial and national fuel-blending standards, such as M15 or M85 (15% methanol and 85% methanol, respectively).

China is also leading the commercialization of methanol's use as a feedstock to manufacture olefins. The use of methanol to produce olefins, at current energy prices, is proving to be cost competitive relative to the traditional production of olefins from naphtha. There are now three methanol-to-olefins (MTO) plants operating in China which are dependent on merchant methanol supply and which have the capacity to consume approximately 3.5 million tonnes of methanol annually. There are other MTO plants which are integrated and purchase methanol to supplement their production when required. We believe demand potential into energy-related applications and olefins production will continue to grow.

During the third quarter of 2013, overall market conditions remained healthy and prices increased. Our average non-discounted price in the third quarter was $502 per tonne compared with $494 per tonne in the second quarter. We recently announced an increase in our North American non-discounted price for November to $599 per tonne.

The methanol price 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. Over the next few years, there is a modest level of new capacity expected to come on-stream relative to demand growth expectations. We recently announced the restart of our Waitara Valley facility and the completion of debottlenecking projects in New Zealand and Canada which have added up to 1.0 million tonnes of additional operating capacity. A 0.8 million tonne plant in Channelview, Texas is expected to restart in 2013 and a 0.7 million tonne plant in Azerbaijan is expected to start-up in 2014. We are relocating two idle Chile facilities to Geismar, Louisiana with the first 1.0 million tonne facility scheduled to start up by the end of 2014 and the second 1.0 million tonne facility in early 2016. We expect that production from new capacity in China will be consumed in that country and that higher cost production capacity in China will need to operate in order to satisfy demand growth.

Methanex Non-Discounted Regional Posted Prices 1
(US$ per tonne) Oct
2013
Sep
2013
Aug
2013
Jul
2013
United States 549 532 532 532
Europe 2 539 505 505 505
Asia 490 470 470 450
1 Discounts from our posted prices are offered to customers based on various factors.
2 EUR408 for Q4 2013 (Q3 2013 - EUR390) converted to United States dollars.

LIQUIDITY AND CAPITAL RESOURCES

Cash flows from operating activities in the third quarter of 2013 increased by $56 million to $181 million compared with $125 million for the second quarter of 2013 and increased by $59 million compared to $122 million for the third quarter of 2012. Cash flows from operating activities for the nine month period ended September 30, 2013 increased by $88 million to $424 million compared with $336 million for the same period in 2012. The changes in cash flows from operating activities resulted from changes in the following:

($ millions) Q3 2013
compared with
Q2 2013
Q3 2013
compared with
Q3 2012
YTD Q3 2013
compared with
YTD Q3 2012
Change in Adjusted EBITDA (attributable to Methanex shareholders) $ 27 $ 80 $ 181
Exclude change in Adjusted EBITDA of associate (Atlas) 3 - (18 )
Cash flows attributable to non-controlling interests 1 12 -
Non-cash working capital 5 (56 ) (54 )
Income taxes paid (5 ) (8 ) (14 )
Geismar project relocation expenses 34 35 5
Share-based payments (6 ) (6 ) (11 )
Other (3 ) 2 (1 )
Increase in cash flows from operating activities $ 56 $ 59 $ 88

During the third quarter of 2013, we paid a quarterly dividend of $0.20 per share, or $19 million.

We operate in a highly competitive commodity industry and believe it is appropriate to maintain a conservative balance sheet and retain financial flexibility. At September 30, 2013, our cash balance was $686 million, including $35 million related to the non-controlling interest in Egypt. On October 22, 2013, we announced the sale of a 10% equity interest in the Egypt methanol facility to Arab Petroleum Investments Corporation (APICORP) for $110 million. Subject to the completion of certain conditions precedent, we expect the sale to be completed in the fourth quarter of 2013. 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 a strong balance sheet and an undrawn $400 million credit facility provided by highly rated financial institutions that expires in mid-2016.

Our planned capital maintenance expenditure program directed towards maintenance, turnarounds and catalyst changes for existing operations is currently estimated to total approximately $70 million to the end of 2014. We recently restarted the Waitara Valley facility and completed debottlenecking projects in New Zealand and Medicine Hat. We are in the process of a major refurbishment of the Motunui 2 facility in New Zealand with estimated remaining capital expenditures of approximately $100 million. We are relocating two methanol plants from our Chile site to Geismar, Louisiana. During the third quarter of 2013, capital expenditures related to the Geismar projects were $67 million, excluding capitalized interest. Remaining capital expenditures related to the Geismar projects are approximately $780 million. We believe that we have the financial capacity to fund these growth initiatives with cash on hand, cash generated from operations and the undrawn bank facility.

We believe we are well positioned to meet our financial commitments, invest to grow the Company and continue to deliver on our commitment to return excess cash to shareholders.

SHORT-TERM OUTLOOK

Entering the fourth quarter, market conditions remain healthy and methanol prices are rising.

The methanol price 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. We believe that our financial position and financial flexibility, outstanding global supply network and competitive-cost position will provide a sound basis for Methanex to continue to be the leader in the methanol industry and to invest to grow the Company.

CONTROLS AND PROCEDURES

For the three months ended September 30, 2013, no changes were made in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ADDITIONAL INFORMATION - SUPPLEMENTAL NON-GAAP MEASURES

In addition to providing measures prepared in accordance with International Financial Reporting Standards (IFRS), we present certain supplemental non-GAAP measures. These are Adjusted EBITDA, Adjusted net income, Adjusted net income per common share and operating income. These measures do not have any standardized meaning prescribed by generally accepted accounting principles (GAAP) and therefore are unlikely to be comparable to similar measures presented by other companies. These supplemental non-GAAP measures are provided to assist readers in determining our ability to generate cash from operations and improve the comparability of our results from one period to another. We believe these measures are useful in assessing operating performance and liquidity of the Company's ongoing business on an overall basis. We also believe Adjusted EBITDA is frequently used by securities analysts and investors when comparing our results with those of other companies.

Adjusted EBITDA (attributable to Methanex shareholders)

Adjusted EBITDA differs from the most comparable GAAP measure, net income attributable to Methanex shareholders, because it excludes depreciation and amortization, finance costs, finance income and other expenses, income tax expense, mark-to-market impact of share-based compensation, Geismar project relocation expenses and charges and write-off of oil and gas rights. Adjusted EBITDA includes an amount representing our 63.1% interest in the Atlas facility and our 60% interest in the methanol facility in Egypt.

Adjusted EBITDA and Adjusted net income exclude the mark-to-market impact of share-based compensation related to the impact of changes in our share price on share appreciation rights, tandem share appreciation rights, deferred share units, restricted share units and performance share units. The mark-to-market impact related to performance share units that is excluded from Adjusted EBITDA and Adjusted net income is calculated as the difference between the grant date value determined using a Methanex total shareholder return factor of 100% and the fair value recorded at each period end. As share-based awards will be settled in future periods, the ultimate value of the units is unknown at the date of grant and therefore the grant date value recognized in Adjusted EBITDA and Adjusted net income may differ from the total settlement cost.

The following table shows a reconciliation from net income attributable to Methanex shareholders to Adjusted EBITDA:

Three Months Ended Nine Months Ended
($ millions) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Net income (loss) attributable to Methanex shareholders $ 87 $ 54 $ (3 ) $ 201 $ 72
Mark-to-market impact of share-based compensation 33 9 - 73 7
Depreciation and amortization 29 29 41 88 114
Geismar project relocation expenses and charges - 34 61 34 65
Write-off of oil and gas rights - 17 - 17 -
Finance costs 14 15 15 44 49
Finance income and other expenses (2 ) (3 ) 4 (3 ) 2
Income tax expense (recovery) 24 1 (15 ) 37 9
Earnings of associate, excluding amount included in Adjusted EBITDA 1 9 12 9 29 24
Non-controlling interests adjustment 1 (10 ) (11 ) (8 ) (29 ) (32 )
Adjusted EBITDA (attributable to Methanex shareholders) $ 184 $ 157 $ 104 $ 491 $ 310
1 These adjustments represent depreciation and amortization, finance costs, finance income and other expenses and income tax expense associated with the 40% non-controlling interest in the methanol facility in Egypt and our 63.1% interest in the Atlas methanol facility.

Adjusted Net Income and Adjusted Net Income per Common Share

Adjusted net income and Adjusted net income per common share are non-GAAP measures because they exclude the mark-to-market impact of share-based compensation and items that are considered by management to be non-operational, including Geismar project relocation expenses and charges and write-off of oil and gas rights. The following table shows a reconciliation of net income attributable to Methanex shareholders to Adjusted net income and the calculation of Adjusted net income per common share:

Three Months Ended Nine Months Ended
($ millions except number of shares and per share amounts) Sep 30
2013
Jun 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Net income (loss) attributable to Methanex shareholders $ 87 $ 54 $ (3 ) $ 201 $ 72
Mark-to-market impact of share-based compensation 33 9 - 73 7
Geismar project relocation expenses and charges - 34 61 34 65
Write-off of oil and gas rights - 17 - 17 -
Income tax recovery related to above items (3 ) (15 ) (22 ) (21 ) (25 )
Adjusted net income $ 117 $ 99 $ 36 $ 304 $ 119
Diluted weighted average shares outstanding (millions) 97 96 94 96 95
Adjusted net income per common share $ 1.22 $ 1.02 $ 0.38 $ 3.16 $ 1.26

Operating Income

Operating income is reconciled directly to a GAAP measure in our consolidated statements of income.

QUARTERLY FINANCIAL DATA (UNAUDITED)

A summary of selected financial information for the prior eight quarters is as follows:

Three Months Ended
($ millions, except per share amounts) Sep 30
2013
Jun 30
2013
Mar 31
2013
Dec 31
2012
Revenue $ 758 $ 733 $ 652 $ 668
Adjusted EBITDA 1,2 184 157 149 119
Net income (loss) 1 87 54 60 (140 )
Adjusted net income 1,2 117 99 88 61
Basic net income (loss) per common share 1 0.91 0.57 0.64 (1.49 )
Diluted net income (loss) per common share 1 0.90 0.56 0.63 (1.49 )
Adjusted net income per share 1,2 1.22 1.02 0.92 0.64
Three Months Ended
($ millions, except per share amounts) Sep 30
2012
Jun 30
2012
Mar 31
2012
Dec 31
2011
Revenue $ 608 $ 613 $ 654 $ 696
Adjusted EBITDA 1,2 104 113 93 133
Net income (loss) 1 (3 ) 52 22 64
Adjusted net income 1,2 36 44 39 65
Basic net income (loss) per common share 1 (0.03 ) 0.56 0.24 0.69
Diluted net income (loss) per common share 1 (0.03 ) 0.50 0.23 0.68
Adjusted net income per share 1,2 0.38 0.47 0.41 0.69
1 Attributable to Methanex Corporation shareholders.
2 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 Additional Information - Supplemental Non-GAAP Measures section for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures.

FORWARD-LOOKING INFORMATION WARNING

This Third Quarter 2013 Management's Discussion and Analysis ("MD&A") as well as comments made during the Third Quarter 2013 investor conference call contain 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:

  • expected demand for methanol and its derivatives,

  • expected new methanol supply or restart of idled capacity and timing for start-up of the same,

  • expected shutdowns (either temporary or permanent) or restarts of existing methanol supply (including our own facilities), including, without limitation, the timing and length of planned maintenance outages,

  • expected methanol and energy prices,

  • expected levels of methanol purchases from traders or other third parties,

  • expected levels, timing and availability of economically priced natural gas supply to each of our plants,

  • capital committed by third parties towards future natural gas exploration and development in the vicinity of our plants,

  • our expected capital expenditures, including, without limitation, those to support natural gas exploration and development for our plants and the restart of our idled methanol facilities,

  • anticipated operating rates of our plants,

  • expected operating costs, including natural gas feedstock costs and logistics costs,

  • expected tax rates or resolutions to tax disputes,

  • expected cash flows, earnings capability and share price,

  • availability of committed credit facilities and other financing,

  • ability to meet covenants or obtain waivers associated with our long-term debt obligations, including, without limitation, the Egypt limited recourse debt facilities that have conditions associated with upstream natural gas development and the finalization of certain land title registration and related mortgages that require action by Egyptian governmental entities,

  • our shareholder distribution strategy and anticipated distributions to shareholders,

  • commercial viability and timing of, or our ability to execute, future projects, plant restarts, capacity expansions, plant relocations, or other business initiatives or opportunities, including the planned relocation of idle Chile methanol plants to Geismar, Louisiana ("Geismar") and certain initiatives in New Zealand,

  • our financial strength and ability to meet future financial commitments,

  • expected global or regional economic activity (including industrial production levels),

  • expected outcomes of litigation or other disputes, claims and assessments,

  • expected actions of governments, government agencies, gas suppliers, courts, tribunals or other third parties, and

  • expected impact on our operations in Egypt or our financial condition as a consequence of civil unrest or actions taken or inaction by the Government of Egypt and its agencies.

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:

  • the supply of, demand for, and price of methanol, methanol derivatives, natural gas, coal, oil and oil derivatives,

  • the success of our natural gas exploration and development in Chile and our ability to procure economically priced natural gas in Chile, New Zealand, Trinidad, Canada and the United States,

  • operating rates of our facilities,

  • receipt of remaining required permits in connection with our Geismar projects,

  • receipt or issuance of third-party consents or approvals, including, without limitation, governmental registrations of land title and related mortgages in Egypt, governmental approvals related to natural gas exploration rights or rights to purchase natural gas,

  • receipt of governmental approvals related to natural gas exploration rights,

  • the establishment of new fuel standards,

  • operating costs including natural gas feedstock and logistics costs, capital costs, tax rates, cash flows, foreign exchange rates and interest rates,

  • the availability of committed credit facilities and other financing,

  • timing of completion and cost of our Geismar projects and our initiatives to increase operating capacity in New Zealand,

  • global and regional economic activity (including industrial production levels),

  • absence of a material negative impact from major natural disasters,

  • absence of a material negative impact from changes in laws or regulations,

  • absence of a material negative impact from political instability in the countries in which we operate,

  • enforcement of contractual arrangements and ability to perform contractual obligations by customers, natural gas and other suppliers and other third parties, and

  • satisfaction of conditions precedent contained in the Geismar I natural gas supply agreement.

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:

  • conditions in the methanol and other industries including fluctuations in the supply, demand for and price of methanol and its derivatives, including demand for methanol for energy uses,

  • the price of natural gas, coal, oil and oil derivatives,

  • the success of natural gas exploration and development activities in southern Chile and our ability to obtain any additional gas in Chile and New Zealand on commercially acceptable terms,

  • the ability to successfully carry out corporate initiatives and strategies,

  • actions of competitors, suppliers and financial institutions,

  • conditions within the natural gas delivery systems that may prevent delivery of our natural gas supply requirements,

  • competing demand for natural gas, especially with respect to domestic needs for gas and electricity in Chile and Egypt,

  • actions of governments and governmental authorities, including, without limitation, the implementation of policies or other measures that could impact the supply of or demand for methanol or its derivatives,

  • changes in laws or regulations,

  • import or export restrictions, anti-dumping measures, increases in duties, taxes and government royalties, and other actions by governments that may adversely affect our operations or existing contractual arrangements,

  • world-wide economic conditions,

  • satisfaction of conditions precedent contained in the Geismar I natural gas supply agreement, and

  • other risks described in our 2012 Management's Discussion and Analysis and this Third Quarter 2013 Management's Discussion and Analysis.

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 anticipated in forward-looking statements may not occur and we do not undertake to update forward-looking statements except as required by applicable securities laws.

HOW WE ANALYZE OUR BUSINESS

Our operations consist of a single operating segment - the production and sale of methanol. We review our results of operations by analyzing changes in the components of Adjusted EBITDA (refer to the Additional Information - Supplemental Non-GAAP Measures section for a description of each non-GAAP measure and reconciliations to the most comparable GAAP measures).

In addition to the methanol that we produce at our facilities ("Methanex-produced methanol"), we also purchase and re-sell methanol produced by others ("purchased methanol") and we sell methanol on a commission basis. We analyze the results of all methanol sales together, excluding commission sales volumes. The key drivers of changes in Adjusted EBITDA are average realized price, cash costs and sales volume which are defined and calculated as follows:

PRICE The change in Adjusted EBITDA as a result of changes in average realized price is calculated as the difference from period to period in the selling price of methanol multiplied by the current period total methanol sales volume excluding commission sales volume plus the difference from period to period in commission revenue.
CASH COST The change in Adjusted EBITDA as a result of changes in cash costs is calculated as the difference from period to period in cash costs per tonne multiplied by the current period total methanol sales volume excluding commission sales volume in the current period. The cash costs per tonne is the weighted average of the cash cost per tonne of Methanex-produced methanol and the cash cost per tonne of purchased methanol. The cash cost per tonne of Methanex-produced methanol includes absorbed fixed cash costs per tonne and variable cash costs per tonne. The cash cost per tonne of purchased methanol consists principally of the cost of methanol itself. In addition, the change in Adjusted EBITDA as a result of changes in cash costs includes the changes from period to period in unabsorbed fixed production costs, consolidated selling, general and administrative expenses and fixed storage and handling costs.
VOLUME The change in Adjusted EBITDA as a result of changes in sales volume is calculated as the difference from period to period in total methanol sales volume excluding commission sales volumes 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, respectively. For purposes of analyzing our business, Adjusted EBITDA, Adjusted net income and Adjusted net income per common share include an amount representing our 63.1% equity share in Atlas.

We own 60% of the 1.26 million tonne per year Egypt methanol facility and market the remaining 40% 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 with the other investors' interests in the methanol facility being presented as "non-controlling interests". For purposes of analyzing our business, Adjusted EBITDA, Adjusted net income and Adjusted net income per common share exclude the amount associated with the other investors' 40% non-controlling interests.

Methanex Corporation
Consolidated Statements of Income
(unaudited)
(thousands of U.S. dollars, except number of common shares and per share amounts)
Three Months Ended Nine Months Ended
Sep 30 Sep 30 Sep 30 Sep 30
2013 2012 2013 2012
(As adjusted - note 11) (As adjusted - note 11)
Revenue $ 758,149 $ 607,936 $ 2,143,147 $ 1,875,257
Cost of sales and operating expenses (598,633 ) (507,683 ) (1,706,744 ) (1,535,539 )
Depreciation and amortization (28,971 ) (40,810 ) (87,741 ) (114,775 )
Geismar project relocation expenses and charges - (60,857 ) (33,867 ) (64,543 )
Write-off of oil and gas rights - - (16,859 ) -
Operating income (loss) 130,545 (1,414 ) 297,936 160,400
Earnings (loss) of associate (note 4) 5,968 5,799 13,271 (214 )
Finance costs (note 6) (13,756 ) (15,346 ) (43,825 ) (48,969 )
Finance income and other expenses 1,599 (3,451 ) 2,670 (1,894 )
Income (loss) before income tax expense 124,356 (14,412 ) 270,052 109,323
Income tax recovery (expense):
Current (12,139 ) (5,130 ) (39,806 ) (21,280 )
Deferred (11,204 ) 20,987 2,851 12,358
(23,343 ) 15,857 (36,955 ) (8,922 )
Net income $ 101,013 $ 1,445 $ 233,097 $ 100,401
Attributable to:
Methanex Corporation shareholders 87,106 (2,571 ) 201,372 71,748
Non-controlling interests 13,907 4,016 31,725 28,653
$ 101,013 $ 1,445 $ 233,097 $ 100,401
Income per share for the period attributable to Methanex Corporation shareholders
Basic net income (loss) per common share $ 0.91 $ (0.03 ) $ 2.12 $ 0.77
Diluted net income (loss) per common share $ 0.90 $ (0.03 ) $ 2.09 $ 0.76
Weighted average number of common shares outstanding (note 7) 95,488,882 93,880,221 95,046,274 93,691,597
Diluted weighted average number of common shares outstanding (note 7) 96,554,316 93,880,221 96,244,865 94,887,279
See accompanying notes to condensed consolidated interim financial statements.
Methanex Corporation
Consolidated Statements of Comprehensive Income
(unaudited)
(thousands of U.S. dollars, except number of common shares and per share amounts)
Three Months Ended Nine Months Ended
Sep 30 Sep 30 Sep 30 Sep 30
2013 2012 2013 2012
Net income $ 101,013 $ 1,445 $ 233,097 $ 100,401
Other comprehensive income, net of taxes:
Items that may be reclassified to income:
Change in fair value of forward exchange contracts 5,737 528 1,291 (343 )
Change in fair value of interest rate swap contracts (602 ) (1,744 ) (902 ) (5,104 )
Realized loss on interest rate swap contracts reclassified to finance costs 2,745 2,719 8,128 8,421
7,880 1,503 8,517 2,974
Comprehensive income $ 108,893 $ 2,948 $ 241,614 $ 103,375
Attributable to:
Methanex Corporation shareholders 94,128 (1,458 ) 206,998 73,395
Non-controlling interests 14,765 4,406 34,616 29,980
$ 108,893 $ 2,948 $ 241,614 $ 103,375
See accompanying notes to condensed consolidated interim financial statements.
Methanex Corporation
Consolidated Statements of Financial Position
(unaudited)
(thousands of U.S. dollars)
Sep 30 Dec 31
AS AT 2013 2012
(As adjusted - note 11)
ASSETS
Current assets:
Cash and cash equivalents $ 686,238 $ 727,385
Trade and other receivables 471,331 417,156
Inventories (note 2) 254,520 256,340
Prepaid expenses 29,723 25,588
1,441,812 1,426,469
Non-current assets:
Property, plant and equipment (note 3) 2,048,021 1,762,873
Investment in associate (note 4) 198,408 184,665
Other assets 63,932 68,554
2,310,361 2,016,092
$ 3,752,173 $ 3,442,561
LIABILITIES AND EQUITY
Current liabilities:
Trade, other payables and accrued liabilities $ 494,512 $ 377,666
Current maturities on long-term debt (note 5) 41,504 38,290
Current maturities on other long-term liabilities 66,564 30,322
602,580 446,278
Non-current liabilities:
Long-term debt (note 5) 1,126,841 1,156,081
Other long-term liabilities 192,758 200,212
Deferred income tax liabilities 161,812 162,253
1,481,411 1,518,546
Equity:
Capital stock 518,981 481,779
Contributed surplus 7,561 15,481
Retained earnings 951,301 805,661
Accumulated other comprehensive loss (7,419 ) (13,045 )
Shareholders' equity 1,470,424 1,289,876
Non-controlling interests 197,758 187,861
Total equity 1,668,182 1,477,737
$ 3,752,173 $ 3,442,561
See accompanying notes to condensed consolidated interim financial statements.
Methanex Corporation
Consolidated Statements of Changes in Equity
(unaudited)
(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, 2011 93,247,755 $ 455,434 $ 22,281 $ 942,978 $ (15,968 ) $ 1,404,725 $ 197,238 $ 1,601,963
Net income - - - 71,748 - 71,748 28,653 100,401
Other comprehensive income - - - - 1,647 1,647 1,327 2,974
Compensation expense recorded for stock options - - 564 - - 564 - 564
Issue of shares on exercise of stock options 720,455 13,267 - - - 13,267 - 13,267
Reclassification of grant date fair value on exercise of stock options - 5,159 (5,159 ) - - - - -
Dividend payments to Methanex Corporation shareholders - - - (50,649 ) - (50,649 ) - (50,649 )
Distributions to non-controlling interests - - - - - - (42,292 ) (42,292 )
Equity contributions by non-controlling interests - - - - - - 1,000 1,000
Balance, September 30, 2012 93,968,210 473,860 17,686 964,077 (14,321 ) 1,441,302 185,926 1,627,228
Net income (139,853 ) - (139,853 ) 4,877 (134,976 )
Other comprehensive income (loss) (1,135 ) 1,276 141 834 975
Compensation expense recorded for stock options - - 162 - - 162 - 162
Issue of shares on exercise of stock options 341,760 5,552 - - - 5,552 - 5,552
Reclassification of grant date fair value on exercise of stock options - 2,367 (2,367 ) - - - - -
Dividend payments to Methanex Corporation shareholders - - - (17,428 ) - (17,428 ) - (17,428 )
Distributions to non-controlling interests - - - - - - (3,776 ) (3,776 )
Equity contributions by non-controlling interests - - - - - - - -
Balance, December 31, 2012 94,309,970 481,779 15,481 805,661 (13,045 ) 1,289,876 187,861 1,477,737
Net income - - - 201,372 - 201,372 31,725 233,097
Other comprehensive income - - - - 5,626 5,626 2,891 8,517
Compensation expense recorded for stock options - - 582 - - 582 - 582
Issue of shares on exercise of stock options 1,349,824 28,700 - - - 28,700 - 28,700
Reclassification of grant date fair value on exercise of stock options - 8,502 (8,502 ) - - - - -
Dividend payments to Methanex Corporation shareholders - - - (55,732 ) - (55,732 ) - (55,732 )
Distributions to non-controlling interests - - - - - - (25,719 ) (25,719 )
Equity contributions by non-controlling interests - - - - - - 1,000 1,000
Balance, September 30, 2013 95,659,794 $ 518,981 $ 7,561 $ 951,301 $ (7,419 ) $ 1,470,424 $ 197,758 $ 1,668,182
See accompanying notes to condensed consolidated interim financial statements.
Methanex Corporation
Consolidated Statements of Cash Flows
(unaudited)
(thousands of U.S. dollars)
Three Months Ended Nine Months Ended
Sep 30 Sep 30 Sep 30 Sep 30
2013 2012 2013 2012
(As adjusted - note 11) (As adjusted - note 11)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 101,013 $ 1,445 $ 233,097 $ 100,401
Add (deduct) loss (earnings) of associate (5,968 ) (5,799 ) (13,271 ) 214
Add (deduct) non-cash items:
Depreciation and amortization 28,971 40,810 87,741 114,775
Geismar project relocation non-cash charges - 25,688 - 25,688
Write-off of oil and gas rights - - 16,859 -
Income tax expense (recovery) 23,343 (15,857 ) 36,955 8,922
Share based compensation expense 38,022 3,340 90,029 24,880
Finance costs 13,756 15,346 43,825 48,969
Other 1,096 7,078 795 10,036
Income taxes paid (12,142 ) (4,154 ) (27,493 ) (14,439 )
Other cash payments, including share-based compensation (8,760 ) (3,622 ) (26,755 ) (19,159 )
Cash flows from operating activities before undernoted 179,331 64,275 441,782 300,287
Changes in non-cash working capital (note 9) 1,282 57,165 (17,741 ) 35,144
180,613 121,440 424,041 335,431
CASH FLOWS FROM FINANCING ACTIVITIES
Dividend payments to Methanex Corporation shareholders (19,141 ) (17,384 ) (55,732 ) (50,649 )
Interest paid, including interest rate swap settlements (21,103 ) (30,542 ) (48,860 ) (55,553 )
Net proceeds on issue of long-term debt - - - 246,548
Repayment of long-term debt and limited recourse debt (19,099 ) (217,682 ) (38,579 ) (235,448 )
Equity contributions by non-controlling interests - - 1,000 1,000
Cash distributions to non-controlling interests (12,695 ) (29,633 ) (25,719 ) (45,632 )
Proceeds from limited recourse debt - - 10,000 -
Proceeds on issue of shares on exercise of stock options 4,549 3,000 28,700 13,267
Other (953 ) (860 ) (2,808 ) (15,156 )
(68,442 ) (293,101 ) (131,998 ) (141,623 )
CASH FLOWS FROM INVESTING ACTIVITIES
Property, plant and equipment (101,409 ) (19,055 ) (197,641 ) (94,820 )
Geismar plants under construction (67,416 ) (24,281 ) (164,493 ) (38,604 )
Other assets (5,199 ) (5,719 ) (10,949 ) (7,635 )
Changes in non-cash working capital related to investing activities (note 9) 39,577 (7,540 ) 39,893 (8,855 )
(134,447 ) (56,595 ) (333,190 ) (149,914 )
Increase (decrease) in cash and cash equivalents (22,276 ) (228,256 ) (41,147 ) 43,894
Cash and cash equivalents, beginning of period 708,514 613,595 727,385 341,445
Cash and cash equivalents, end of period $ 686,238 $ 385,339 $ 686,238 $ 385,339
See accompanying notes to condensed consolidated interim financial statements.

Methanex Corporation

Notes to Condensed Consolidated Interim Financial Statements (unaudited)

Except where otherwise noted, tabular dollar amounts are stated in thousands of U.S. dollars.

1. Basis of presentation:

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 supplier of methanol to major international markets in Asia Pacific, North America, Europe and Latin America.

These condensed consolidated interim financial statements are prepared in accordance with International Accounting Standards (IAS) 34, Interim Financial Reporting, as issued by the International Accounting Standards Board (IASB) on a basis consistent with those followed in the most recent annual consolidated financial statements, except as described in note 11 below. As described in note 11, the Company has adopted new International Financial Reporting Standards (IFRS) effective January 1, 2013 with retrospective application and as a result the comparative periods have been restated.

These condensed consolidated interim financial statements do not include all of the information required for full annual financial statements and were approved and authorized for issue by the Audit, Finance & Risk Committee of the Board of Directors on October 30, 2013.

2. 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 included in cost of sales and operating expenses and depreciation and amortization for the three and nine month periods ended September 30, 2013 is $506 million (2012 - $470 million) and $1,519 million (2012 - $1,389 million), respectively.

3. Property, plant and equipment:

Buildings, Plant Installations & Machinery Plants Under Construction Oil & Gas Properties Other Total
Cost at September 30, 2013 $ 3,048,809 $ 244,741 $ 5,404 $ 81,654 $ 3,460,608
Accumulated depreciation at September 30, 2013 1,301,342 - 77,236 34,009 1,412,587
Net book value at September 30, 2013 $ 1,747,467 $ 244,741 $ 8,168 $ 47,645 $ 2,048,021
Cost at December 31, 2012 $ 2,866,013 $ 75,238 $ 80,368 $ 68,906 $ 3,090,525
Accumulated depreciation at December 31, 2012 1,225,202 - 74,151 28,299 1,327,652
Net book value at December 31, 2012 $ 1,640,811 $ 75,238 $ 6,217 $ 40,607 $ 1,762,873

The Company is relocating two idle Chile facilities to Geismar, Louisiana with Geismar I scheduled to start up by the end of 2014 and Geismar II in early 2016. During the three months ended September 30, 2013, the Company incurred capital expenditures related to the Geismar projects of $67 million, excluding capitalized interest. Remaining capital expenditures for these projects is estimated to be $780 million, excluding capitalized interest.

4. Investment in Atlas methanol facility:

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. Effective January 1, 2013, the Company accounts for its interest in Atlas using the equity method (refer to note 11). Summarized financial information of Atlas (100% basis) is as follows:

Sep 30 Dec 31
Summarized Financial Information as at 2013 2012
Cash and cash equivalents $ 8,241 $ 28,883
Other current assets 147,982 104,933
Non-current assets 381,659 407,362
Current liabilities (42,870 ) (65,005 )
Long-term debt, including current maturities (68,673 ) (80,594 )
Other long-term liabilities, including current maturities (133,529 ) (123,801 )
Net assets at 100% $ 292,810 $ 271,778
Net assets at 63.1% $ 184,763 $ 171,492
Long-term receivable from Atlas 13,645 13,173
Investment in associate $ 198,408 $ 184,665
Three Months Ended Nine Months Ended
Summarized Financial Information Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Revenue $ 100,657 $ 84,581 $ 264,438 $ 199,777
Cost of sales and depreciation and amortization (84,576 ) (70,884 ) (226,020 ) (188,075 )
Operating income 16,081 13,697 38,418 11,702
Finance costs, finance income and other expenses (2,895 ) (2,857 ) (9,767 ) (11,127 )
Income tax expense (3,727 ) (1,648 ) (7,619 ) (913 )
Net earnings (loss) at 100% $ 9,459 $ 9,192 $ 21,032 $ (338 )
Earnings (loss) of associate at 63.1% $ 5,968 $ 5,799 $ 13,271 $ (214 )

b) Contingent liability:

The Board of Inland Revenue of Trinidad and Tobago has issued assessments against Atlas in respect of the 2005 and 2006 financial years. All subsequent tax years remain open to assessment. The assessments relate to the pricing arrangements of certain long-term fixed price sales contracts that extend to 2014 and 2019 related to methanol produced by Atlas. The impact of the amounts in dispute for the 2005 and 2006 financial years is not significant. Atlas has partial relief from corporation income tax until 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.

5. Long-term debt:

Sep 30 Dec 31
As at 2013 2012
Unsecured notes
$350 million at 3.25% due December 15, 2019 $ 344,316 $ 343,828
$250 million at 5.25% due March 1, 2022 246,566 246,326
$150 million at 6.00% due August 15, 2015 149,520 149,344
740,402 739,498
Egypt limited recourse debt facilities 404,259 438,631
Other limited recourse debt facilities 23,684 16,242
Total long-term debt 1 1,168,345 1,194,371
Less current maturities (41,504 ) (38,290 )
$ 1,126,841 $ 1,156,081
1 Long-term debt is presented net of deferred financing fees.

During the three months ended September 30, 2013, the Company made repayments on its Egypt limited recourse debt facilities of $18.2 million and other limited recourse debt facilities of $0.9 million.

At September 30, 2013, management believes the Company was in compliance with all significant covenants and default provisions related to long-term debt obligations.

6. Finance costs:

Three Months Ended Nine Months Ended
Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Finance costs $ 16,039 $ 16,020 $ 48,835 $ 49,643
Less capitalized interest related to Geismar plants under construction (2,283 ) (674 ) (5,010 ) (674 )
$ 13,756 $ 15,346 $ 43,825 $ 48,969

Finance costs are primarily comprised of interest on borrowings and finance lease obligations, the effective portion of interest rate swaps designated as cash flow hedges, amortization of deferred financing fees, and accretion expense associated with site restoration costs. Interest during construction is capitalized until the plant is substantially completed and ready for productive use.

The Company has interest rate swap contracts on its Egypt limited recourse debt facilities to swap the LIBOR-based interest payments for an average aggregated fixed rate of 4.8% plus a spread on approximately 75% of the Egypt limited recourse debt facilities for the period to March 31, 2015.

7. Net income per common share:

Diluted net income per common share is calculated by considering the potential dilution that would occur if outstanding stock options and, under certain circumstances, tandem share appreciation rights (TSARs) were exercised or converted to common shares.

Outstanding TSARs may be settled in cash or common shares at the holder's option and for purposes of calculating diluted net income per common share, the more dilutive of the cash-settled and equity-settled method is used, regardless of how the plan is accounted for. Accordingly, TSARs that are accounted for using the cash-settled method will require adjustments to the numerator and denominator if the equity-settled method is determined to have a dilutive effect on diluted net income per common share.

A reconciliation of the numerator used for the purpose of calculating diluted net income per common share is as follows:

Three Months Ended Nine Months Ended
Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Numerator for basic net income (loss) per common share $ 87,106 $ (2,571 ) $ 201,372 $ 71,748
Adjustment for the effect of TSARs:
Cash settled recovery included in net income - 306 - -
Equity settled expense - (733 ) - -
Numerator for diluted net income (loss) per common share $ 87,106 $ (2,998 ) $ 201,372 $ 71,748

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. A reconciliation of the denominator used for the purposes of calculating basic and diluted net income per common share is as follows:

Three Months Ended Nine Months Ended
Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Denominator for basic net income per common share 95,488,882 93,880,221 95,046,274 93,691,597
Effect of dilutive stock options 1,065,434 - 1,198,591 1,195,682
Denominator for diluted net income per common share 96,554,316 93,880,221 96,244,865 94,887,279

For the three month and nine month periods ended September 30, 2013 and 2012, basic and diluted net income (loss) per common share attributable to Methanex shareholders were as follows:

Three Months Ended Nine Months Ended
Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Basic net income (loss) per common share $ 0.91 $ (0.03 ) $ 2.12 $ 0.77
Diluted net income (loss) per common share $ 0.90 $ (0.03 ) $ 2.09 $ 0.76

8. Share-based compensation:

a) Share appreciation rights (SARs), tandem share appreciation rights (TSARs) and stock options:

(i) Outstanding units:

Information regarding units outstanding at September 30, 2013 is as follows:

SARs TSARs
Number of Units Weighted Average Exercise Price Number of Units Weighted Average Exercise Price
Outstanding at December 31, 2012 897,525 $ 28.63 1,815,535 $ 28.45
Granted 360,900 38.24 544,200 38.24
Exercised (98,176 ) 27.01 (31,400 ) 27.27
Cancelled (5,500 ) 30.86 (2,700 ) 31.73
Outstanding at June 30, 2013 1,154,749 $ 31.76 2,325,635 $ 30.75
Exercised (24,482 ) 27.61 (239,700 ) 25.33
Cancelled - - (2,200 ) 30.91
Outstanding at September 30, 2013 1,130,267 $ 31.85 2,083,735 $ 31.37
Stock Options
Number of Units Weighted Average Exercise Price
Outstanding at December 31, 2012 2,982,947 $ 19.97
Granted 75,600 38.24
Exercised (1,018,520 ) 23.39
Cancelled (48,128 ) 16.13
Outstanding at June 30, 2013 1,991,899 $ 19.01
Exercised (331,304 ) 14.19
Outstanding at September 30, 2013 1,660,595 $ 19.97
Units Outstanding at
September 30, 2013
Units Exercisable at
September 30, 2013
Range of Exercise Prices Weighted Average Remaining Contractual Life (Years) Number of Units Outstanding Weighted Average
Exercise Price
Number of Units Exercisable Weighted Average
Exercise Price
SARs:
$23.36 to 29.18 4.0 453,637 $ 26.86 360,326 $ 26.40
$31.73 to 38.24 6.0 676,630 35.20 93,670 31.73
5.2 1,130,267 $ 31.85 453,996 $ 27.50
TSARs:
$23.36 to 29.18 4.0 911,545 $ 27.03 748,464 $ 26.65
$31.73 to 38.24 5.9 1,172,190 34.75 205,760 31.73
5.0 2,083,735 $ 31.37 954,224 $ 27.74
Stock options:
$6.33 to 11.56 2.4 631,765 $ 6.40 631,765 $ 6.40
$23.92 to 38.24 2.1 1,028,830 28.30 876,180 27.21
2.2 1,660,595 $ 19.97 1,507,945 $ 18.49

(ii) Compensation expense related to SARs and TSARs:

Compensation expense for SARs and TSARs is measured based on their fair value and is recognized over the vesting period. Changes in fair value each period are recognized in net income for the proportion of the service that has been rendered at each reporting date. The fair value at September 30, 2013 was $64.4 million compared with the recorded liability of $54.4 million. The difference between the fair value and the recorded liability of $10.0 million will be recognized over the weighted average remaining vesting period of approximately 1.6 years. The weighted average fair value was estimated at September 30, 2013 using the Black-Scholes option pricing model.

For the three and nine month periods ended September 30, 2013, compensation expense related to SARs and TSARs included an expense in cost of sales and operating expenses of $22.3 million (2012 - expense of $0.1 million) and an expense of $46.2 million (2012 - expense of $7.2 million), respectively. This included an expense of $20.3 million (2012 - recovery of $1.1 million) and an expense of $39.4 million (2012 - expense of $0.3 million) related to the effect of the change in the Company's share price for the three and nine month periods ended September 30, 2013.

(iii) Compensation expense related to stock options:

For the three and nine month periods ended September 30, 2013, compensation expense related to stock options included in cost of sales and operating expenses was $0.2 million (2012 - $0.2 million) and $0.6 million (2012 - $0.6 million), respectively. The fair value of each stock option grant was estimated on the grant date using the Black-Scholes option pricing model.

b) Deferred, restricted and performance share units:

Deferred, restricted and performance share units outstanding at September 30, 2013 are as follows:

Number of Deferred Share Units Number of Restricted Share Units Number of Performance Share Units
Outstanding at December 31, 2012 566,850 38,883 1,053,869
Granted 10,122 22,500 304,600
Granted in-lieu of dividends 4,860 573 8,788
Redeemed (49,432 ) - (410,177 )
Cancelled - - (7,690 )
Outstanding at June 30, 2013 532,400 61,956 949,390
Granted 525 - -
Granted in-lieu of dividends 2,074 244 3,748
Cancelled - - (414 )
Outstanding at September 30, 2013 534,999 62,200 952,724

Compensation expense for deferred, restricted and performance share units is measured at fair value based on the market value of the Company's common shares and is recognized over the vesting period. Changes in fair value are recognized in net income for the proportion of the service that has been rendered at each reporting date. The fair value of deferred, restricted and performance share units at September 30, 2013 was $88.5 million compared with the recorded liability of $72.7 million. The difference between the fair value and the recorded liability of $15.8 million will be recognized over the weighted average remaining vesting period of approximately 1.8 years.

For the three and nine month periods ended September 30, 2013, compensation expense related to deferred, restricted and performance share units included in cost of sales and operating expenses was an expense of $15.5 million (2012 - expense of $3.1 million) and an expense of $43.2 million (2012 - expense of $17.1 million), respectively. This included an expense of $13.0 million (2012 - expense of $1.1 million) and an expense of $33.9 million (2012 - expense of $7.3 million) related to the effect of the change in the Company's share price for the three and nine month periods ended September 30, 2013.

Changes in non-cash working capital:

Changes in non-cash working capital for the three and nine month periods ended September 30, 2013 were as follows:

Three Months Ended Nine Months Ended
Sep 30
2013
Sep 30
2012
Sep 30
2013
Sep 30
2012
Decrease (increase) in non-cash working capital:
Trade and other receivables $ 5,930 $ 10,270 ) $ (54,175 ) $ (26,960 )
Inventories 16,416 20,195 1,820 45,260
Prepaid expenses 1,505 6,185 (4,135 ) (2,601 )
Trade, other payables and accrued liabilities, including long-term payables included in other long-term liabilities 12,227 33,476 99,199 12,189
36,078 49,586 42,709 27,888
Adjustments for items not having a cash effect and working capital changes relating to taxes and interest paid 4,781 39 (20,557 ) (1,599 )
Changes in non-cash working capital having a cash effect $ 40,859 $ 49,625 $ 22,152 $ 26,289
These changes relate to the following activities:
Operating $ 1,282 $ 57,165 $ (17,741 ) $ 35,144
Investing 39,577 (7,540 ) 39,893 (8,855 )
Changes in non-cash working capital $ 40,859 $ 49,625 $ 22,152 $ 26,289

10. Financial instruments:

Financial instruments are either measured at amortized cost or fair value. Held-to-maturity investments, loans and receivables and other financial liabilities are measured at amortized cost. Held-for-trading financial assets and liabilities and available-for-sale financial assets are measured on the Consolidated Statements of Financial Position at fair value. Derivative financial instruments are classified as held-for-trading and are recorded on the Consolidated Statements of Financial Position at fair value unless exempted. Changes in fair value of held-for-trading derivative financial instruments are recorded in earnings unless the instruments are designated as cash flow hedges.

The euro hedges, Egypt interest rate swaps, and New Zealand dollar hedges designated as cash flow hedges are measured at fair value based on industry-accepted valuation models and inputs obtained from active markets.

The Egypt limited recourse debt facilities bear interest at LIBOR plus a spread. The Company has interest rate swap contracts to swap the LIBOR-based interest payments for an average aggregated fixed rate of 4.8% plus a spread on approximately 75% of the Egypt limited recourse debt facilities for the period to March 31, 2015. The Company has designated these interest rate swaps as cash flow hedges. These interest rate swaps had an outstanding notional amount of $315 million as at September 30, 2013. The notional amount decreases over the expected repayment period. At September 30, 2013, these interest rate swap contracts had a negative fair value of $19.4 million (December 31, 2012 - $32.7 million) recorded in other long-term liabilities. The fair value of these interest rate swap contracts will fluctuate until maturity.

The Company also designates as cash flow hedges forward exchange contracts to sell euro and buy New Zealand dollar at a fixed USD exchange rate. At September 30, 2013, the Company had outstanding forward exchange contracts designated as cash flow hedges to sell a notional amount of EUR19.1 million and buy a notional amount of NZD $69.4 million in exchange for US dollars. The euro contracts had a negative fair value of $0.7 million recorded in current liabilities and the New Zealand dollar contracts had a positive fair value of $1.8 million recorded in other assets. Changes in fair value of derivative financial instruments designated as cash flow hedges have been recorded in other comprehensive income.

The carrying values of the Company's financial instruments approximate their fair values, except as follows:

September 30, 2013
As at Carrying Value Fair Value
Long-term debt $ 1,184,319 $ 1,195,607

There is no publicly traded market for the limited recourse debt facilities, the fair value of which is estimated by reference to current market prices for debt securities with similar terms and characteristics. The fair value of the unsecured notes was calculated by reference to a limited number of small transactions in September 2013. The fair value of the Company's unsecured notes will fluctuate until maturity.

11. Adoption of New Accounting Standards:

a) Effective January 1, 2013, the Company has adopted the following new IASB accounting standards related to consolidation and joint arrangements: IFRS 10, Consolidated Financial Statements; IFRS 11, Joint Arrangements; and IFRS 12, Disclosure of Interests in Other Entities.

As a result of the adoption of these new standards, the Company's 63.1% interest in the Atlas entity is accounted for using the equity method. The Company has restated its Consolidated Statement of Financial Position as at January 1, 2012 and December 31, 2012 and its Consolidated Statement of Income and Comprehensive Income for the three and nine months ended September 30, 2012. Reconciliations of the restatements of the Consolidated Statement of Financial Position as at December 31, 2012 and Consolidated Statement of Income and Comprehensive Income for the three and nine months ended September 30, 2012 are as follows:

Consolidated Statement of Financial Position
As at December 31, 2012
As Previously Stated Restatement of Atlas
to Equity Method
As Adjusted
ASSETS
Current assets:
Cash and cash equivalents $ 745,610 $ (18,225 ) $ 727,385
Trade and other receivables 429,203 (12,047 ) 417,156
Inventories 253,023 3,317 256,340
Prepaid expenses 28,314 (2,726 ) 25,588
1,456,150 (29,681 ) 1,426,469
Non-current assets:
Property, plant and equipment 2,014,748 (251,875 ) 1,762,873
Investment in associate - 184,665 184,665
Other assets 73,724 (5,170 ) 68,554
2,088,472 (72,380 ) 2,016,092
$ 3,544,622 $ (102,061 ) $ 3,442,561
LIABILITIES AND EQUITY
Current liabilities:
Trade, other payables and accrued liabilities $ 353,744 $ 23,922 $ 377,666
Current maturities on long-term debt 53,334 (15,044 ) 38,290
Current maturities on other long-term liabilities 33,903 (3,581 ) 30,322
440,981 5,297 446,278
Non-current liabilities:
Long-term debt 1,191,891 (35,810 ) 1,156,081
Other long-term liabilities 242,435 (42,223 ) 200,212
Deferred income tax liabilities 191,578 (29,325 ) 162,253
1,625,904 (107,358 ) 1,518,546
Equity:
Capital stock 481,779 - 481,779
Contributed surplus 15,481 - 15,481
Retained earnings 805,661 - 805,661
Accumulated other comprehensive loss (13,045 ) - (13,045 )
Shareholders' equity 1,289,876 - 1,289,876
Non-controlling interests 187,861 - 187,861
Total equity 1,477,737 - 1,477,737
$ 3,544,622 $ (102,061 ) $ 3,442,561
Consolidated Statement of Income and Comprehensive Income
Three months ended September 30, 2012
As Previously Stated Restatement of Atlas to Equity Method As Adjusted
Revenue $ 655,330 $ (47,394 ) $ 607,936
Cost of sales and operating expenses (538,994 ) 31,311 (507,683 )
Depreciation and amortization (47,689 ) 6,879 (40,810 )
Geismar project relocation expenses and changes (60,857 ) - (60,857 )
Operating income 7,790 (9,204 ) (1,414 )
Earnings of associate - 5,799 5,799
Finance costs (17,764 ) 2,418 (15,346 )
Finance income and other expenses (3,398 ) (53 ) (3,451 )
Income before income tax expense (13,372 ) (1,040 ) (14,412 )
Income tax expense: -
Current (6,844 ) 1,714 (5,130 )
Deferred 21,661 (674 ) 20,987
14,817 1,040 15,857
Net income $ 1,445 $ - $ 1,445
Change in fair value of forward exchange contracts, net of tax 528 - 528
Change in fair value of interest rate swap contracts, net of tax (1,744 ) - (1,744 )
Realized loss on interest rate swap contracts reclassified to finance costs, net of tax 2,719 - 2,719
Comprehensive income $ 2,948 $ - $ 2,948
Attributable to:
Methanex Corporation shareholders (1,458 ) - (1,458 )
Non-controlling interests 4,406 - 4,406
$ 2,948 $ - $ 2,948
Consolidated Statement of Income and Comprehensive Income
Nine months ended September 30, 2012
As Previously Stated Restatement of Atlas to Equity Method As Adjusted
Revenue $ 1,977,300 $ (102,043 ) $ 1,875,257
Cost of sales and operating expenses (1,614,320 ) 78,781 (1,535,539 )
Depreciation and amortization (130,092 ) 15,317 (114,775 )
Geismar project relocation expenses and changes (64,543 ) - (64,543 )
Operating income 168,345 (7,945 ) 160,400
Loss of associate - (214 ) (214 )
Finance costs (56,434 ) 7,465 (48,969 )
Finance income and other expenses (2,012 ) 118 (1,894 )
Income before income tax expense 109,899 (576 ) 109,323
Income tax expense:
Current (22,001 ) 721 (21,280 )
Deferred 12,503 (145 ) 12,358
(9,498 ) 576 (8,922 )
Net income $ 100,401 $ - $ 100,401
Change in fair value of forward exchange contracts, net of tax (343 ) - (343 )
Change in fair value of interest rate swap contracts, net of tax (5,104 ) - (5,104 )
Realized loss on interest rate swap contracts reclassified to finance costs, net of tax 8,421 - 8,421
Comprehensive income $ 103,375 $ - $ 103,375
Attributable to:
Methanex Corporation shareholders 73,395 - 73,395
Non-controlling interests 29,980 - 29,980
$ 103,375 $ - $ 103,375

b) Effective January 1, 2013, the Company adopted IFRS 13, Fair Value Measurements. As a result of this new standard, incremental disclosures have been provided in note 10 to these condensed consolidated interim financial statements.

c) Effective January 1, 2013, the Company adopted the revised IFRS 19, Employee Benefits. The adoption of this standard has not had a significant impact on the Company.

d) Effective January 1, 2013, the Company adopted the revised IAS, Presentation of Financial Statements. The adoption of this standard has resulted in a change to the presentation of the Company's Consolidated Statements of Comprehensive Income.

12. Subsequent Event:

On October 22, 2013, the Company agreed to sell a 10% interest in Egyptian Methanex Methanol Company S.A.E. (EMethanex) for cash proceeds of $110 million. The sale is subject to the completion of certain conditions precedent. Methanex will continue to account for EMethanex using consolidation accounting and as a result will recognize the difference between the proceeds received and the carrying value of its investment as a change in shareholders' equity.

Methanex Corporation
Quarterly History (unaudited)
YTD 2013 Q3 2013 Q2 2013 Q1 2013
2012
Q4 Q3 Q2 Q1 2011 Q4 Q3 Q2 Q1
METHANOL SALES VOLUMES
(thousands of tonnes)
Methanex-produced 3,085 1,040 1,021 1,024 4,039 1,059 1,053 1,001 926 3,853 1,052 983 970 848
Purchased methanol 2,052 715 749 588 2,565 664 641 569 691 2,815 644 672 664 835
Commission sales 1 698 237 242 219 855 176 205 276 198 846 208 235 231 172
5,835 1,992 2,012 1,831 7,459 1,899 1,899 1,846 1,815 7,514 1,904 1,890 1,865 1,855
METHANOL PRODUCTION
(thousands of tonnes)
New Zealand 1,019 349 361 309 1,108 378 346 210 174 830 211 209 207 203
Atlas, Trinidad (63.1%) 703 254 201 248 826 180 255 264 127 891 195 170 263 263
Titan, Trinidad 478 128 169 181 786 189 186 196 215 711 180 224 186 121
Egypt (60%) 464 168 163 133 557 129 62 164 202 532 132 191 178 31
Medicine Hat 390 130 129 131 481 132 117 118 114 329 130 125 74 -
Chile 96 6 29 61 313 59 59 82 113 554 113 116 142 183
3,150 1,035 1,052 1,063 4,071 1,067 1,025 1,034 945 3,847 961 1,035 1,050 801
AVERAGE REALIZED METHANOL PRICE 2
($/tonne) 424 438 425 412 382 389 373 384 382 374 388 377 363 367
($/gallon) 1.28 1.32 1.28 1.24 1.15 1.17 1.12 1.15 1.15 1.12 1.17 1.13 1.09 1.10
PER SHARE INFORMATION ($ per share) 3
Basic net income (loss) 2.12 0.91 0.57 0.64 (0.73) (1.49) (0.03) 0.56 0.24 2.16 0.69 0.67 0.44 0.37
Diluted net income (loss) 2.09 0.90 0.56 0.63 (0.73) (1.49) (0.03) 0.50 0.23 2.06 0.68 0.59 0.43 0.37
Adjusted net income 4 3.16 1.22 1.02 0.92 1.90 0.64 0.38 0.47 0.41 1.93 0.69 0.43 0.41 0.39
1 Commission sales represent volumes marketed on a commission basis related to the 36.9% of the Atlas methanol facility and 40% of the Egypt methanol facility that we do not own.
2 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 volumes of Methanex-produced (attributable to Methanex shareholders) and purchased methanol.
3 Per share information calculated using amounts attributable to Methanex shareholders.
4 This item is a non-GAAP measure that does not have any standardized meaning prescribed by GAAP and therefore is unlikely to be comparable to similar measures presented by other companies. Refer to the Additional Information - Supplemental Non-GAAP Measures section for a description of the non-GAAP measure and reconciliation to the most comparable GAAP measure.
Contact:
Methanex Corporation - Investor Inquiries
Sandra Daycock
Director, Investor Relations
604-661-2600
invest@methanex.com
www.methanex.com

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