CFK CE Franklin Ltd. (MM)

CALGARY, Oct. 27, 2011 /CNW/ - CE FRANKLIN LTD. (TSX.CFT, NASDAQ.CFK) reported net earnings of $4.8 million or $0.27 per share for the third quarter ended September 30, 2011 a significant increase from net earnings of $2.2 million or $0.12 per share generated in the third quarter ended September 30, 2010. Financial Highlights (millions of Cdn. $ except per share data) Three Months Ended Nine Months Ended September 30 September 30 2011 2010 2011 2010 Unaudited Unaudited Revenues 140.5 132.2 392.0 353.9 Gross Profit 23.9 19.2 65.4 54.5 Gross Profit - % of sales 17.0 % 14.5 % 16.7 % 15.4 % EBITDA(1) 7.7 3.8 16.0 8.7 EBITDA(1)- % of sales 5.5 % 2.9 % 4.1 % 2.5 % Net earnings 4.8 2.2 9.8 4.3 Per share Basic 0.27 0.12 0.56 0.24 Diluted 0.26 0.12 0.54 0.24 Net working capital(2) 134.6 129.0 Long term debt / Bank $ 5.8 $ 14.4 operating loan(2) "Improved product margins, supported by disciplined revenue growth lead to increased profitability.  Activity levels are expected to remain at or above prior year levels as the industry works through this period of economic volatility" said Michael West, President and CEO. The September 30, 2011 condensed interim consolidated financial statements are prepared under International Financial Reporting Standards ("IFRS"). Consequently the comparative figures for 2010 and the Company's statement of financial position as at January 1, 2010 have been restated from accounting principles generally accepted in Canada ("Canadian GAAP") to comply with IFRS. The reconciliations from the previously published Canadian GAAP financial statements are summarized in Note 3 to the condensed interim consolidated financial statements, and there were no material differences. Net earnings for the third quarter of 2011, were $4.8 million, an increase of $2.6 million from the third quarter of 2010.  Revenues were $140.5 million, an increase of $8.3 million (6%) from the third quarter of 2010. Industry activity continued to improve and is focused on oil, oil sands and liquid rich natural gas plays. Well completions increased 34% compared to the third quarter of 2010. Capital project business revenue grew $6.2 million year over year due to improved industry activity levels. Gross profits increased by $4.7 million (24%) due to the increase in revenues and improved gross profit margins year over year. Average gross profit margins were consistent with the second quarter of 2011 but improved over the third quarter 2010 average gross profit margin, as increased purchasing levels contributed to higher volume rebate income. Selling, general and administrative expenses increased by $2.3 million (15%) from prior year to $17.8 million for the quarter as compensation and operating costs have increased in response to higher revenue levels. During the quarter, the Company moved its head office location within downtown Calgary and as a consequence recorded a one time lease charge of $0.7 million in relation to its old head office lease obligations net of expected sublease revenue. The Company also recorded an unrealized foreign exchange gain of $1.0 million in the quarter on foreign exchange contracts used to manage currency exposure on US denominated product purchases. The weighted average number of shares outstanding during the third quarter was consistent with the prior year period as the rise in share price during the last year has limited the activity occurring under the normal course issuer bid program. Net earnings per share (basic) was $0.27 in the third quarter of 2011, compared to net earnings of $0.12 per share in the third quarter of 2010. Net earnings for the nine months ended September 30, 2011 at $9.8 million was more than double the net income for the same prior year period. Revenues were $392.0 million, an increase of $38.1 million (11%) over the comparable 2010 period due to improvements in capital project and maintenance repair and operating revenues. Well completions have increased 32% year over year as industry activity continues to build. Gross profit was up $10.9 million (20%) due to the increase in revenues combined with an increase in vendor rebate income due to increased purchasing levels. Selling, general and administrative expenses increased by $5.4 million (12%) to $51.2 million for the nine months ended for the same reasons they were higher in the third quarter. Income taxes increased by $1.9 million for the nine months ended September 30, 2011 compared to the prior year period due to higher pre-tax earnings. The weighted average number of shares outstanding (basic) during the third quarter was consistent with the prior year period as the rise in share price during the last year has limited the activity occurring under the normal course issuer bid program.  Net earnings per share (basic) was $0.56 for the nine months ended September 30, 2011, compared to $0.24 earned in same prior year period. Business Outlook Oil and gas industry activity in 2011 is expected to remain at or above 2010 levels for the remainder of the year.  Natural gas prices remain depressed as North American production capacity and inventory levels continue to dominate demand.  Natural gas capital expenditure activity is focused on the emerging shale gas plays in northeastern British Columbia and liquid rich gas plays in northwestern Alberta where the Company has a strong market position.  Conventional and heavy oil economics are attractive at current price levels leading to continuing activity in eastern Alberta and southeast Saskatchewan.  Oil sands project announcements continue at current oil price levels. Approximately 50% to 60% of the Company's total revenues are driven by our customers' capital expenditure requirements. CE Franklin's revenues are expected to increase modestly in 2012 as the oil and gas industry activity levels remain relatively consistent with 2011 levels. Gross profit margins are expected to remain under pressure as customers that produce natural gas focus on reducing their costs to maintain acceptable project economics and due to continued aggressive oilfield supply industry competition as industry activity levels remain below the last five year average. The Company will continue to manage its cost structure to protect profitability while maintaining service capacity and advancing strategic initiatives. Over the medium to longer term, the Company's strong financial and competitive positions should enable profitable growth of its distribution network through the expansion of its product lines, supplier relationships and capability to service additional oil and gas and other industrial end use markets. (1) EBITDA represents net earnings before interest, taxes, depreciation and amortization. EBITDA is supplemental non-GAAP financial measure used by management, as well as industry analysts, to evaluate operations. Management believes that EBITDA, as presented, represents a useful means of assessing the performance of the Company's ongoing operating activities, as it reflects the Company's earnings trends without showing the impact of certain charges. The Company is also presenting EBITDA and EBITDA as a percentage of revenues because it is used by management as supplemental measures of profitability. The use of EBITDA by the Company has certain material limitations because it excludes the recurring expenditures of interest, income tax, and depreciation expenses. Interest expense is a necessary component of the Company's expenses because the Company borrows money to finance its working capital and capital expenditures. Income tax expense is a necessary component of the Company's expenses because the Company is required to pay cash income taxes. Depreciation expense is a necessary component of the Company's expenses because the Company uses property and equipment to generate revenues. Management compensates for these limitations to the use of EBITDA by using EBITDA as only a supplementary measure of profitability. EBITDA is not used by management as an alternative to net earnings, as an indicator of the Company's operating performance, as an alternative to any other measure of performance in conformity with generally accepted accounting principles or as an alternative to cash flow from operating activities as a measure of liquidity. A reconciliation of EBITDA to Net earnings is provided within the Company's Management Discussion and Analysis. Not all companies calculate EBITDA in the same manner and EBITDA does not have a standardized meaning prescribed by GAAP. Accordingly, EBITDA, as the term is used herein, is unlikely to be comparable to EBITDA as reported by other entities. (2) Net working capital is defined as current assets less cash and cash equivalents, accounts payable and accrued liabilities, current taxes payable and other current liabilities. Net working capital and long term debt / bank operating loan amounts are as at quarter end. Additional Information Additional information relating to CE Franklin, including its third quarter 2011 Management Discussion and Analysis and interim consolidated financial statements and its Form 20-F / Annual Information Form, is available under the Company's profile on the SEDAR website at www.sedar.com and at www.cefranklin.com. Conference Call and Webcast Information A conference call to review the 2011 third quarter results, which is open to the public, will be held on Friday, October 28, 2011 at 11:00 a.m. Eastern Time (9:00a.m. Mountain Time). Participants may join the call by dialing 1-647-427-7450 in Toronto or dialing 1-888-231-8191 at the scheduled time of 11:00 a.m. Eastern Time.  For those unable to listen to the live conference call, a replay will be available at approximately 2:00 p.m. Eastern Time on the same day by calling 1-416-849-0833 in Toronto or dialing 1-855-859-2056 and entering the Passcode of 15091601 and may be accessed until midnight November 4, 2011. The call will also be webcast live at: http://www.newswire.ca/en/webcast/viewEvent.cgi?eventID=3683680 and will be available on the Company's website at http://www.cefranklin.com. Michael West, President and Chief Executive Officer will lead the discussion and will be accompanied by Derrren Newell, Vice President and Chief Financial Officer. The discussion will be followed by a question and answer period. About CE Franklin For more than half a century, CE Franklin has been a leading supplier of products and services to the energy industry.  CE Franklin distributes pipe, valves, flanges, fittings, production equipment, tubular products and other general oilfield supplies to oil and gas producers in Canada as well as to the oil sands, refining, heavy oil, petrochemical, forestry and mining industries.  These products are distributed through its 43 branches, which are situated in towns and cities serving particular oil and gas fields of the western Canadian sedimentary basin. Forward-looking Statements: The information in this news release may contain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 and other applicable securities legislation.  All statements, other than statements of historical facts, that address activities, events, outcomes and other matters that CE Franklin plans, expects, intends, assumes, believes, budgets, predicts, forecasts, projects, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements.  These forward-looking statements are based on management's current belief, based on currently available information, as to the outcome and timing of future events.  When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements and refer to the Form 20-F or our annual information form for further detail. Management's Discussion and Analysis at October 27, 2011 The following Management's Discussion and Analysis ("MD&A") is provided to assist readers in understanding CE Franklin Ltd.'s ("CE Franklin" or the "Company") financial performance and position during the periods presented and significant trends that may impact future performance of CE Franklin. This MD&A should be read in conjunction with the Company's condensed interim consolidated financial statements for the three and nine month period ended September 30, 2011 and the MD&A and the consolidated financial statements for the three and six month periods ended June 30, 2011 and the three month period ended March 31, 2011 (the Company's first financial statements under IFRS) and the MD&A and consolidated financial statements for the year ended December 31, 2010. All amounts are expressed in Canadian dollars and are in accordance with International Financial Reporting Standards ("IFRS"), except where otherwise noted. The September 30, 2011 condensed interim consolidated financial statements are prepared under IFRS. Consequently the comparative figures for 2010 and the Company's statement of financial position as at January 1, 2010 have been restated from accounting principles generally accepted in Canada ("Canadian GAAP") to comply with IFRS. The reconciliations from the previously published Canadian GAAP financial statements are summarized in Note 3 to the condensed interim consolidated financial statements, and there were no material differences. In addition, IFRS 1 on first time adoption allows certain exemptions from retrospective application of IFRS in the opening statement of financial position. Where these exemptions have been used they have also been explained in Note 3 to the condensed interim consolidated financial statements. Overview CE Franklin is a leading distributor of pipe, valves, flanges, fittings, production equipment, tubular products and other general industrial supplies primarily to the oil and gas industry through its 43 branches situated in towns and cities that serve oil and gas fields of the western Canadian sedimentary basin. In addition, the Company distributes similar products to the oil sands, refining, and petrochemical industries and non-oilfield related industries such as forestry and mining. The Company's branch operations service over 3,000 customers by providing the right materials where and when they are needed, and for the best value.  Our branches, supported by our centralized Distribution Centre in Edmonton, Alberta, stock over 25,000 stock keeping units sourced from over 2,000 suppliers.  This supply chain infrastructure enables us to provide our customers with the products they need on a same day or over-night basis.  Our centralized inventory and procurement capabilities allow us to leverage our scale to enable industry leading hub and spoke purchasing and logistics capabilities. Our branches are also supported by services provided by the Company's corporate office in Calgary, Alberta including sales, marketing, product expertise, logistics, invoicing, credit and collection and other business services. The Company's shares trade on the TSX ("CFT") and NASDAQ ("CFK") stock exchanges.  Schlumberger Limited ("Schlumberger"), a major oilfield service company based in Paris, France, owns approximately 56% of the Company's shares. Business Strategy The Company is pursuing the following strategies to grow its business profitably: -- Expand the reach and market share serviced by the Company's distribution network. The Company is focusing its sales efforts and product offering on servicing complex, multi-location needs of large and emerging customers in the energy sector. Organic growth is expected to be complemented by selected acquisitions over time. -- Expand production equipment service capability to capture more of the product life cycle requirements for the equipment the Company sells such as down hole pump repair, oilfield engine maintenance, well optimization and on site project management. This will differentiate the Company's service offering from its competitors and deepen relationships with its customers. -- Expand oil sands and industrial project and Maintenance, Repair and Operating Supplies ("MRO") business by leveraging our existing supply chain infrastructure, product and project expertise. -- Increase the resourcing of customer project sales quotation and order fulfillment services provided by our Distribution Centre to augment local branch capacity to address seasonal and project driven fluctuations in customer demand. By doing so, we aim to increase our capacity flexibility and improve operating efficiency while providing consistent service. Business Outlook Oil and gas industry activity in 2011 is expected to remain at or above 2010 levels for the remainder of the year.  Natural gas prices remain depressed as North American production capacity and inventory levels continue to dominate demand.  Natural gas capital expenditure activity is focused on the emerging shale gas plays in northeastern British Columbia and liquid rich gas plays in northwestern Alberta where the Company has a strong market position.  Conventional and heavy oil economics are attractive at current price levels leading to continuing activity in eastern Alberta and southeast Saskatchewan.  Oil sands project announcements continue at current oil price levels. Approximately 50% to 60% of the Company's total revenues are driven by our customers' capital expenditure requirements. CE Franklin's revenues are expected to increase modestly in 2012 as the oil and gas industry activity levels remain relatively consistent with 2011 levels. Gross profit margins are expected to remain under pressure as customers that produce natural gas focus on reducing their costs to maintain acceptable project economics and due to continued aggressive oilfield supply industry competition as industry activity levels remain below the last five year average. The Company will continue to manage its cost structure to protect profitability while maintaining service capacity and advancing strategic initiatives. Over the medium to longer term, the Company's strong financial and competitive positions should enable profitable growth of its distribution network through the expansion of its product lines, supplier relationships and capability to service additional oil and gas and other industrial end use markets. Third Quarter Operating Results The following table summarizes CE Franklin's results of operations: (In millions of Canadian Dollars except per share data) Three Months Ended September 30 NineMonths Ended September 30 2011 2010 2011 2010 Revenues 140.5 100.0 % 132.2 100.0 % 392.0 100.0 % 353.9 100.0 % Cost of Sales (116.6) (83.0) % (113.0) (85.5) % (326.6) (83.3) % (299.5) (84.6) % Gross Profit 23.9 17.0 % 19.2 14.5 % 65.4 16.7 % 54.4 15.4 % Selling, (17.8) (12.7) % (15.5) (11.7) % (51.2) (13.1) % (45.8) (12.9) % general and administrative expenses Foreign 1.6 1.1 % 0.1 0.1 % 1.8 0.5 % - - % exchange and other EBITDA(1) 7.7 5.5 % 3.8 2.9 % 16.0 4.1 % 8.6 2.5 % Depreciation (0.6) (0.4) % (0.6) (0.5) % (1.8) (0.5) % (1.8) (0.5) % Interest (0.2) (0.1) % (0.1) (0.1) % (0.4) (0.1) % (0.5) (0.1) % Earnings 6.9 4.9 % 3.1 2.3 % 13.8 3.5 % 6.3 1.9 % before tax Income tax (2.1) (1.5) % (0.9) (0.7) % (4.0) (1.0) % (2.0) (0.6) % expense Net earnings 4.8 3.4 % 2.2 1.7 % 9.8 2.5 % 4.3 1.3 % Net earnings per share Basic $ 0.27 $ 0.12 $ 0.56 $ 0.24 Diluted $ 0.26 $ 0.12 $ 0.54 $ 0.24 Weighted average number of shares outstanding (000's) Basic 17,537 17,461 17,507 17,518 Diluted 18,165 17,783 18,142 17,838 (1) EBITDA represents net earnings before interest, taxes, depreciation and amortization. EBITDA is a supplemental non-GAAP financial measure used by management, as well as industry analysts, to evaluate operations. Management believes that EBITDA, as presented, represents a useful means of assessing the performance of the Company's ongoing operating activities, as it reflects the Company's earnings trends without showing the impact of certain charges. The Company is also presenting EBITDA and EBITDA as a percentage of revenues because it is used by management as supplemental measures of profitability. The use of EBITDA by the Company has certain material limitations because it excludes the recurring expenditures of interest, income tax, and depreciation expenses. Interest expense is a necessary component of the Company's expenses because the Company borrows money to finance its working capital and capital expenditures. Depreciation expense is a necessary component of the Company's expenses because the Company is required to pay cash to acquire equipment to generate revenues. Management compensates for these limitations to the use of EBITDA by using EBITDA as only a supplementary measure of profitability. EBITDA is not used by management as an alternative to net earnings, as an indicator of the Company's operating performance, as an alternative to any other measure of performance in conformity with generally accepted accounting principles or as an alternative to cash flow from operating activities as a measure of liquidity. A reconciliation of EBITDA to net earnings is provided within the table above. Not all companies calculate EBITDA in the same manner and EBITDA does not have a standardized meaning prescribed by GAAP. Accordingly, EBITDA, as the term is used herein, is unlikely to be comparable to EBITDA as reported by other entities. Third Quarter Results Net earnings for the third quarter of 2011, were $4.8 million, an increase of $2.6 million from the third quarter of 2010.  Revenues were $140.5 million, an increase of $8.3 million (6%) from the third quarter of 2010. Industry activity continued to improve and is focused on oil, oil sands and liquid rich natural gas plays. Well completions increased 34% compared to the third quarter of 2010. Capital project business revenue grew $6.2 million year over year due to improved industry activity levels. Gross profits increased by $4.7 million (24%) due to the increase in revenues and improved gross profit margins year over year. Average gross profit margins were consistent with the second quarter of 2011 but improved over the third quarter 2010 average gross profit margin, as increased purchasing levels contributed to higher volume rebate income. Selling, general and administrative expenses increased by $2.3 million (15%) to $17.8 million for the quarter as compensation and operating costs have increased in response to higher revenue levels. During the quarter, the Company moved its head office location within downtown Calgary and as a consequence recorded a one time lease charge of $0.7 million in relation to its old head office lease obligations net of expected sublease revenue. The Company also recorded an unrealized foreign exchange gain of $1.0 million in the quarter on foreign exchange contracts used to manage currency exposure on US denominated product purchases. The weighted average number of shares outstanding during the third quarter was consistent with the prior year period as the rise in share price during the last year has limited the activity occurring under the normal course issuer bid program. Net earnings per share (basic) was $0.27 in the third quarter of 2011, compared to net earnings of $0.12 per share in the third quarter of 2010. Year to date Results Net Income for the nine months ended September 30, 2011 at $9.8 million was more than double the net income for the same prior year period. Revenues were $392.0 million, an increase of $38.1 million (11%) over the comparable 2010 period due to improvements in capital project and maintenance repair and operating revenues. Well completions have increased 32% year over year as industry activity continues to build. Gross profit was up $10.9 million (20%) due to the increase in revenues combined with an increase in vendor rebate income due to increased purchasing levels. Selling, general and administrative expenses increased by $5.4 million (12%) to $51.2 million for the nine months ended for the same reasons they were higher in the third quarter. Income taxes increased by $1.9 million for the nine months ended September 30, 2011 compared to the prior year period due to higher pre-tax earnings. The weighted average number of shares outstanding (basic) during the third quarter was consistent with the prior year period as the rise in share price during the last year has limited the activity occurring under the normal course issuer bid program.  Net earnings per share (basic) was $0.56 for the nine months ended September 30, 2011, compared to $0.24 earned in the same prior year period. Revenues Revenues for the quarter ended September 30, 2011, were $140.5 million, an increase of 6% from the quarter ended September 30, 2010, as detailed above in the "Third Quarter Results" discussion. Oil and gas commodity prices are a key driver of industry capital project activity as commodity prices directly impact the economic returns realized by oil and gas companies. The Company uses oil and gas well completions and average rig counts as industry activity measures to assess demand for oilfield equipment used in capital projects.  Oil and gas well completions require the products sold by the Company to complete a well and bring production on stream and are a general indicator of energy industry activity levels.  Average drilling rig counts are also used by management to assess industry activity levels as the number of rigs in use ultimately drives well completion requirements.  Well completion, rig count and commodity price information for the three and nine month periods ended September 30, 2011 and 2010 are provided in the table below. Q3 Average % YTDAverage % 2011 2010 change 2011 2010 change Gas - Cdn. $ 3.67 $ 3.55 3 % $ 3.77 $ 4.12 (8) % $/gj (AECO spot) Oil - Cdn. $ 99.16 $ 77.37 28 % $ 102.74 $ 79.30 30 % $/bbl (synthetic crude) Average rig 456 325 40 % 392 309 27 % count Well completions: Oil 2,699 1,484 82 % 6,685 3,916 71 % Gas 796 1,127 (29) % 3,436 3,738 (8) % Total well 3,495 2,611 34 % 10,121 7,654 32 % completions Average statistics are shown except for well completions. Sources:Oil and Gas prices - First Energy Capital Corp.; Rig count data - CAODC; well completion data - Daily Oil Bulletin (in millions Three monthsended September Nine months ended September of Cdn. $) 30 30 2011 2010 2011 2010 End use $ % $ % $ % $ % revenue demand Capital 72.9 52 % 66.7 50 % 205.7 52 % 182.4 52 % projects Maintenance, repair and operating supplies ("MRO") 67.6 48 % 65.5 50 % 186.3 48 % 171.5 48 % Total 140.5 100 % 132.2 100 % 392.0 100 % 353.9 100 % Revenues Note:Capital project end use revenues are defined by the Company as consisting of the tubular and 80% of pipe, flanges and fittings; and valves and accessories product revenues respectively; MRO revenues are defined by the Company as consisting of pumps and production equipment, production services; general product and 20% of pipes, flanges and fittings; and valves and accessory product revenues respectively. Revenues from capital project related products were $72.9 million in the third quarter of 2011, an increase of 9% ($6.2 million) from the third quarter of 2010. Total well completions increased by 34% in the third quarter of 2011 and the average working rig count increased by 40% compared to the prior year period. Gas wells comprised 23% of the total wells completed in western Canada in the third quarter of 2011 compared to 43% in the third quarter of 2010. Spot gas prices ended the third quarter at $3.52 per GJ (AECO) a decrease of 4% from third quarter average prices.  Oil prices ended the third quarter at $90.34 per bbl (Synthetic Crude) a decrease of 9% from the third quarter average. Depressed gas prices are expected to continue to negatively impact gas drilling activity over the remainder of 2011, which in turn is expected to constrain demand for the Company's products. Natural gas customers continue to utilize a high level of competitive bid activity to procure the products they require in an effort to reduce their costs. The Company is addressing this industry trend by pursuing initiatives focused on improving revenue quotation processes and increasing the operating flexibility and efficiency of its branch network.  The Company is well positioned to support customers who are pursuing oil plays and more particularly tight oil plays. MRO product revenues are related to overall oil and gas industry production levels and tend to be more stable than capital project revenues. MRO product revenues for the quarter ended September 30, 2011 increased by $2.1 million (3%) to $67.6 million compared to the quarter ended September 30, 2010 and comprised 48% of the Company's total revenues (2010 - 50%). The Company's strategy is to grow profitability by focusing on its core western Canadian oilfield product distribution business, complemented by an increase in the product life cycle services provided to its customers and the focus on the emerging oil sands capital project and MRO revenues opportunities. Revenues from these initiatives to date are provided below: Q3 2011 Q32010 YTD2011 YTD 2010 Revenues $ % $ % $ % $ % ($millions) Oilfield 115.1 82 % 104.2 79 % 327.2 84 % 292.5 84 % Oil sands 18.9 13 % 23.7 18 % 48.3 12 % 49.8 14 % Production 6.5 5 % 4.3 3 % 16.5 4 % 11.6 3 % services Total 140.5 100 % 132.2 100 % 392.0 100 % 353.9 100 % Revenues Revenues from oilfield products to conventional western Canada oil and gas end use applications were $115.1 million for the third quarter of 2011, backing out tubular product sales, which were down $0.7 million in the third quarter year over year, oilfield revenue was up 12.2%.  This increase was driven by the 34% increase in well completions compared to the prior year period. Revenues from oil sands end use applications were $18.9 million in the third quarter, a decrease of $4.8 million (20%) compared to $23.7 million in the third quarter of 2010 reflecting lower turnaround activity and no tailing pipe sales in 2011.  The Company continues to position its major project execution capability and the Fort McMurray branch to penetrate this emerging market for capital projects and MRO products. Production service revenues were $6.5 million in the third quarter of 2011, a 51% increase from the $4.3 million of revenues in the third quarter of 2010, reflecting improved oil production economics resulting in increased customer maintenance activities. Gross Profit Q3 2011 Q32010 YTD 2011 YTD2010 Gross profit ($ millions) $ 23.9 $ 19.2 $ 65.4 $ 54.5 Gross profit margin as a 17.0 % 14.5 % 16.7 % 15.4 % % of revenues Gross profit composition by product revenue category: Tubulars 1 % 3 % 3 % 2 % Pipe, flanges and 33 % 28 % 30 % 29 % fittings Valves and accessories 21 % 20 % 21 % 20 % Pumps, production 17 % 15 % 15 % 14 % equipment and services General 28 % 34 % 31 % 35 % Total gross profit 100 % 100 % 100 % 100 % Gross profit was $23.9 million in the third quarter of 2011, an increase of $4.7 million (24%) from the third quarter of 2010 due to increased revenues and average gross profit margins compared to the prior year period. Gross profit margins for the quarter remained consistent with the second quarter 2011 levels and were better than the prior year period at 16.9% as increased purchasing levels contributed to higher volume rebate income.  In the quarter the Company effectively passed along price increases related to increasing steel costs from our suppliers to our customers.  Increased pipe, flanges and fittings and valves and accessories gross profit composition was due to improved gross profit margins. The decrease in tubular gross profit composition reflects larger lower margin sales and the disposal of surplus tubular inventory. Selling, General and Administrative ("SG&A") Costs ($millions) Q3 2011 Q3 2010 YTD 2011 YTD2010 $ % $ % $ % $ % People 10.6 60 8.9 57 30.9 61 26.5 58 Costs Facility 4.3 24 3.3 21 11.5 22 10.1 22 and office costs Selling 1.7 10 1.8 12 4.2 8 4.5 10 Costs Other 1.2 6 1.5 10 4.6 9 4.7 10 SG&A costs 17.8 100 15.5 100 51.2 100 45.8 100 SG&A costs 12.7 % 11.7 % 13.1 % 12.9 % as % of revenues SG&A costs increased $2.3 million (15%) in the third quarter of 2011 from the prior year period and represented 12.7% of revenues compared to 11.7% in the prior year period. The $2.3 million increase in expenses was attributable to higher people costs reflecting a 6% increase in employee head count to service the additional sales volumes and higher incentive compensation costs reflecting the improved profit performance of the business year over year.  Facility and office costs also increased in the quarter as the Company moved its head office location within downtown Calgary and as a consequence recorded a one time lease charge of $0.7 million for its old head office lease obligations net of expected sublease revenue. Depreciation Expense Depreciation expense of $0.6 million in the third quarter of 2011 was comparable to the third quarter of 2010. Interest Expense Interest expense of $0.2 million in the third quarter of 2011 was higher than the prior year as fees related to the renewal of the Company's banking facility were expensed in the period. Foreign Exchange Gain and other Foreign exchange gains and other in the quarter amounted to $1.6 million as the significant weakening of the Canadian dollar at the end of the quarter increased the translation gains from US denominated net working capital assets.  The Company recognized a $1.0 million unrealized foreign currency gain on $14.2 million of foreign currency forward contracts it had outstanding at quarter end.  As at September 30, 2011, a one percent change in the Canadian dollar relative to the US dollar would decrease or increase the Company's annual net income by $0.1 million. Income Tax Expense The Company's effective tax rate for the third quarter of 2011 was 29.8%, down 0.5% from the third quarter of 2010 as the decline in the statutory rate was partially offset by the impact of permanent differences. The current effective tax rate is higher than the statutory rate due to the impact of non-deductible items and other adjustments. Substantially all of the Company's tax provision is currently payable. Summary of Quarterly Financial Data The selected quarterly financial data is presented in Canadian dollars and in accordance with IFRS. This information is derived from the Company's unaudited quarterly financial statements. As noted above the September 30, 2011 interim consolidated financial statements have been prepared under IFRS. The comparative figures shown in the table below for 2010 have been restated from Canadian GAAP. The reconciliations from Canadian GAAP to IFRS have been completed and there were no material differences noted. The conversion from Canadian GAAP to IFRS is further discussed in Note 3 of the condensed interim consolidated financial statements. (in millions of Cdn. $ except per share data) Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Unaudited 2009 (2) 2010 2010 2010 2010 2011 2011 2011 Revenues 93.0 121.9 99.9 132.2 135.6 137.7 113.9 140.5 Gross Profit 15.3 19.7 15.6 19.2 20.5 22.3 19.3 23.9 Gross Profit % 16.5 % 16.1 % 15.6 % 14.5 % 15.1 % 16.2 % 16.9 % 17.0 % EBITDA 0.6 4.1 0.7 3.8 3.8 5.3 3.1 7.7 EBITDA as a % of 0.6 % 3.4 % 0.7 % 2.9 % 2.8 % 3.8 % 2.7 % 5.5 % revenues Net earnings (0.5) 2.2 (0.1) 2.2 1.6 3.4 1.7 4.8 (loss) Net earnings (loss) as a % of revenues (0.5) % 1.8 % (0.1) % 1.7 % 1.2 % 2.5 % 1.5 % 3.4 % Net earnings (loss) per share Basic $ (0.03) $ 0.13 $ (0.01) $ 0.12 $ 0.09 $ 0.19 0.10 $ 0.27 Diluted $ (0.03) $ 0.12 $ (0.01) $ 0.12 $ 0.09 $ 0.19 0.09 $ 0.26 Net working 136.6 113.9 111.8 129.0 125.7 120.1 136.5 134.6 capital(1) Long term 26.8 1.4 0.3 14.4 6.4 0.3 12.2 5.8 debt/bankoperating loan(1) Total well 1,576 2,846 2,197 2,611 4,760 3,861 2,765 3,495 completions (1) Net working capital and long term debt/bank operating loan amounts are as at quarter end (2) Prepared using Canadian GAAP The Company's revenue levels are affected by weather conditions. As warm weather returns in the spring each year, the winter's frost comes out of the ground rendering many secondary roads incapable of supporting the weight of heavy equipment until they have dried out. In addition, many exploration and production areas in northern Canada are accessible only in the winter months when the ground is frozen. An exceptionally wet second quarter in 2011 had some impact on customer capital programs in the third quarter. As a result, the first and fourth quarters typically represent the busiest time for oil and gas industry activity and the highest revenue activity for the Company. Revenue levels drop dramatically during the second quarter until such time as roads have dried and road bans have been lifted. This typically results in a significant reduction in earnings during the second quarter, as the decline in revenue typically out paces the decline in SG&A costs as the majority of the Company's SG&A costs are fixed in nature. Net working capital (defined as current assets less cash and cash equivalents, accounts payable and accrued liabilities, income taxes payable and other current liabilities) and borrowing levels follow similar seasonal patterns as revenue. Liquidity and Capital Resources The Company's primary internal source of liquidity is cash flow from operating activities before net changes in non-cash working capital balances related to operations. Cash flow from operating activities and the Company's $60.0 million revolving term credit facility are used to finance the Company's net working capital, capital expenditures and acquisitions. As at September 30, 2011 the Company had $5.8 million in borrowings under its revolving term credit facility, a net decrease of $0.6 million from December 31, 2010. Borrowing levels have decreased due to the Company generating $10.8 million in cash flow from operating activities before net changes in working capital.  This was offset by $2.1 million in capital and other expenditures and $0.7 million for the purchase of shares to resource stock compensation obligations and the repurchase of shares under the Company's Normal Course Issuer Bid ("NCIB"). As at September 30, 2010, there were $14.1 million in borrowings under the Company's debt facility, a decrease of $12.5 million from December 31, 2009. Borrowing levels have decreased since December 31, 2009 due to the Company generating $7.5 million in cash flow from operating activities before net changes in working capital and a $7.7 million reduction in net working capital. This was offset by $1.1 million in capital and other expenditures, $0.4 million for the settlement of share obligations and $1.2 million for the purchase of shares to resource stock compensation obligations and the repurchase of shares under the Company's NCIB. Net working capital was $134.6 million at September 30, 2011, an increase of $8.9 million from December 31, 2010. Accounts receivable increased by $3.1 million to $96.1 million at September 30, 2011 from December 31, 2010 due to the 4% increase in revenues in the third quarter compared to the fourth quarter of 2010, partially offset by a weaker Days Sales Outstanding ("DSO"). DSO in the third quarter of 2011 was 58 days compared to 56 days in the fourth quarter of 2010 and 58 days in the third quarter of 2010. DSO is calculated using average revenues per day for the quarter compared to the period end accounts receivable balance. Inventory increased by $7.7 million at September 30, 2011 from December 31, 2010. Inventory turns for the third quarter of 2011 decreased to 4.5 turns compared to 4.9 turns in the fourth quarter of 2010. Inventory turns are calculated using cost of goods sold for the quarter on an annualized basis compared to the period end inventory balance. The Company continues to adjust its investment in inventory to align with anticipated industry activity levels and supplier lead times in order to improve inventory turnover efficiency. Accounts payable and accrued liabilities increased by $6.6 million (10%) to $70.0 million at September 30, 2011 from December 31, 2010 due to the seasonal increase in activity. Capital expenditures in the third quarter of 2011 were $1.1 million, $0.5 million higher than the prior year period and were comprised primarily of vehicles, warehouse equipment replacements and branch improvements.  In the quarter the Company disposed of a surplus building and some surplus vehicles for net proceeds of $0.4 million. The Company has a $60.0 million revolving term credit facility that matures in July 2014 (the "Credit Facility"). The loan facility bears interest based on floating interest rates and is secured by a general security agreement covering all assets of the Company. The maximum amount available under the Credit Facility is subject to a borrowing base formula applied to accounts receivable and inventories. The Credit Facility requires the Company to maintain the ratio of its debt to debt plus equity at less than 40%. As at September 30, 2011, this ratio was 3%. The Company must also maintain coverage of its net operating cash flow as defined in the Credit Facility agreement over interest expense for the trailing twelve month period of greater than 1.25 times. As at September 30, 2011 this ratio was 24.9 times. The Credit Facility contains certain other covenants with which the Company is in compliance. As at September 30, 2011 the Company had available undrawn borrowing capacity of $54.5 million under this Credit facility. Contractual Obligations There have been no material changes in off-balance sheet contractual commitments since June 30, 2011. Capital Stock As at September 30, 2011 and 2010, the following shares and securities convertible into shares were outstanding: (millions) September 30, 2011 September 30, 2010 Shares Shares Shares outstanding 17.5 17.4 Stock options 0.6 1.1 Share unit plan obligations 0.7 0.6 Shares outstanding and 18.8 19.1 issuable The weighted average number of shares outstanding during the third quarter of 2011 was 17.5 million, which was consistent with the prior year period as the rise in the Company's share price during the last year has limited the activity occurring under the normal course issuer bid program. The diluted weighted average number of shares outstanding was 18.2 million, which is also consistent with the prior year quarter. The Company has established an independent trust to purchase common shares of the Company on the open market to resource share unit plan obligations. During the three and nine month periods ended September 30, 2011, 500 common shares and 75,500 common shares were acquired by the trust at an average cost per share of $8.28 and $9.26 per share respectively (three and nine months ended September 30, 2010 - 92,500 and 129,300 common shares at an average cost per share of $6.79 and $6.83 respectively). As at September 30, 2011, the trust held 481,726 shares (September 30, 2010 - 471,610 shares). On December 21, 2010, the Company announced the renewal of the NCIB, to purchase up to 850,000 common shares representing approximately 5% of its outstanding common shares. Shares may be purchased up to December 31, 2011. As at September 30, 2011 the Company had purchased 3,102 shares at an average cost of $7.56 per share (September 30, 2010 - 57,878 shares at an average cost of $6.61 per share). Critical Accounting Estimates There have been no material changes to critical accounting estimates since December 31, 2010. The Company is not aware of any environmental or asset retirement obligations that could have a material impact on its operations. Change in Accounting Policies Transition to International Financial Reporting Standards ("IFRS") In February 2008, the Canadian Accounting Standards Board confirmed that the basis for financial reporting by Canadian publicly accountable enterprises will change from Canadian GAAP to IFRS effective for January 1, 2011, including the preparation and reporting of one year of comparative figures. This change is part of a global shift to provide consistency in financial reporting in the global marketplace. Over the transition period the Company assessed the differences between Canadian GAAP and IFRS. A risk based approach was used to identify possibly significant differences based on possible financial impact and complexity. As described in Note 3 to the condensed interim consolidated financial statements no material differences were identified. As such there are no reconciling items that materially changed the reporting requirements upon the transition from Canadian GAAP to IFRS.  Similarly, no significant information system changes were required in order to adopt IFRS. IFRS 1 allows first time adopters of IFRS to take advantage of a number of voluntary exemptions from the general principal of retroactive restatement. In adopting IFRS, the Company did take advantage of the following voluntary exemptions under IFRS 1. Business Combinations The Company has not applied IFRS 3, the Business Combinations standard to acquisitions of subsidiaries that occurred before January 1, 2010, the Company's transition date to IFRS. As such there is no retrospective change in accounting for business combinations. The Company used this exemption to simplify its IFRS conversion plan and improve comparability between its Canadian GAAP statements and its IFRS statements. Borrowing Costs IAS 23 requires that borrowing costs directly attributable to the acquisition, construction or production of a qualifying asset (one that takes a substantial period of time to get ready for use or sale) be capitalized as part of the cost of that asset. The option of immediately expensing those borrowing costs has been removed. The Company has elected to account for such transactions on a go forward basis, and as such there is no retrospective change in accounting for borrowing standards. The Company used this exemption to simplify its IFRS conversion plan and improve comparability between its Canadian GAAP statements and its IFRS statements. Stock Options The Company has assessed and quantified the difference in accounting for stock based compensation under IFRS compared to Canadian GAAP and has deemed the difference to be immaterial. The Company has elected to not apply IFRS 2 to share based payments granted and fully vested before the Company's date of transition to IFRS.  The Company used this exemption to simplify its IFRS conversion plan and improve comparability between its Canadian GAAP statements and its IFRS statements. As part of the transition to IFRS the Company established that the carrying value of its property and equipment were substantially equivalent between IFRS and Canadian GAAP and therefore the Company has continued to carry its property and equipment at the historic costs model as was used under Canadian GAAP in these statements. Controls and Procedures Internal control over financial reporting ("ICFR") is designed to provide reasonable assurance regarding the reliability of the Company's financial reporting and its compliance with IFRS in its financial statements. The President and Chief Executive Officer and the Vice President and Chief Financial Officer of the Company have evaluated whether there were changes to its ICFR during the nine months ended September 30, 2011 that have materially affected or are reasonably likely to materially affect the ICFR. No such changes were identified through their evaluation. Risk Factors The Company is exposed to certain business and market risks including risks arising from transactions that are entered into the normal course of business, which are primarily related to interest rate changes and fluctuations in foreign exchange rates. During the reporting period, no events or transactions since the year ended December 31, 2010 have occurred that would materially change the business and market risk information disclosed in the Company's Form 20F. Forward Looking Statements The information in the MD&A may contain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, that address activities, events, outcomes and other matters that CE Franklin plans, expects, intends, assumes, believes, budgets, predicts, forecasts, projects, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. These forward-looking statements are based on management's current belief, based on currently available information, as to the outcome and timing of future events. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this MD&A, including those in under the caption "Risk Factors". Forward-looking statements appear in a number of places and include statements with respect to, among other things: -- forecasted oil and gas industry activity levels in 2011 and beyond; -- planned capital expenditures and working capital and availability of capital resources to fund capital expenditures and working capital; -- the Company's future financial condition or results of operations and future revenues and expenses; -- the Company's business strategy and other plans and objectives for future operations; -- fluctuations in worldwide prices and demand for oil and gas; -- fluctuations in the demand for the Company's products and services. Should one or more of the risks or uncertainties described above or elsewhere in this MD&A occur, or should underlying assumptions prove incorrect, the Company's actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements expressed or implied, included in this MD&A and attributable to CE Franklin are qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that CE Franklin or persons acting on its behalf might issue. CE Franklin does not undertake any obligation to update any forward-looking statements to reflect events or circumstance after the date of filing this MD&A, except as required by law. Additional Information Additional information relating to CE Franklin, including its third quarter 2011 Management Discussion and Analysis and interim consolidated financial statements and its Form 20-F / Annual Information Form, is available under the Company's profile on the SEDAR website at www.sedar.com and at www.cefranklin.com. CE Franklin Ltd. CONDENSED INTERIM CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - UNAUDITED As at September 30 As at December 31 (in thousands of Canadian dollars) 2011 2010 Assets Current assets Accounts receivable (Note 4) 96,089 92,950 Inventories (Note 5) 102,504 94,838 Other 6,966 1,625 205,559 189,413 Non-current assets Property and equipment 10,035 9,431 Goodwill 20,570 20,570 Deferred tax assets (Note 6) 1,593 1,116 Other assets 188 147 Total Assets 237,945 220,677 Liabilities Current liabilities Accounts payable and accrued 69,956 63,363 liabilities (Note 7) Current taxes payable (Note 6) 1,002 348 70,958 63,711 Non current liabilities Long term debt (Note 8) 5,782 6,430 Total liabilities 76,740 70,141 Shareholders' equity Capital stock (Note 11) 23,376 23,078 Contributed surplus 20,271 19,716 Retained earnings 117,558 107,742 161,205 150,536 Total liabilities and 237,945 220,677 shareholders' equity See accompanying notes to these condensed interim consolidated financial statements CE Franklin Ltd. CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY - UNAUDITED (Canadian CapitalStock dollars and number of shares in thousands) Number of Contributed Retained Shareholders' Shares $ Surplus Earnings Equity Balance - 17,581 23,284 17,184 102,159 142,627 January 1, 2010 Stock based - - 1,485 - 1,485 compensation expense (Note 11 (b) and (c)) Normal (58) (76) - (298) (374) Course Issuer Bid (Note 11 (d)) Modification - - 103 - 103 of Stock option plan (Note 11 (a) and (b)) Share Units 67 464 (464) - - exercised (Note 11 (c)) Purchase of (179) (1,229) - - (1,229) shares in trust for Share Unit Plans (Note 11 (c)) Options 33 259 (100) - 159 exercised from treasury Directors - 73 (251) - (178) Share Unit Plan exercise (Note 11 (c)) Net earnings - - - 4,272 4,272 Balance - 17,444 22,775 17,957 106,133 146,865 September 30, 2010 Balance - 17,474 23,078 19,716 107,742 150,536 January 1, 2011 Stock based - - 1,556 - 1,556 compensation expense (Note 11 (b) and (c)) Normal (3) (4) - (19) (23) Course Issuer Bid (Note 11 (d)) Stock 97 735 (735) - - options exercised (Note 11 (b)) Share Units 45 266 (266) - - exercised (Note 11 (c)) Purchase of (76) (699) - - (699) shares in trust for Share Unit Plans (Note 11 (c)) Net earnings - - - 9,835 9,835 Balance - 17,537 23,376 20,271 117,558 161,205 September 30, 2011 See accompanying notes to these condensed interim consolidated financial statements CE Franklin Ltd. CONDENSED INTERIM CONSOLIDATED STATEMENTS OF EARNINGS AND COMPREHENSIVE INCOME - UNAUDITED Three months ended Nine months ended (in thousands of September 30 September 30 September 30 September 30 Canadian dollars 2011 2010 2011 2010 except pershare amounts) Revenue 140,454 132,159 392,021 353,944 Cost of sales 116,581 112,928 326,592 299,485 Gross profit 23,873 19,231 65,429 54,459 Other expenses Selling, 17,801 15,511 51,181 45,821 general and administrative expenses (Note 14) Depreciation 633 620 1,836 1,855 18,434 16,131 53,017 47,676 Operating profit 5,439 3,100 12,412 6,783 Foreign (1,596) (130) (1,768) (45) exchange gain and other Interest 226 108 398 539 expense Earnings before 6,809 3,122 13,782 6,289 tax Income tax expense (recovery)(Note 6) Current 2,215 1,120 4,383 2,124 Deferred (185) (173) (436) (107) 2,030 947 3,947 2,017 Net earnings and 4,779 2,175 9,835 4,272 comprehensive income Net earnings per share(Note 12) Basic 0.27 0.12 0.56 0.24 Diluted 0.26 0.12 0.54 0.24 Weighted average number of shares outstanding ('000s) Basic 17,537 17,461 17,507 17,518 Diluted (Note 18,165 17,783 18,142 17,838 12) See accompanying notes to these condensed interim consolidated financial statements CE Franklin Ltd. CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CASHFLOWS - UNAUDITED Three monthsended Nine months ended September 30 September 30 September 30 September 30 (in thousands of 2011 2010 2011 2010 Canadian dollars) Cash flows from operating activities Net earnings for 4,779 2,175 9,835 4,272 the period Items not affecting cash - Depreciation 633 620 1,836 1,855 Deferred income (185) (173) (436) (107) tax (recovery) Stock based 384 728 1,506 1,520 compensation expense Foreign (1,995) (130) (1,948) (52) exchange and other 3,616 3,220 10,793 7,488 Net change in non-cash working capital balance related to operations - Accounts (14,916) (30,000) (2,997) (24,263) receivable Inventories 5,543 (788) (7,666) 6,560 Other current (1,624) (3,340) (3,644) (1,454) assets Accounts payable 13,530 16,555 6,374 25,725 and accrued liabilities Current taxes 1,002 237 653 1,156 payable 7,151 (14,116) 3,513 15,212 Cash flows used in investing activities Purchase of (1,068) (629) (2,540) (1,099) property and equipment Proceeds on 352 - 397 - disposal of property and eqipment Business - - - 12 acquisition (716) (629) (2,143) (1,087) Cash flows (used in)/ from financing activities Increase - 14,094 - (12,455) (decrease) in bank operating loan (Decrease) in (6,443) - (648) - long term debt Issuance of - 92 - 111 capital stock - stock options exercised Settlement of - - - (178) share unit plan obligations Purchase of - (56) (23) (374) capital stock through normal course issuer bid Purchase of capital stock in trust for Share Unit Plans 8 (347) (699) (1,229) (6,435) 13,783 (1,370) (14,125) Change in cash and - (962) - - cash equivalentduring the period Cash and cash - 962 - - equivalentsat the beginning of the period Cash and cash - - - - equivalentsat the end of the period Cash paid during the period for: Interest 89 146 223 393 Income taxes 1,189 717 3,638 957 See accompanying notes to these condensed interim consolidated financial statements CE Franklin Ltd. ------------------------------ Notes to Condensed Interim Consolidated Financial Statements - Unaudited (Tabular amounts in thousands of Canadian dollars, except share and per share amounts) 1. General information CE Franklin Ltd. (the "Company") is headquartered and domiciled in Calgary, Canada. The Company is a subsidiary of Schlumberger Limited, a global energy services company. The address of the Company's registered office is 1800, 635 8th Ave SW, Calgary, Alberta, Canada and it is incorporated under the Alberta Business Corporations Act. The Company is a distributor of pipe, valves, flanges, fittings, production equipment, tubular products and other general industrial supplies primarily to the oil and gas industry through its 43 branches situated in towns and cities that serve oil and gas fields of the western Canadian sedimentary basin. In addition, the Company distributes similar products to the oil sands, refining, and petrochemical industries and non-oilfield related industries such as forestry and mining. 2. Accounting policies Basis of preparation and adoption of IFRS The Company prepares its financial statements in accordance with Canadian generally accepted accounting principles as set out in the Handbook of the Canadian Institute of Chartered Accountants ("CICA Handbook"). In 2010, the CICA Handbook was revised to incorporate International Financial Reporting Standards ("IFRS"), and require publicly accountable enterprises to apply such standards effective for years beginning on or after January 1, 2011. Accordingly, the Company commenced reporting on this basis in its 2011 interim consolidated financial statements. In these financial statements, the term "Canadian GAAP" refers to Canadian GAAP before the adoption of IFRS. These interim consolidated financial statements have been prepared in accordance with IFRS applicable to the preparation of interim financial statements, including IAS 34, Interim Financial Reporting, and IFRS 1, First-time Adoption of International Financial Reporting Standards. The accounting policies followed in these interim financial statements are the same as those applied in the Company's interim financial statements for the period ended March 31, 2011. The Company has consistently applied the same accounting policies throughout all periods presented, as if these polices had always been in effect. Note 3 discloses the impact of the transition to IFRS on the Company's reported equity as at September 30, 2011 and comprehensive income for the three and nine months ended September 30, 2011, including the nature and effect of significant changes in accounting policies from those used in the Company's consolidated financial statements for the year ended December 31, 2010. The accounting policies applied in these condensed interim consolidated financial statements are based on IFRS effective for the year ended December 31, 2011, as issued and outstanding as of October 27, 2011, the date the Board of Directors approved the statements. Any subsequent changes to IFRS that are given effect in the Company's annual consolidated financial statements for the year ending December 31, 2011 could result in the restatement of these interim consolidated financial statements, including transition adjustments recognized on change-over to IFRS. The condensed interim consolidated financial statements should be read in conjunction with the Company's Canadian GAAP annual financial statements for the year ended December 31, 2010, and the Company's interim financial statements for the quarter ended March 31, 2011 prepared in accordance with IFRS applicable to interim financial statements. 3. Explanation of transition to IFRS The Company does not have any material differences between IFRS and Canadian GAAP. As such there are no reconciling items that would materially change the reporting requirements under Canadian GAAP to IFRS. The interim consolidated financial statements for the period ended March 31, 2011 were the Company's first financial statements prepared under IFRS. For all accounting periods prior to this, the Company prepared its financial statements under Canadian GAAP. IFRS 1 allows first time adopters to IFRS to take advantage of a number of voluntary exemptions from the general principal of retrospective restatement. The Company has taken the following exemptions: IFRS 2 Share based payments The Company has elected to not apply IFRS 2 to share based payments granted and fully vested before the Company's date of transition to IFRS. The Company has assessed and quantified the difference in accounting for stock based compensation under IFRS compared to Canadian GAAP and has deemed the difference to be immaterial. IFRS 3 Business combinations This standard has not been applied to acquisitions of subsidiaries that occurred before January 1, 2010, the Company's transition date to IFRS. As such, there is no retrospective change in accounting for business combinations. IAS 23 Borrowing costs Borrowing costs requires an entity to capitalize borrowing costs directly attributable to the acquisition, construction or production of a qualifying asset (one that takes a substantial period of time to get ready for use or sale) as part of the cost of that asset. The option of immediately expensing those borrowing costs has been removed. The Company has elected to account for such transactions on a go forward basis. As such there is no retrospective change in accounting for borrowing costs. As part of the transition to IFRS the Company established that the carrying values of its property and equipment were substantially equivalent between IFRS and Canadian GAAP and therefore the Company has continued to carry its property and equipment at the historic costs model as was used under Canadian GAAP in these statements. 4.Accounts receivable September 30, 2011 December 31, 2010 Current 50,060 40,014 Less than 60 days overdue 34,301 41,253 Greater than 60 days overdue 7,193 5,519 Total Trade receivables 91,554 86,786 Allowance for credit losses (1,504) (1,887) Net trade receivables 90,050 84,899 Other receivables 6,039 8,051 96,089 92,950 A substantial portion of the Company's accounts receivable balance is with customers within the oil and gas industry and is subject to normal industry credit risks. Concentration of credit risk in trade receivables is limited as the Company's customer base is large and diversified. The Company follows a program of credit evaluations of customers and limits the amount of credit extended when deemed necessary. The Company has established procedures in place to review and collect outstanding receivables. Significant outstanding and overdue balances are reviewed on a regular basis and resulting actions are put in place on a timely basis. Appropriate provisions are made for debts that may be impaired on a timely basis. The Company maintains an allowance for possible credit losses that are charged to selling, general and administrative expenses by performing an analysis of specific accounts. 5. Inventories The Company maintains net realizable value allowances against slow moving, obsolete and damaged inventories that are charged to cost of goods sold on the statement of earnings. These allowances are included in the inventory value disclosed above. Movement of the allowance for net realizable value is as follows: Nine months ended Year ended September30, 2011 December 31, 2010 Opening balance as at January 1, 5,000 6,300 Additions 728 900 Utilization through write downs (1,358) (2,200) Closing balance 4,370 5,000 6. Taxation The difference between the income tax provision recorded and the provision obtained by applying the combined federal and provincial statutory rates is as follows: Three Months Ended Nine Months Ended September 30 September 30 2011 % 2010 % 2011 % 2010 % Earnings before 6,809 3,121 13,782 6,289 income taxes Income taxes 1,825 26.8 887 28.4 3,680 26.7 1,787 28.4 calculated at statutory rates Non-deductible 22 0.3 25 0.8 55 0.4 80 1.3 items Share based 19 0.3 46 1.5 81 0.6 159 2.5 compensation Adjustments for 164 2.4 (11) (0.4) 131 0.9 (9) (0.1) filing returns and others 2,030 29.8 947 30.3 3,947 28.6 2,017 32.1 As at September 30, 2011, income taxes payable was $1.0 million (December 31, 2010 - $0.3 million payable). Income tax expense is based on management's best estimate of the weighted average annual income tax rate expected for the full financial year. As at September 30, 2011 December 31, 2010 Assets Property and equipment 887 870 Stock based compensation 830 487 expense Other 536 156 2,253 1,513 Liabilities Goodwill and other 660 397 Net Deferred taxasset 1,593 1,116 Deductible temporary differences are recognized to the extent that it is probable that taxable profit will be available against which the deductible temporary differences can be utilized. 7. Accounts payable and accrued liabilities   September 30, 2011 December 31, 2010 Current Trade payables 24,899 23,966 Other payables 9,477 7,057 Accrued compensation 2,951 2,434 expenses Other accrued liabilities 32,629 29,906 69,956 63,363 8. Long term debt and bank operating loan September30, 2011 December 31, 2010 JEN Supply debt 290 290 Bank operating loan 5,492 6,140 Long term debt 5,782 6,430 In July of 2011, the Company entered into a $60.0 million revolving term Credit Facility that matures in July 2014.  Borrowings under the Credit Facility bear interest based on floating interest rates and are secured by a general security agreement covering all assets of the Company. The maximum amount available under the Credit Facility is subject to a borrowing base formula applied to accounts receivable and inventories. The Credit Facility requires that the Company maintains the ratio of its debt to debt plus equity at less than 40%. As at September 30, 2011, this ratio was 3% (December 31, 2010 - 4%). The Company must also maintain coverage of its net operating cash flow as defined in the Credit Facility agreement, over interest expense for the trailing twelve month period, at greater than 1.25 times. As at September 30, 2011, this ratio was 24.9 times (December 31, 2010 - 14.1 times).  The Credit Facility contains certain other covenants, with which the Company is in compliance and has been for the comparative periods. As at September 30, 2011, the Company had borrowed $5.5 million and had available undrawn borrowing capacity of $54.5 million under the Credit Facility. In management's opinion, the Company's available borrowing capacity under its Credit Facility and ongoing cash flow from operations, are sufficient to resource its ongoing obligations. The JEN Supply debt is unsecured and bears interest at the floating Canadian bank prime rate and is repayable in 2012. 9. Capital management The Company's primary source of capital is its shareholders' equity and cash flow from operating activities before net changes in non-cash working capital balances. The Company augments these capital sources with a $60 million, revolving bank term loan facility maturing in July 2014 (see Note 8) which is used to finance its net working capital and general corporate requirements. The Company's objective is to maintain adequate capital resources to sustain current operations including meeting seasonal demands of the business and the economic cycle.  The Company's capital is summarised as follows: September 30, 2011 December 31, 2010 Shareholders' equity 161,205 150,536 Long term debt / Bank 5,782 6,430 operating loan Net working capital 134,601 125,702 Net working capital is defined as current assets less cash and cash equivalents, accounts payable and accrued liabilities, current taxes payable and other current liabilities. 10. Related party transactions Schlumberger owns approximately 56% of the Company's outstanding shares. The Company is the exclusive distributor in Canada of downhole pump production equipment manufactured by Wilson Supply, a division of Schlumberger. Purchases of such equipment conducted in the normal course on commercial terms were as follows: For the nine months ended September 30 2011 2010 Cost of sales for the three months ended 3,357 2,232 Cost of sales for the nine months ended 7,446 5,932 Inventory 4,854 3,323 Accounts payable and accrued liabilities 1,264 953 Accounts receivable 4 - 11. Capital Stock a) The Company has authorized an unlimited number of common shares with no par value. At September 30, 2011, the Company had 17.5 million common shares, 0.7 million stock options and 0.6 million share units outstanding. b) The Board of Directors may grant options to purchase common shares to substantially all employees, officers and directors and to persons or corporations who provide management or consulting services to the Company.  The exercise period and the vesting schedule after the grant date are not to exceed 10 years. Option activity for each of the nine month periods ended September 30 was as follows: (000's) 2011 2010 Outstanding - January 1 1,073 1,195 Exercised (97) (73) Forfeited (228) (26) Outstandingat September 30 748 1,096 Exercisable at September 30 662 824 Stock based compensation expense recorded for the three and nine month period ended September 30, 2011 was $72,000 (2010 - $517,000) and $302,000 (2010 - $1,271,000) respectively and is included in selling, general and administrative expenses on the Consolidated Statement of Earnings and Comprehensive Income.  No options were granted during the nine  month period ended September 30, 2011 or the year ended December 31, 2010. Options vest one third or one fourth per year from the date of grant. Prior to the fourth quarter of 2010, the Company's stock option plan included a cash settlement mechanism. During the fourth quarter of 2010, the Company discontinued the settlement of stock option obligations with cash payments in favour of issuing shares from treasury. At the time of this plan modification, the current liability of $2,075,000 was transferred to contributed surplus on the Company's consolidated statement of financial position. Stock options were revalued at each period end using the Black Scholes pricing model, the following assumptions were used: 2010 Dividend yield Nil Risk-free interest rate 3.48% Expected life 5 years Expected volatility 63.2% Note: Expected volatility is based on historical volatility. c) Share Unit Plans The Company has Restricted Share Unit ("RSU"), Performance Share Unit ("PSU") and Deferred Share Unit ("DSU") plans (collectively the "Share Unit Plans"), where by RSU's, PSU's and DSU's are granted entitling the participant, at the Company's option, to receive either a common share or cash equivalent in exchange for a vested unit. For the PSU plan the number of units granted is dependent on the Company meeting certain return on net asset ("RONA") performance thresholds during the year of grant. The multiplier within the plan ranges from 0% - 200% dependent on performance. RSU and PSU grants vest one third per year over the three year period following the date of the grant. DSU's vest on the date of grant, and can only be redeemed when the Director resigns from the Board.  Compensation expense related to the units granted is recognized over the vesting period based on the fair value of the units at the date of the grant and is recorded to contributed surplus.  The contributed surplus balance is reduced as the vested units are exchanged for either common shares or cash. During the nine month period ended September 30, 2011 and 2010 the fair value of the RSU, PSU and DSU units granted was $2,219,000 (2010 - $1,968,000) and compensation expense recorded in the three and nine month period ended September 30, 2011, were $262,000 (2010 - $349,000) and $1,053,000 (2010 - $961,000). Share Unit Plan activity for the periods ended September 30, 2011, and December 31, 2010 was as follows: (000's) September 30, 2011 December 31, 2010 Number ofUnits Number of Units RSU PSU DSU Total RSU PSU DSU Total Outstanding at January 1 273 97 80 450 223 53 98 374 Granted 128 117 22 267 145 132 31 308 Performance adjustments - - - - - (77) - (77) Exercised (35) (10) - (45) (82) (7) (49) (138) Forfeited (55) (42) - (97) (13) (4) - (17) Outstanding at end of period 311 162 102 575 273 97 80 450 Exercisable at end of period 96 35 102 233 30 10 80 120 The Company has established an independent trust to purchase common shares of the Company on the open-market to satisfy Share Unit Plan obligations. The Company's intention is to settle all share based obligations with shares delivered from the trust. The trust is considered to be a special interest entity and is consolidated in the Company's financial statements with the cost of the shares held in trust reported as a reduction to capital stock.  For the nine month period ended September 30, 2011, 75,500 common shares were purchased by the trust (2010 - 179,300) at an average cost of $9.26 per share (2010 - $6.79).  As at September 30, 2011, the trust held 481,726 shares (2010  - 471,610). d) Normal Course Issuer Bid ("NCIB") On December 21, 2010, the Company announced a NCIB to purchase for cancellation up to 850,000 common shares representing approximately 5% of its outstanding common shares. During the nine months ended September 30, 2011, the company purchased 3,102 shares at an average cost of $7.56 (2010: 57,878 shares purchased at an average cost of $6.61). 12. Earnings per share Basic Basic earnings per share is calculated by dividing the net income attributable to shareholders by the weighted average number of ordinary shares in issue during the year. Dilutive Diluted earnings per share are calculated using the treasury stock method, as if RSU's, PSU's, DSU's and stock options were exercised at the beginning of the year and funds received were used to purchase the Company's common shares on the open market at the average price for the year. Three MonthsEnded Nine Months Ended September 30 September 30 2011 2010 2011 2010 Total Comprehensive income 4,779 2,175 9,835 4,272 attributable to shareholders Weighted average number of common 17,537 17,461 17,507 17,518 shares issued (000's) Adjustments for: Stock options 250 39 380 - Share Units 378 283 255 320 Weighted average number of 18,165 17,783 18,142 17,838 ordinary shares for dilutive Net earnings per share: Basic 0.27 0.12 0.56 0.24 Net earnings per share: Diluted 0.26 0.12 0.54 0.24 13. Financial instruments a) Fair values The Company's financial instruments recognized on the consolidated statements of financial position consist of accounts receivable, accounts payable and accrued liabilities and long term debt. The fair values of these financial instruments, excluding long term debt, approximate their carrying amounts due to their short-term maturity. At September 30, 2011, the fair value of the long term debt approximated their carrying values due to their floating interest rate nature and short term maturity. Long term debt is initially recorded at fair value and subsequently measured at amortized cost using the effective interest rate method. b) Credit Risk is described in Note 4. c) Market Risk and Risk Management The Company's long term debt bears interest based on floating interest rates. As a result the Company is exposed to market risk from changes in the Canadian prime interest rate which can impact its borrowing costs. Based on the Company's borrowing levels as at September 30, 2011, a change of one percent in interest rates would decrease or increase the Company's annual net income by $0.1 million. From time to time the Company enters into foreign exchange forward contracts to manage its foreign exchange market risk by fixing the value of its liabilities and future commitments. The Company is exposed to possible losses in the event of non-performance by counterparties. The Company manages this credit risk by entering into agreements with counterparties that are substantially all investment grade financial institutions. The Company's foreign exchange risk arises principally from the settlement of United States dollar dominated net working capital balances as a result of product purchases denominated in United States dollars. As at September 30, 2011, the Company had contracted to purchase US$14.2 million at fixed exchange rates with terms not exceeding nine months (December 31, 2010 - $6.5 million). The fair market values of the contracts were $1.0 million at September 30, 2011 and nominal at December 31, 2010. The Company recorded on these contracts an unrealized gain of $1.0 million for the three and nine month periods ended September 30, 2011 which has been recorded in foreign exchange (gain) loss.  As at September 30, 2011, a one percent change in the Canadian dollar relative to the US dollar would decrease or increase the Company's annual net income by $0.1 million. Selling, general and administrative ("SG&A") Costs Selling, general and administrative costs for the three and nine month periods ended September 30 are as follows: Three months ended Nine months ended 2011 2010 2011 2010 $ % $ % $ % $ % Salaries and 10,596 60% 8,938 58% 30,908 60% 26,500 58% Benefits Selling Costs 1,663 9% 1,843 12% 4,216 8% 4,583 10% Facility and 4,268 24% 3,211 21% 11,520 23% 10,081 22% office costs Other 1,274 7% 1,519 9% 4,537 9% 4,657 10% SG&A costs 17,801 100% 15,511 100% 51,181 100% 45,821 100% 15. Segmented reporting The Company distributes oilfield products principally through its network of 43 branches located in western Canada primarily to oil and gas industry customers.  Accordingly, the Company has determined that it operated through a single operating segment and geographic jurisdiction. 16. Seasonality The Company's sales levels are affected by weather conditions. As warm weather returns in the spring each year, the winter's frost comes out of the ground rendering many secondary roads incapable of supporting the weight of heavy equipment until they have dried out. In addition, many exploration and production areas in northern Canada are accessible only in the winter months when the ground is frozen. As a result, the first and fourth quarters typically represent the busiest time for oil and gas industry activity and the highest sales activity for the Company. Revenue levels drop dramatically during the second quarter until such time as roads have dried and road bans have been lifted. This typically results in a significant reduction in earnings during the second quarter, as the decline in revenues typically out paces the decline in SG&A costs as the majority of the Company's SG&A costs are fixed in nature. Net working capital (defined as current assets less cash and cash equivalents, accounts payable and accrued liabilities, income taxes payable and other current liabilities) and bank revolving loan borrowing levels follow similar seasonal patterns as revenues.             CE Franklin Ltd. CONTACT: Investor Relations800-345-2858403-531-5604investor@cefranklin.com

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