Methanex Reports Third Quarter Results-Methanol Demand Healthy
(firmenpresse) - VANCOUVER, BRITISH COLUMBIA -- (Marketwire) -- 10/26/11 -- For the third quarter of 2011, Methanex (TSX: MX)(NASDAQ: MEOH)(SANTIAGO: METHANEX) reported Adjusted EBITDA1 of $134.8 million and net income attributable to Methanex shareholders of $62.3 million ($0.67 basic net income per common share and $0.59 per share on a diluted basis(2)). This compares with Adjusted EBITDA(1) of $103.7 million and net income attributable to Methanex shareholders of $40.5 million ($0.44 basic net income per common share and $0.43 per share on a diluted basis(2)) for the second quarter of 2011.
Bruce Aitken, President and CEO of Methanex commented, "Our new Egypt and Medicine Hat plants operated very well, making a significant contribution to our earnings. In addition, methanol demand and pricing were higher in the third quarter. Entering the fourth quarter, methanol demand continues to be healthy and the longer term outlook is excellent, as there is little new capacity being added to the industry over the next few years to meet expected demand growth."
Mr. Aitken concluded, "We have a healthy balance sheet with US$261 million of cash on hand and an undrawn credit facility. With the additions of Egypt and Medicine Hat earlier this year, we are in a stronger position to generate cash flows, invest in strategic opportunities to grow the Company, and continue to deliver on our commitment to return excess cash to shareholders."
A conference call is scheduled for October 27, 2011 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) 695-6616, or toll free at (800) 396-7098. A playback version of the conference call will be available for three weeks at (905) 694-9451, or toll free at (800) 408-3053. The passcode for the playback version is 1632584. There will be a simultaneous audio-only webcast of the conference call, which can be accessed from our website at . The webcast will be available on our 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", on the NASDAQ Global Market in the United States under the trading symbol "MEOH", and on the foreign securities market of the Santiago Stock Exchange in Chile under the trading symbol "Methanex". Methanex can be visited online at .
FORWARD-LOOKING INFORMATION WARNING
This Third Quarter 2011 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 2011 Management's Discussion and Analysis for more information.
THIRD QUARTER MANAGEMENT'S DISCUSSION AND ANALYSIS
Except where otherwise noted, all currency amounts are stated in United States dollars. This Third Quarter 2011 Management's Discussion and Analysis ("MD&A") dated October 26, 2011 for Methanex Corporation ("the Company") should be read in conjunction with the Company's condensed consolidated interim financial statements for the periods ended September 30, 2011, June 30, 2011 and March 31, 2011, which are prepared in accordance with International Accounting Standards (IAS) 34, Interim Financial Reporting, as issued by the International Accounting Standards Board (IASB), as well as the 2010 Annual Consolidated Financial Statements and the MD&A included in the Methanex 2010 Annual Report, which were prepared in accordance with Canadian generally accepted accounting principles (Canadian GAAP). The Methanex 2010 Annual Report and additional information relating to Methanex is available on SEDAR at and on EDGAR at . For a discussion of the Company's adoption of International Financial Reporting Standards (IFRS), refer to the International Financial Reporting Standards (IFRS) section of this MD&A.
Chile
During the third quarter of 2011, we produced 116,000 tonnes in Chile operating one plant at approximately 40% capacity. We continue to operate our methanol facilities in Chile significantly below site capacity. This is primarily due to curtailments of natural gas supply from Argentina - refer to the Management's Discussion and Analysis included in our 2010 Annual Report for more information.
Lower production at our Chile facilities during the third quarter of 2011 compared with the second quarter of 2011 was due to the need for the state-owned energy company Empresa Nacional del Petroleo (ENAP) to satisfy incremental natural gas demand for residential purposes in southern Chile during the winter season when residential energy demand is at its peak, as well as declines in the deliverability from existing gas fields. Lower methanol production in Chile for the first nine months of 2011 compared with the same period in 2010 is due primarily to lower gas deliveries from ENAP and declines in deliverability from existing gas fields.
Our goal is to progressively increase production at our Chile site with natural gas from suppliers in Chile. We are pursuing investment opportunities with ENAP, GeoPark Chile Limited (GeoPark) and others to help accelerate natural gas exploration and development in southern Chile. We are working with ENAP to develop natural gas in the Dorado Riquelme block. Under the arrangement, we fund a 50% participation in the block and, as at September 30, 2011, we had contributed approximately $105 million. Over the past few years, we have also provided GeoPark with $57 million (of which approximately $40 million had been repaid at September 30, 2011) to support and accelerate GeoPark's natural gas exploration and development activities. GeoPark has agreed to supply us with all natural gas sourced from the Fell block under a ten-year exclusive supply arrangement that commenced in 2008. During the third quarter of 2011, substantially all production at our Chilean facilities was produced with natural gas supplied from the Fell and Dorado Riquelme blocks.
Other investment activities are also supporting the acceleration of natural gas exploration and development in areas of southern Chile. In late 2007, the government of Chile completed an international bidding round to assign oil and natural gas exploration areas that lie close to our production facilities and announced the participation of several international oil and gas companies. For two of the exploration blocks, we are participating in a consortium with other international oil and gas companies with GeoPark as the operator. We have approximately 15% participation in the consortium and at September 30, 2011, we had contributed $3 million for our share of the exploration costs. In 2010, the Chilean government initiated a new round allocating further exploration acreage to international oil and gas companies. Contracts for these new exploration areas are currently under negotiation.
While significant investments have been made in the last few years for natural gas exploration and development in southern Chile, the timelines for significant increases in gas production are much longer than we had originally anticipated and existing gas fields are experiencing declines. As a result, the short-term outlook for gas supply in Chile continues to be challenging. We are examining the viability of utilizing coal gasification as a feedstock and relocation of capacity to an alternative location.
The future operating rate of our Chile site is primarily dependent on demand for natural gas for residential purposes, which is higher in the southern hemisphere winter, production rates from existing natural gas fields, and the level of natural gas deliveries from future exploration and development activities in southern Chile. We cannot provide assurance regarding the production rates from existing natural gas fields or that we, ENAP, GeoPark or others will be successful in the exploration and development of natural gas or that we will obtain any additional natural gas from suppliers in Chile on commercially acceptable terms. As a result, we cannot provide assurance in the level of natural gas supply or that we will be able to source sufficient natural gas to operate any capacity in Chile or that we will have sufficient future cash flows from Chile to support the carrying value of our Chilean assets and that this will not have an adverse impact on our results of operations and financial condition.
Trinidad
Our equity ownership of methanol facilities in Trinidad represents over 2.0 million tonnes of cost-competitive annual capacity. During the third quarter of 2011 we produced 394,000 tonnes compared with 449,000 tonnes during the second quarter of 2011. Lower production in the third quarter of 2011 compared with the second quarter of 2011 was primarily due to an unplanned outage at our Atlas facility which lasted approximately 21 days. We restarted operations at the Atlas facility in mid-August and have since operated the plant at approximately 70% of capacity. We expect to maintain operating the plant at approximately 70% of capacity until the next major turnaround currently scheduled for early 2012. Although our Titan facility operated at full capacity during the third quarter we did experience some gas curtailments late in the third quarter and into the fourth quarter due to upstream outages. We are engaged with key stakeholders to find a solution to this issue, but in the meantime expect to continue to experience some gas curtailments to our Trinidad site.
New Zealand
Our New Zealand facilities provide cost-competitive capacity and are underpinned by shorter term natural gas supply contracts. During the third quarter of 2011, we produced 209,000 tonnes compared with 207,000 tonnes during the second quarter of 2011. We are currently operating one 850,000 tonne per year plant at our Motunui facility in New Zealand and we have natural gas contracts with a number of gas suppliers that will allow us to continue to operate this plant through 2012. We also have an additional 1.38 million tonnes per year of idled capacity in New Zealand, including a second 850,000 tonne per year Motunui plant and a 530,000 tonne per year plant at our nearby site in Waitara Valley. These facilities provide the potential to increase production in New Zealand depending on the methanol supply and demand dynamics and the availability of economically priced natural gas feedstock. We believe there has been continued improvement in the natural gas supply outlook in New Zealand and we are focused on accessing additional natural gas supply to increase production in New Zealand. We are continuing to pursue opportunities to obtain economically priced natural gas with suppliers in New Zealand to operate a second plant.
Egypt
The 1.26 million tonne per year methanol plant in Egypt commenced commercial operations in mid-March and has continued to operate well since that time. During the third quarter of 2011, the Egypt methanol facility (60% interest) produced 191,000 tonnes compared with 178,000 tonnes during the second quarter of 2011. We have a 60% interest in the facility and have marketing rights for 100% of the production.
Medicine Hat
Our 470,000 tonne per year facility in Medicine hat, Alberta was restarted in late April 2011, and has continued to operate well since that time. During the third quarter of 2011, we produced 125,000 tonnes compared with 74,000 tonnes during the second quarter of 2011. We have a program in place to purchase natural gas on the Alberta gas market and we have contracted sufficient volumes of natural gas to meet over 80% of our natural gas requirements when operating at capacity for the period to March 2013 with the remainder of natural gas purchased on the spot market. We believe that the long term natural gas dynamics in North America will support the long term operation of this facility.
FINANCIAL RESULTS
For the third quarter of 2011, we recorded Adjusted EBITDA of $134.8 million and net income attributable to Methanex Corporation shareholders of $62.3 million ($0.67 basic net income per common share and $0.59 per share on a diluted basis). This compares with Adjusted EBITDA of $103.7 million and net income attributable to Methanex Corporation shareholders of $40.5 million ($0.44 basic net income per common share and $0.43 per share on a diluted basis) and Adjusted EBITDA of $55.9 million and net income attributable to Methanex Corporation shareholders of $28.7 million ($0.31 basic and diluted net income per common share) for the second quarter of 2011 and third quarter of 2010, respectively.
For the nine months ended September 30, 2011, we recorded Adjusted EBITDA of $316.4 million and net income attributable to Methanex Corporation shareholders of $137.5 million ($1.48 basic net income per common share and $1.38 per share on a diluted basis). This compares with Adjusted EBITDA of $199.0 million and net income attributable to Methanex Corporation shareholders of $70.5 million ($0.76 basic net income per common share and $0.75 per share on a diluted basis) during the same period in 2010.
For the three and nine month periods ended September 30, 2011, share-based compensation created additional volatility in our earnings due to significant changes in our share price. We grant share-based awards as an element of compensation and, as more fully discussed in the Share-based compensation section, certain of these awards are marked to market each quarter with the changes in fair value recognized in earnings for the proportion of the service that has been rendered at the reporting date. During the third quarter of 2011, our share price experienced a significant decline and this resulted in a share-based compensation recovery. The amount of share-based compensation expense (recovery) included in net income and Adjusted EBITDA is as follows:
Included in the share-based compensation expense (recovery) is the fair value adjustment related to tandem share appreciation rights (TSARs). TSARs are share-based awards that may be settled in cash or common shares at the holder's option. TSARs are accounted for as if they are cash-settled and as a result, a fair value adjustment is included in share-based compensation expense (recovery) each quarter. For purposes of calculating diluted net income per common share, the more dilutive of the cash-settled method or equity-settled method is used. For the three and nine month periods ended September 30, 2011, diluted net income per common share is lower than basic net income per common share by $0.08 and $0.10, respectively, primarily due to the impact of TSARs being treated as equity-settled for purposes of calculating diluted net income per common share. See note 8 of the Company's condensed consolidated interim financial statements for the calculation of diluted net income per common share.
EARNINGS ANALYSIS
Our operations consist of a single operating segment - the production and sale of methanol. In addition to the methanol that we produce at our facilities, we also purchase and re-sell methanol produced by others 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 change in our Adjusted EBITDA for methanol sales are average realized price, sales volume and cash costs.
We own 60% of the 1.26 million tonne per year Egypt methanol facility and 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' interest in the methanol facility being presented as "non-controlling interests." For purposes of reviewing our operations, we analyze Adjusted EBITDA in the discussion below excluding the amounts associated with the other investors' 40% non-controlling interest.
For a further discussion of the definitions and calculations used in our Adjusted EBITDA analysis, refer to How We Analyze Our Business. Also, refer to the Supplemental Non-IFRS Measures section for a reconciliation of Adjusted EBITDA to the most comparable IFRS measure.
Adjusted EBITDA (attributable to Methanex shareholders)
The changes in Adjusted EBITDA resulted from changes in the following:
Average realized price
Throughout the third quarter of 2011, methanol demand continued to be healthy despite the increase in concern around the global economy. Industry supply and demand conditions are favorable, and as a result, the pricing environment has been relatively stable (refer to Supply/Demand Fundamentals section for more information). Our average non- discounted posted price for the third quarter of 2011 was $445 per tonne compared with $421 per tonne for the second quarter of 2011 and $334 per tonne for the third quarter of 2010. Our average realized price for the third quarter of 2011 was $377 per tonne compared with $363 per tonne for the second quarter of 2011 and $286 per tonne for the third quarter of 2010. The change in our average realized price for the third quarter of 2011 increased Adjusted EBITDA by $22 million compared with the second quarter of 2011 and increased Adjusted EBITDA by $151 million compared with the third quarter of 2010. Our average realized price for the nine months ended September 30, 2011 was $369 per tonne compared with $291 per tonne for the same period in 2010 and this increased Adjusted EBITDA by $388 million.
Sales volume
Total methanol sales volumes excluding commission sales volumes for the third quarter of 2011 were comparable to the second quarter of 2011 and the third quarter of 2010. Total methanol sales volumes excluding commission sales were higher for the nine months ended September 30, 2011 compared with the nine months ended September 30, 2010 by 189,000 tonnes and this increased Adjusted EBITDA by $12 million. We increased our sales volumes in 2011 compared with 2010 primarily as a result of increased supply from the Egypt and Medicine Hat methanol facilities.
Total cash costs
The primary driver of changes in our total cash costs are changes in the cost of methanol we produce at our facilities and changes in the cost of methanol we purchase from others. Most of our production facilities are underpinned by natural gas purchase agreements with pricing terms that include base and variable price components. The variable component is adjusted in relation to changes in methanol prices above pre-determined prices at the time of production. 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 natural gas costs and purchased methanol costs will 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:
Methanex-produced methanol costs
We purchase natural gas for the Chile, Trinidad, Egypt and New Zealand methanol facilities under natural gas purchase agreements where the terms include a base price and a variable price component linked to the price of methanol. For all periods presented, changes in natural gas costs associated with produced methanol were primarily due to the impact of changes in methanol prices and the timing of inventory flows.
Proportion of produced methanol sales
The cost of purchased methanol is generally higher than the cost of produced methanol. Accordingly, an increase in the proportion of produced methanol sales results in a decrease in our overall cost structure for a given period. For the third quarter of 2011 compared with the second quarter of 2011, the impact of higher sales volumes from our Egypt and Medicine Hat facilities was offset by lower sales of methanol produced at our Atlas and Chile facilities. For the third quarter of 2011 compared with the third quarter of 2010, higher sales of produced methanol, primarily due to the impact of sales volumes from the Egypt and Medicine Hat facilities, increased EBITDA by $12 million.
For the nine month period ended September 30, 2011 compared with nine month period ended September 30, 2010, the impact of higher sales volumes from our Egypt and Medicine Hat facilities was offset by lower sales of methanol produced at our Chile and Titan facilities.
Purchased methanol costs
Purchased methanol costs were higher for all periods presented primarily as a result of higher methanol pricing.
Logistics costs
For the third quarter of 2011 compared with the second quarter of 2011, logistics costs were similar. For the three and nine month periods ended September 30, 2011 compared with same periods in 2010, logistics costs were higher by $4 million and $16 million, respectively, due primarily to higher bunker fuel costs.
Other, net
For the third quarter of 2011 and the nine month period ended September 30, 2011 compared with the comparable periods in 2010, other costs were higher primarily as a portion of fixed manufacturing costs were charged directly to earnings rather than to inventory due to lower production at our facilities in Chile and Trinidad as well as the impact of a weaker US dollar on the cost structure of our operations.
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 stock options, the cost is measured based on an estimate of the fair value at the date of grant using the Black-Scholes option pricing model and this grant-date fair value is recognized as compensation expense over the related service period with no subsequent re-measurement in fair value. Accordingly, share-based compensation expense associated with stock options will not vary significantly from period to period. Commencing in 2010, we granted share appreciation rights (SARs) and tandem share appreciation rights (TSARs) to replace grants of stock options with the objective to reduce dilution to shareholders. SARs and TSARs are units that grant the holder the right to receive a cash payment upon exercise for the difference between the market price of the Company's common shares and the exercise price, which is determined at the date of grant. SARs and TSARs are measured based on estimated fair value each quarter, which is determined using the Black-Scholes option pricing model.
Deferred, restricted and performance share units are grants of notional common shares that are redeemable for cash upon vesting based on the market value of the Company's common shares and are non-dilutive to shareholders. Performance share units have an additional feature where the ultimate number of units that vest will be determined by the Company's total shareholder return in relation to a predetermined target over the period to vesting. The number of units that will ultimately vest will be in the range of 50% to 120% of the original grant. For deferred, restricted and performance share units, the fair value is initially measured at the grant date and subsequently re-measured each quarter based on the market value of the Company's common shares.
For all the share-based awards with the exception of stock options, the initial value and any subsequent change in fair value is recognized in earnings over the related service period for the proportion of the service that has been rendered at each reporting date. Accordingly, share-based compensation associated with these share-based awards may vary significantly from period to period as a result of changes in the share price.
As a result of the decrease in our share price during the third quarter of 2011, we recorded a share-based compensation recovery of $21 million. This compares with share-based compensation expense of $2 million for the second quarter of 2011 and $9 million for the third quarter of 2010. For the nine month period ending September 30, 2011, we recorded a share-based compensation recovery of $9 million compared with a share-based compensation expense of $18 million for the same period in 2010.
Depreciation and Amortization
Depreciation and amortization was $44 million for the third quarter of 2011 compared with $40 million for the second quarter of 2011 and $35 million for the third quarter of 2010. The increase in depreciation and amortization for both periods is primarily a result of the commencement of depreciation associated with the methanol facilities in Egypt (100% basis) and Medicine Hat and higher unabsorbed depreciation attributable to an unplanned outage at our Atlas facility which lasted approximately 21 days.
Depreciation and amortization was $113 million for the nine month period ended September 30, 2011 compared with $106 million in the same period in 2010 primarily due to the commencement of depreciation associated with the methanol facilities in Egypt (100% basis) and Medicine Hat.
Finance Costs
Capitalized interest relates to interest costs capitalized during the construction of the 1.26 million tonne per year methanol facility in Egypt (100% basis). The Egypt methanol facility commenced production in mid-March 2011 and accordingly, we ceased capitalization of interest costs from this date.
Finance Income and Other Expenses
Finance income and other expenses for the third quarter of 2011 was $2 million expense compared with $1 million income for the second quarter of 2011 and a $1 million expense for the third quarter of 2010. Finance income and other expenses for the nine month period ended September 30, 2011 was $5 million income compared with nil for the nine month period ended September 30, 2010. 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
The effective tax rate for the third quarter of 2011 was approximately 20% compared with approximately 25% for the second quarter of 2011. 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%. Our Atlas facility in Trinidad has partial relief from corporation income tax until 2014. During the third quarter of 2011, we earned a higher proportion of our consolidated income from methanol produced in Canada and New Zealand, where we have unrecognized loss carryforwards, and this contributed to a lower effective tax rate compared with the second quarter of 2011.
In Chile the tax rate consists of a first tier tax that is payable when income is earned and a second tier tax that is due when earnings are distributed from Chile. The second tier tax is initially recorded as future income tax expense and is subsequently reclassified to current income tax expense when earnings are distributed.
SUPPLY/DEMAND FUNDAMENTALS
We estimate that methanol demand is growing at a rate of approximately 6% in 2011 and is currently approximately 49 million tonnes on an annualized basis. Increases in demand have been driven by both traditional and energy derivatives in Asia (particularly in China). Entering the fourth quarter of 2011, despite recent elevated concerns around the global economic outlook, we have not seen any significant impact on global methanol demand.
Traditional derivatives account for about two-thirds of global methanol demand and are correlated to industrial production.
Energy derivatives account for about one third of global methanol demand and over the last few years high energy prices have driven strong demand growth for methanol into energy applications such as gasoline blending and DME, primarily in China. Methanol blending into gasoline in China has been particularly strong and we believe that future growth in this application is supported by recent regulatory changes in that country. Many provinces in China have implemented fuel blending standards, and an M85 (or 85% methanol) national standard took effect December 1, 2009. We believe demand potential into energy derivatives will be stronger in a high energy price environment.
During the third quarter of 2011, as a result of steady demand and planned and unplanned industry outages, market conditions were favorable and pricing was stable. Our average non-discounted price for October 2011 is approximately $458 per tonne and we recently announced our North America non-discounted price for November at $459 per tonne, which is unchanged from October.
Over the next few years, there is little new capacity expected to come on-stream outside China. There is a 0.85 million tonne plant expected to restart in Beaumont, Texas in 2012 and a 0.7 million tonne plant expected to start up in Azerbaijan in 2014. 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.
LIQUIDITY AND CAPITAL RESOURCES
Consolidated cash flows from operating activities in the third quarter of 2011 were $119.1 million compared with $77.6 million for the second quarter of 2011 and $61.4 million for the third quarter of 2010. The change in consolidated cash flows from operating activities in the third quarter of 2011 compared with the second quarter of 2011 and the third quarter of 2010 is primarily a result of changes in Adjusted EBITDA, excluding share based compensation expense (recovery), and changes in non-cash working capital.
Adjusted cash flows from operating activities, which excludes the amounts associated with the 40% non-controlling interests in the methanol facility in Egypt and changes in non-cash working capital, were $103.6 million in the third quarter of 2011 compared with $86.5 million for the second quarter of 2011 and $64.7 million for the third quarter of 2010. The change in Adjusted cash flows from operating activities in the third quarter of 2011 compared with the second quarter of 2011 and the third quarter of 2010 is primarily a result of changes in Adjusted EBITDA, excluding share based compensation expense (recovery). Refer to the Supplemental Non-IFRS Measures section for a reconciliation of Adjusted cash flows from operating activities to the most comparable IFRS measure.
During the third quarter of 2011, we paid a quarterly dividend of $0.17 per share, or $16 million.
The Egypt limited recourse debt facilities required that certain conditions associated with plant construction and commissioning be met by September 30, 2011 ("project completion"). Project completion was achieved during the third quarter of 2011. In connection with achieving project completion, we agreed to a covenant to complete by March 31, 2012 certain land title registrations and related mortgages which require action by Egyptian government entities. We do not believe that the finalization of these items is material and will seek a waiver from the lenders if not completed by March 31, 2012. We cannot assure you that the land title registrations and related mortgages will be finalized by March 31, 2012 or that we would be able to obtain a waiver from the lenders.
During the third quarter of 2011, a debt principal payment of $16.1 million was paid on the Egypt credit facility and $29 million (Methanex share $17 million) was contributed to fund the related debt service reserve account.
At September 30, 2011, management believes the Company was in compliance with all of the covenants and default provisions related to its long-term debt obligations.
We have agreements in place to participate in or support natural gas exploration and development in southern Chile and during the third quarter of 2011, we spent $4 million to support these initiatives.
We operate in a highly competitive commodity industry and believe it is appropriate to maintain a conservative balance sheet and to maintain financial flexibility. Our cash balance at September 30, 2011 was $261 million. We have a strong balance sheet and an undrawn $200 million credit facility provided by highly rated financial institutions that was extended early in the third quarter of 2011 to mid-2015. We intend to refinance the $200 million notes due August 2012. 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. Our planned capital maintenance expenditure program directed towards major maintenance, turnarounds and catalyst changes for existing operations, is currently estimated to total approximately $70 million for the period to the end of 2012.
We believe we are well positioned to meet our financial commitments and continue to invest to grow the Company.
SHORT-TERM OUTLOOK
As we enter the fourth quarter, despite recent elevated concerns around the global economic outlook, we have not seen any significant impact on global methanol demand.
We increased our production in 2011 with the new 1.26 million tonne per year methanol facility in Egypt and our 470,000 tonne per year plant in Medicine Hat, Alberta. These facilities are operating well and have increased our earnings capability. This will be partially offset in the short-term by the impact of our Atlas facility producing at reduced rates until the next scheduled turnaround currently planned for early 2012.
The methanol price will ultimately depend on the strength of the global economy, industry operating rates, global energy prices, new supply additions, the rate of industry restructuring 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, 2011, 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.
INTERNATIONAL FINANCIAL REPORTING STANDARDS (IFRS)
Transition from Canadian generally accepted accounting principles (Canadian GAAP) to IFRS
The first quarter of 2011 ended March 31, 2011 with comparative financial results for 2010 was our first interim period reported under IFRS. All comparative figures in this third quarter interim report have been restated to be in accordance with IFRS, unless specifically noted otherwise.
Our financial statements were prepared in accordance with Canadian GAAP until December 31, 2010. While IFRS uses a conceptual framework similar to Canadian GAAP, there are significant differences in recognition, measurement and disclosures. In our MD&A in the 2010 Annual Report, we disclosed the significant impacts on transition to IFRS. The disclosure in our MD&A in the 2010 Annual Report is consistent with the impacts disclosed in the condensed consolidated interim financial statements. For a description of the significant accounting policies the Company has adopted under IFRS, including the estimates and judgments we consider most significant in applying those accounting policies, please refer to note 2 of the condensed consolidated interim financial statements included in the interim report for the three months ended March 31, 2011.
The adoption of IFRS resulted in some changes to the consolidated balance sheets and income statements of the Company previously reported under Canadian GAAP. To help users of the financial statements better understand the impact of the adoption of IFRS on the Company, we have provided reconciliations from Canadian GAAP to IFRS for total assets, liabilities, and equity, as well as net income and comprehensive income for the comparative reporting periods. Please refer to note 12 of the condensed consolidated interim financial statements for the reconciliations between IFRS and Canadian GAAP for the period ended September 30, 2010 and refer to note 18 of the condensed consolidated interim financial statements for the period ended March 31, 2011 for the reconciliations between IFRS and Canadian GAAP at the date of transition, January 1, 2010 and for the year ended December 31, 2010.
IFRS 1 First-time Adoption of International Financial Reporting Standards
Adoption of IFRS requires the application of IFRS 1, First-time Adoption of International Financial Reporting Standards, which provides guidance for an entity's initial adoption of IFRS. IFRS 1 gives entities adopting IFRS for the first time a number of optional exemptions and mandatory exceptions, in certain areas, to the general requirement for full retrospective application of IFRS. In our MD&A in the 2010 Annual Report, we disclosed the optional exemptions available under IFRS 1 that we elected on transition to IFRS. The elections as previously disclosed are consistent with the elections as disclosed in the condensed consolidated interim financial statements. Please refer to note 12 of the condensed consolidated interim financial statements for a detailed description of the IFRS 1 exemptions we elected to apply.
IFRS Conversion
Our plan to convert our consolidated financial statements to IFRS at the change over date of January 1, 2011 with comparative financial results included a formal project governance structure that included the Audit, Finance and Risk Committee, senior management, and an IFRS steering committee to monitor progress and review and approve recommendations. The IFRS transition plan progressed according to schedule and was comprehensive and addressed topics such as the impact of IFRS on accounting policies and implementation decisions, infrastructure, business activities, compensation matters and control activities.
Anticipated changes to IFRS
Consolidation and Joint Arrangement Accounting
In May 2011, the IASB issued new accounting standards related to consolidation and joint arrangement accounting. The IASB has revised the definition of "control," which is a criterion for consolidation accounting. In addition, changes to IFRS in the accounting for joint arrangements were issued which, under certain circumstances, removed the option for proportionate accounting so that the equity method of accounting for such interests would need to be applied. The impact of applying consolidation accounting or equity accounting does not result in any change to net earnings or shareholders' equity, but would result in a significant presentation impact. We are currently assessing the impact of these standards on our financial statements. The effective date for these standards is for periods commencing on or after January 1, 2013, with earlier adoption permitted.
Leases
As part of their global conversion project, the International Accounting Standards Board (IASB) and the U.S. Financial Accounting Standards Board ("FASB") issued a joint Exposure Draft proposing that lessees would be required to recognize all leases on the statement of financial position. We have a fleet of ocean-going vessels under time charter agreements with terms of up to 15 years, which are currently accounted for as operating leases. The proposed rules would require these time charter agreements to be recorded on the Consolidated Statements of Financial Position, resulting in a material increase to total assets and liabilities. The IASB and FASB currently expect to issue a final standard in 2012.
ADDITIONAL INFORMATION - SUPPLEMENTAL NON-IFRS MEASURES
In addition to providing measures prepared in accordance with International Financial Reporting Standards (IFRS), we present certain supplemental non-IFRS measures. These are Adjusted EBITDA and Adjusted cash flows from operating activities. These measures do not have any standardized meaning prescribed by IFRS and therefore are unlikely to be comparable to similar measures presented by other companies. These supplemental non-IFRS measures are provided to assist readers in determining our ability to generate cash from operations. 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.
These measures should be considered in addition to, and not as a substitute for, net income, cash flows and other measures of financial performance and liquidity reported in accordance with IFRS.
Adjusted EBITDA (attributable to Methanex shareholders)
Adjusted EBITDA differs from the most comparable IFRS measure, cash flows from operating activities, because it does not include changes in non-cash working capital, other cash payments related to operating activities, other non-cash items, taxes paid, finance income and other expenses, and Adjusted EBITDA associated with the 40% non-controlling interest in the methanol facility in Egypt and because cash flows from operating activities does not include share-based compensation expense.
The following table shows a reconciliation of cash flows from operating activities to Adjusted EBITDA:
Adjusted Cash Flows from Operating Activities (attributable to Methanex shareholders)
Adjusted cash flows from operating activities differs from the most comparable IFRS measure, cash flows from operating activities, because it does not include changes in non-cash working capital and cash flows associated with the 40% non- controlling interest in the methanol facility in Egypt.
The following table shows a reconciliation of cash flows from operating activities to Adjusted cash flows from operating activities:
QUARTERLY FINANCIAL DATA (UNAUDITED)
A summary of selected financial information for the prior eight quarters is as follows:
FORWARD-LOOKING INFORMATION WARNING
This Third Quarter 2011 Management's Discussion and Analysis ("MD&A") as well as comments made during the Third Quarter 2011 investor conference call contain forward-looking statements with respect to us and our industry. Statements that include the words "believes," "expects," "may," "will," "should," "intends," "plans," "estimates," "anticipates," 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:
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:
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:
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 our adjusted earnings before interest, taxes, depreciation and amortization (Adjusted EBITDA) (refer to the Supplemental Non-IFRS Measures section for a reconciliation to the most comparable IFRS measure), depreciation and amortization, finance costs, finance income and other expenses, and income taxes.
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 change in our Adjusted EBITDA are average realized price, cash costs and sales volume which are defined and calculated as follows:
PRICE
The change in our 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 income.
CASH COST
The change in our 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. 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 our 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 our 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% through a commission offtake agreement. We account for this investment using proportionate consolidation which results in 63.1% of the revenues and expenses being included in our financial statements with the remaining 36.9% portion included as commission income.
We own 60% of the 1.26 million tonne per year Egypt methanol facility and market the remaining 40% 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' interest in the methanol facility being presented as "non-controlling interests". For purposes of analyzing our results, we analyze Adjusted EBITDA and Adjusted cash flows from operating activities excluding the amounts associated with the other investors' 40% non-controlling interest and include these results in commission income on a consistent basis with how we present the Atlas facility.
Methanex Corporation
Consolidated Statements of Income (unaudited)
(thousands of U.S. dollars, except number of common shares and per share amounts)
Methanex Corporation
Consolidated Statements of Comprehensive Income (unaudited)
(thousands of U.S. dollars, except number of common shares and per share amounts)
Methanex Corporation
Consolidated Statements of Financial Position (unaudited)
(thousands of U.S. dollars)
Methanex Corporation
Consolidated Statements of Changes in Equity (unaudited)
(thousands of U.S. dollars, except number of common shares)
Methanex Corporation
Consolidated Statements of Cash Flows (unaudited)
(thousands of U.S. dollars)
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:
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 the significant accounting policies disclosed in note 2 of the March 31, 2011 interim financial statements and therefore should be read in conjunction with the condensed consolidated interim financial statements for the period ended March 31, 2011. These condensed consolidated interim financial statements are part of the period covered by the Company's first International Financial Reporting Standards (IFRS) consolidated financial statements for the year ending December 31, 2011 and therefore IFRS 1, First Time Adoption of IFRS has been applied. The 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 26, 2011.
The Company's condensed consolidated interim financial statements were prepared in accordance with accounting principles generally accepted in Canada (Canadian GAAP) until December 31, 2010. The period ended March 31, 2011, with comparative results for 2010, was the Company's first IFRS condensed consolidated interim financial statements. Canadian GAAP differs from IFRS in some areas and accordingly, the significant accounting policies applied in the preparation of these condensed consolidated interim financial statements have been consistently applied to all periods presented except in instances where IFRS 1 either requires or permits an exemption. An explanation of how the transition from Canadian GAAP to IFRS has affected the reported consolidated statements of income, comprehensive income, financial position, and cash flows of the Company for the period ended September 30, 2010 is provided in note 12. This note includes information on the provisions of IFRS 1 and the exemptions that the Company elected to apply at the date of transition, January 1, 2010, and reconciliations of equity, net income and comprehensive income for the comparative periods ended September 30, 2010. For a summary of the impact of transition from Canadian GAAP to IFRS at the date of transition, January 1, 2010, as well as for the year ended December 31, 2010, refer to note 18 of the condensed consolidated interim financial statements for the first quarter of 2011 ended March 31, 2011.
These condensed consolidated interim financial statements include the Egypt methanol facility on a consolidated basis, with the other investors' 40% share presented as non-controlling interest and our proportionate share of the Atlas methanol facility.
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, 2011 is $516 million (2010 - $405 million) and $1,513 million (2010 - $1,147 million), respectively.
3. Property, plant and equipment:
4. Interest in Atlas joint venture:
The Company has a 63.1% joint venture interest in Atlas Methanol Company (Atlas). Atlas owns a 1.7 million tonne per year methanol production facility in Trinidad. Included in the condensed consolidated interim financial statements are the following amounts representing the Company's proportionate interest in Atlas:
5. Long-term debt:
During the three and nine month periods ended September 30, 2011, the Company made repayments on its Egypt limited recourse debt facilities of $16.1 million and $31.7 million, respectively, and other limited recourse debt facilities of $0.6 million and $1.8 million, respectively. The Company also made repayments on its Atlas limited recourse debt facilities of $8.0 million during the nine month period ended September 30, 2011.
The covenants governing the Company's unsecured notes apply to the Company and its subsidiaries excluding the Atlas joint venture and Egypt entity ("limited recourse subsidiaries") and include restrictions on liens and sale and lease- back transactions, or merger or consolidation with another corporation or sale of all or substantially all of the Company's assets. The indenture also contains customary default provisions.
The Company has a $200 million unsecured revolving bank facility provided by highly rated financial institutions and this was extended in early July 2011 to May 2015. This facility contains covenant and default provisions in addition to those of the unsecured notes as described above. Significant covenants and default provisions under this facility include:
The Atlas and Egypt limited recourse debt facilities are described as limited recourse as they are secured only by the assets of the Atlas joint venture and the Egypt entity, respectively. Accordingly, the lenders to the limited recourse debt facilities have no recourse to the Company or its other subsidiaries. The Atlas and Egypt limited recourse debt facilities have customary covenants and default provisions which apply only to these entities including restrictions on the incurrence of additional indebtedness and a requirement to fulfill certain conditions before the payment of cash or other distributions.
The Egypt limited recourse debt facilities required that certain conditions associated with plant construction and commissioning be met by September 30, 2011 ("project completion"). Project completion was achieved during the third quarter of 2011. In connection with achieving project completion, we agreed to a covenant to complete by March 31, 2012 certain land title registrations and related mortgages which require action by Egyptian government entities. We do not believe that the finalization of these items is material and will seek a waiver from the lenders if not completed by March 31, 2012. We cannot assure you that the land title registrations and related mortgages will be finalized by March 31, 2012 or that we would be able to obtain a waiver from the lenders.
At September 30, 2011, management believes the Company was in compliance with all of the covenants and default provisions related to long-term debt obligations.
6. Expenses by function:
Included in total expenses for the three and nine month periods ended September 30, 2011 are employee expenses, including share-based compensation expense (recovery), of $13.0 million (2010 - $32.3 million) and $87.4 million (2010 - $94.5 million), respectively.
7. Finance costs:
Finance costs are primarily comprised of interest on borrowings and finance lease obligations, amortization of deferred financing fees, and accretion expense associated with site restoration costs. Interest during construction of the Egypt methanol facility was capitalized until the plant was substantially completed and ready for productive use in mid-March of 2011. 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 of September 28, 2007 to March 31, 2015. For the three and nine month periods ended September 30, 2011 interest costs of nil (2010 - $9.7 million) and $7.2 million (2010 - $28.3 million), respectively, related to this project were capitalized.
8. Net income per common share:
Diluted net income per common share is calculated by giving effect to the potential dilution that would occur if outstanding stock options and 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 cash-settled and equity-settled is used regardless of how the plan is accounted for. Accordingly, TSARs which are accounted for as cash-settled for accounting purposes will require an adjustment to the numerator and denominator if they are determined to have a dilutive effect on diluted net income per common share.
During the three and nine month periods ended September 30, 2011, the Company's share price declined and the Company recorded a share based compensation recovery related to TSARs. For these periods, the equity-settled method has been determined to be the more dilutive for purposes of calculating diluted net income per common share.
A reconciliation of the net income used for the purpose of calculating diluted net income per common share is as follows:
Stock options and TSARs are considered dilutive when the average market price of the Company's common shares during the period disclosed exceeds the exercise price of the stock option or TSAR. A reconciliation of the number of common shares used for the purposes of calculating basic and diluted net income per common share is as follows:
For the three and nine month periods ended September 30, 2011, basic and diluted net income per common share attributable to Methanex shareholders were as follows:
9. Share-based compensation:
a) Stock options:
(i) Outstanding stock options:
Common shares reserved for outstanding stock options at September 30, 2011:
Information regarding the stock options outstanding at September 30, 2011 is as follows:
(ii) Compensation expense related to stock options:
For the three and nine month periods ended September 30, 2011, compensation expense related to stock options included in cost of sales and operating expenses was $0.2 million (2010 - $0.3 million) and $0.7 million (2010 - $1.2 million), respectively. The fair value of the stock option grant was estimated on the date of grant using the Black-Scholes option pricing model.
(b) Share appreciation rights and tandem share appreciation rights:
During 2010, the Company's stock option plan was amended to include tandem share appreciation rights (TSARs) and a new plan was introduced for share appreciation rights (SARs). A SAR gives the holder a right to receive a cash payment equal to the amount the market price of the Company's common shares exceeds the exercise price. A TSAR gives the holder the choice between exercising a regular stock option or surrendering the option for a cash payment equal to the amount the market price of the Company's common shares exceeds the exercise price. All SARs and TSARs granted have a maximum term of seven years with one-third vesting each year after the date of grant.
(i) Outstanding SARs and TSARs:
SARs and TSARs outstanding at September 30, 2011:
(ii) Compensation expense related to SARs and TSARs:
Compensation expense for SARs and TSARs is initially measured based on their fair value and is recognized over the related service period. Changes in fair value each period are recognized in earnings for the proportion of the service that has been rendered at each reporting date. The fair value at September 30, 2011 was $5.6 million compared with the recorded liability of $4.0 million. The difference between the fair value and the recorded liability of $1.6 million will be recognized over the weighted average remaining service period of approximately 1.7 years. The weighted average fair value of the vested SARs and TSARs was estimated at September 30, 2011 using the Black-Scholes option pricing model.
For the three and nine month periods ended September 30, 2011, compensation expense related to SARs and TSARs included a recovery in cost of sales and operating expenses of $8.4 million (2010 - expense of $2.2 million) and $4.5 million (2010 - expense of $4.4 million), respectively.
(c) Deferred, restricted and performance share units:
Deferred, restricted and performance share units outstanding at September 30, 2011 are as follows:
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 related service period. Changes in fair value are recognized in earnings 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, 2011 was $39.5 million compared with the recorded liability of $34.9 million. The difference between the fair value and the recorded liability of $4.6 million will be recognized over the weighted average remaining service period of approximately 1.4 years.
For the three and nine month periods ended September 30, 2011, compensation expense related to deferred, restricted and performance share units included in cost of sales and operating expenses was a recovery of $12.2 million (2010 - expense of $6.4 million) and recovery of $4.8 million (2010 - expense of $12.4 million), respectively. This included a recovery of $13.8 million (2010 - expense of $4.6 million) and $12.1 million (2010 - expense of $4.5 million) related to the effect of the change in the Company's share price for the three and nine month periods ended September 30, 2011 respectively.
10. Changes in non-cash working capital:
Changes in non-cash working capital for the three and nine month periods ended September 30, 2011 were as follows:
11. Financial instruments:
The following table provides the carrying value of each category of financial assets and liabilities and the related balance sheet item:
At September 30, 2011, all of the Company's financial instruments are recorded on the balance sheet at amortized cost with the exception of cash and cash equivalents, derivative financial instruments and project financing reserve accounts included in other assets which are recorded at fair value.
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
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Datum: 26.10.2011 - 19:55 Uhr
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