CFK CE Franklin Ltd. (MM)

CALGARY, April 26, 2012 /CNW/ - CE FRANKLIN LTD. (TSX.CFT, NASDAQ.CFK) reported net earnings of $7.9 million or $0.46 per share (basic) for the first quarter ended March 31, 2012, a significant increase from net earnings of $3.4 million or $0.19 per share (basic) generated in the first quarter ended March 31, 2011. Financial Highlights (millions of Cdn. $ except per share data) Three Months Ended March31 2012 2011 Unaudited Revenues $ 160.3 $ 137.7 Gross Profit $ 29.4 $ 22.3 Gross Profit - % of sales 18.3% 16.2% EBITDA(1) $ 11.3 $ 5.3 EBITDA % of sales(1) 7.0% 3.8% Net earnings $ 7.9 $ 3.4 Per share Basic $ 0.46 $ 0.19 Diluted $ 0.44 $ 0.19 Net working capital(2) $ 137.8 $ 120.1 Long term debt $ - $ 0.3 "Solid revenue growth, improved product margins and disciplined cost management lead to increased profitability.  Activity levels are expected to remain at prior year levels as strong oil and oilsands activity offsets softer gas activity," said Michael West, President and CEO. Net earnings for the first quarter of 2012, were $7.9 million, an increase of $4.5 million (132%) from the first quarter of 2011.  Revenues were $160.3 million, an increase of $22.6 million (16%) from the first quarter of 2011. Despite well completions decreasing by 26% compared to the first quarter of 2011, both the capital project business and maintenance repair and operating ("MRO") revenues grew by $7.3 million and $15.1 million respectively year over year. The increase in capital projects revenue was driven by higher sales to oil and oilsands projects.  Increased MRO activity came from all areas of the business.  Spring break up arrived earlier than normal and dampened activity levels late in the quarter.  Gross profits increased by $7.1 million (32%) due to the increase in revenues and improved gross profit margins year over year. Average gross profit margins improved sequentially compared to the fourth quarter of 2011 and improved over the first quarter 2011 due to improved supply chain costs and increased volume rebate income arising from increased purchasing levels. Selling, general and administrative expenses increased by $0.8 million (5%) to $17.8 million for the quarter as compensation and operating costs have increased in response to higher revenue levels. The weighted average number of shares outstanding during the first 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 $0.46 in the first quarter of 2012, compared to net earnings of $0.19 per share in the first quarter of 2011. Business Outlook Oil and gas industry activity in 2012 is expected to remain at 2011 levels for the remainder of the year.  Natural gas prices remain depressed as North American production capacity and inventory levels continue to exceed demand.  Natural gas capital expenditure activity is focused on liquid rich gas plays and the Company is well positioned to service customers pursuing these gas plays.  Conventional and heavy oil economics are attractive at current price levels leading to continuing activity in on these plays.  Activity is especially strong in southeast Saskatchewan.  Oil sands project announcements are expected to continue with 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 through organic growth 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 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 IFRS. 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 first quarter 2012 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 2012 first quarter results, which is open to the public, will be held on Friday, April 27, 2012 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 63408715 and may be accessed until midnight May 3, 2012. The call will also be webcast live at: http://www.newswire.ca/en/webcast/detail/938361/1004129 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 75 years, 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 39 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. The following 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 should be read in conjunction with the Company's condensed interim consolidated financial statements for the three month period ended March 31, 2012 and the MD&A and consolidated financial statements for the year ended December 31, 2011. All amounts are expressed in Canadian dollars and are in accordance with International Financial Reporting Standards ("IFRS") as issued by the International Accounting Standards Board ("IASB"), except where otherwise noted. 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 in Canada through its 39 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, midstream, refining, petrochemical 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 infrastructure enables us to provide our customers with the products they need on a same day or overnight basis.  Our centralized inventory and procurement capabilities allow us to leverage our scale to enable industry leading hub and spoke purchasing, logistics and project execution capabilities. The 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 common shares trade on the TSX ("CFT") and NASDAQ ("CFK") stock exchanges.  Schlumberger Limited ("Schlumberger"), a major oilfield service company based in Paris, France, indirectly owns approximately 56% of the Company's shares. Business Strategy The Canadian oilfield equipment supply industry is highly competitive and fragmented.  There are approximately 230 oilfield supply stores in Canada which generate annual estimated sales of $2 billion to $3 billion.  CE Franklin competes with three other large oilfield product distributors and with numerous local and regional distributors as well as specialty equipment distributors and manufacturers.  The oilfield equipment market is part of the larger industrial equipment supply market, which is also serviced by numerous competitors.  The oil sands and niche industrial product markets are more specialized and solutions oriented and require more in-depth product knowledge and supplier relationships to service specific customer requirements. Oilfield equipment distributors compete based on price and level of service.  Service includes the ability to consistently provide required products to a customer's operating site when needed, project management services, product expertise and support, billing and expenditure management services, and related equipment services. Demand for oilfield products and services is driven by the level of capital expenditures in the oil and gas industry in the Western Canadian sedimentary basin as well as by production related maintenance, repair and operating ("MRO") requirements.  MRO demand tends to be relatively stable over time and predictable in terms of product and service requirements and typically comprises 40% to 50% of the Company's annual sales.  Capital project demand fluctuates over time with oil and gas commodity prices, which directly impacts the economic returns realized by oil and gas companies. The size, scope, and product mix of each order will affect profitability.  Local walk in relationship business with smaller orders or more specialized products will typically generate higher profit margins compared to large project bids for alliance customers where the Company can take advantage of volume discounts and longer lead times.  Larger oil and gas customers tend to have a broader geographic operating reach requiring multi-site service capability, conducting larger capital projects, and requiring more sophisticated billing and project management services than do smaller customers.  The Company has entered into numerous alliances with larger customers where the scale and repeat nature of business enables efficiencies which are shared with the customer through lower profit margins. Barriers to entry in the oilfield supply business are low with start-up operations typically focused on servicing local relationship based MRO customers.  To compete effectively on capital project business and to service larger customers requires multi-location branch operations, increased financial, procurement, product expertise and breadth of product lines, information systems and process capability, which significantly increases the barriers to entry. The Company's 39 branch operations provide substantial geographic coverage across the oil and gas producing regions in western Canada.  Each branch services and competes for local business and services the Company's alliance customers supported by centralized support services provided by the Company's Distribution Centre and corporate office in Calgary. The Company's large branch network, coupled with its centralized capabilities enables it to develop strong supply chain relationships with suppliers and provide it with a competitive advantage over local independent oilfield and specialty equipment distributors for large alliance customers who are seeking multi-location, one stop shopping, and more comprehensive service. 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 may be complemented by selected acquisitions. -- Expand production equipment service capability to capture more of the product life cycle requirements for the equipment the Company sells such as downhole pump repair, oilfield engine maintenance, well optimization and onsite project management. This will differentiate the Company's service offering from its competitors and deepen relationships with its customers. -- Expand oil sands, industrial project and MRO business by leveraging our existing supply chain infrastructure, product, and major 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 customer service. Business Outlook Oil and gas industry activity in 2012 is expected to remain at 2011 levels for the remainder of the year.  Natural gas prices remain depressed as North American production capacity and inventory levels continue to exceed demand.  Natural gas capital expenditure activity is focused on liquid rich gas plays and the Company is well positioned to service customers pursuing these gas plays.  Conventional and heavy oil economics are attractive at current price levels leading to continuing activity in on these plays.  Activity is especially strong in 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 through organic growth 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. ThreeMonthsEndedMarch 31 2012 2011 Revenues 160.3 100.0 % 137.7 100.0 % Cost of Sales (130.9) (81.7) % (115.4) (83.9) % Gross Profit 29.4 18.3 % 22.3 16.1 % Selling, general and administrative expenses (17.8) (11.1) % (17.0) (12.8) % Foreign exchange and other (0.3) (0.2) % - - % EBITDA(1) 11.3 7.0 % 5.3 3.4 % Depreciation (0.6) (0.4) % (0.6) (0.5) % Interest (0.1) (0.1) % (0.2) (0.2) % Earnings before tax 10.6 6.5 % 4.6 2.7 % Income tax expense (2.7) (1.6) % (1.2) (0.9) % Net earnings 7.9 4.9 % 3.4 1.8 % Net earnings per share Basic $ 0.46 $ 0.19 Diluted $ 0.44 $ 0.19 Weighted average number of shares outstanding (000's) Basic 17,443 17,488 Diluted 18,149 18,052 (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 IFRS. Accordingly, EBITDA, as the term is used herein, is unlikely to be comparable to EBITDA as reported by other entities. First Quarter Results Net earnings for the first quarter of 2012, were $7.9 million, an increase of $4.5 million (132%) from the first quarter of 2011.  Revenues were $160.3 million, an increase of $22.6 million (16%) from the first quarter of 2011. Despite well completions decreasing by 26% compared to the first quarter of 2011, both the capital project business and maintenance repair and operating ("MRO") revenues grew by $7.3 million and $15.1 million respectively year over year. The increase in capital projects revenue was driven by higher sales to oil and oilsands projects.  Increased MRO activity came from all areas of the business.  Spring break up arrived earlier than normal and dampened activity levels late in the quarter.  Gross profits increased by $7.1 million (32%) due to the increase in revenues and improved gross profit margins year over year. Average gross profit margins improved sequentially compared to the fourth quarter of 2011 and improved over the first quarter 2011 due to improved supply chain costs and increased volume rebate income arising from increased purchasing levels. Selling, general and administrative expenses increased by $0.8 million (5%) to $17.8 million for the quarter as compensation and operating costs have increased in response to higher revenue levels. The weighted average number of shares outstanding during the first 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 $0.46 in the first quarter of 2012, compared to net earnings of $0.19 per share in the first quarter of 2011. Revenues Revenues for the quarter ended March 31, 2012, were $160.3 million, an increase of 16% from the quarter ended March 31, 2011. 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 three month periods ended March 31, 2012 and 2011 are provided in the table below. Q1 Average % 2012 2011 change Gas - Cdn. $ 2.14 $ 3.76 (43)% $/gj (AECO spot) Oil - Cdn. $ 94.49 $ 99.63 (5)% $/bbl (synthetic crude) Average rig 541 532 2 % count Well completions: Oil 2,262 2,201 3 % Gas 611 1,660 (63)% Total well 2,873 3,861 (26)% 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 of Three monthsended March31 Cdn. $) 2012 2011 End use revenue $ % $ % demand Capital projects 83.5 52 76.0 55 Maintenance, repair 76.8 48 61.7 45 and operating supplies ("MRO") Total Revenues 160.3 100 137.7 100 Revenues from capital project related products were $83.5 million in the first quarter of 2012, an increase of 10% ($7.5 million) from the first quarter of 2011 due to increased oil and oil sands based sales. Total well completions decreased by 26% in the first quarter of 2012.  Gas well completions comprised 21% of the total wells completed in western Canada in the first quarter of 2012 compared to 43% in the first quarter 2011.  The average working rig count increased by 2% compared to the prior year period. Spot gas prices ended the first quarter at $2.14 per GJ (AECO) a decrease of 43% from first quarter 2011 average prices.  Oil prices ended the first quarter at $94.49 per bbl (Synthetic Crude) a decrease of 5% from the first quarter 2011 average. Depressed gas prices are expected to continue to negatively impact gas drilling and well completion activity over the remainder of 2012, 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.  Activity related to oil and oilsands activity remains strong and the Company is well positioned to support customers who are pursuing oil plays and more particularly tight oil plays.  Spring break up arrived in late March which dampened activity levels late in the quarter. 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 March 31, 2012 increased by $15.1 million (24%) to $76.8 million compared to the quarter ended March 31, 2011 and comprised 48% of the Company's total revenues (2011 - 45%) as both oil and gas MRO activities were strong in the quarter. The Company's strategy is to grow profitability by focusing on its core western Canadian oilfield product distribution business, complemented by an increase in the product life cycle services provided to its customers and the focus on the emerging oil sands capital project and MRO revenues opportunities. Revenues from these initiatives to date are provided below: Q12012 Q12011 Revenues($millions) $ % $ % Oilfield 140.4 87 122.6 89 Oil sands 12.1 8 10.0 7 Production services 7.8 5 5.1 4 Total Revenues 160.3 100 137.7 100 Revenues from oilfield products to conventional western Canada oil and gas end use applications were $120.3 million for the first quarter of 2012, backing out tubular product sales, year over year oilfield revenue was up 19.4%. This increase was driven by oil related capital projects and strong MRO demand. Revenues from oil sands end use applications were $12.1 million in the first quarter, an increase of $2.1 million (21%) from the first quarter of 2011 reflecting the timing of project revenues. 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 $7.8 million in the first quarter of 2012, a 53% increase from the $5.1 million of revenues in the first quarter of 2011, reflecting improved oil production economics resulting in increased customer maintenance activities. Gross Profit Q12012 Q1 2011 Gross profit ($ $ 29.4 $ 22.3 millions) Gross profit margin as 18.3 % 16.1 % a % of revenues Gross profit composition by product revenue category: Tubulars 3 % 6 % Pipe, flanges and 30 % 26 % fittings Valves and accessories 19 % 21 % Pumps, production 19 % 15 % equipment and services General 29 % 32 % Total gross profit 100 % 100 % Gross profit was $29.4 million in the first quarter of 2012, an increase of $7.1 million (32%) from the first quarter of 2011 due to increased revenues and average gross profit margins compared to the prior year period. Gross profit margins for the quarter were improved due to improved supply chain costs and recognition of higher volume rebate income due to higher purchasing levels.  Increased pipe flanges and fittings gross profit composition was due to improved gross profit margins.  Other gross profit composition categories were impacted by having more sales to our larger lower margin customers.  The decrease in tubular gross profit composition reflects larger lower margin sales and the disposal of surplus tubular inventory. Selling, General and Administrative ("SG&A")Costs ($millions) Q12012 Q1 2011 $ % $ % People Costs 11.0 61 10.3 60 Facility and office 3.5 20 3.7 22 costs Selling Costs 1.9 11 1.5 9 Other 1.4 8 1.5 9 SG&A costs 17.8 100 17.0 100 SG&A costs as % of 11% 12% revenues SG&A costs increased $0.8 million (5%) in the first quarter of 2012 from the prior year period and represented 11% of revenues compared to 12% in the prior year period. The $0.8 million increase in expenses was attributable to higher incentive and selling costs reflecting the improved performance of the business year over year. Depreciation Expense Depreciation expense of $0.6 million in the first quarter of 2012 was comparable to the first quarter of 2011. Interest Expense Interest expense was minimal in the first quarter of 2012 and was lower than the prior year due to lower borrowing levels. Foreign Exchange and other Foreign exchange and other in the quarter was a loss of $0.3 million as the Canadian dollar strengthened which increased the translation loss from US denominated net working capital assets.  The Company recognized a $0.3 million unrealized foreign exchange loss on $11.6 million of foreign currency forward contracts it had outstanding at quarter end.  As at March 31, 2012, a one percent change in the Canadian dollar relative to the US dollar would decrease or increase the Company's annual net income by approximately $0.1 million. Income Tax Expense The Company's effective tax rate for the first quarter of 2012 was 25.5% down from a 26.5% effective rate in the first quarter 2011. The current effective tax rate is lower than the prior year due to lower statutory rates. Summary of Quarterly Financial Data The selected quarterly financial data below is presented in Canadian dollars and in accordance with IFRS.  This information is derived from the Company's unaudited quarterly financial statements. (in millions of Cdn. $ except per sharedata) Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Unaudited 2010 2010 2010 2011 2011 2011 2011 2012 Revenues 99.9 132.2 135.6 137.7 113.9 140.5 154.3 160.3 Gross Profit 15.6 19.2 20.5 22.3 19.3 23.9 25.3 29.4 Gross % % % % % % % % Profit % 15.6 14.5 15.1 16.2 16.9 17.0 16.4 18.3 EBITDA 0.7 3.8 3.8 5.3 3.1 7.6 6.6 11.3 EBITDA as a % % % % % % % % % of revenues 0.7 2.9 2.8 3.8 2.7 5.4 4.3 7.0 Net earnings (loss) (0.1) 2.2 1.6 3.4 1.7 4.8 4.5 7.9 Net earnings (loss) as a % of revenues (0.1) % 1.7 % 1.2 % 2.5 % 1.5 % 3.4 % 2.9 % 4.9 % Net earnings (loss) per share Basic $ (0.01) $ 0.12 $ 0.09 $ 0.19 $ 0.10 $ 0.27 0.26 $ 0.46 Diluted $ (0.01) $ 0.12 $ 0.09 $ 0.19 $ 0.09 $ 0.26 0.25 $ 0.44 Net working capital(1) 111.8 129.0 125.7 120.1 136.5 134.6 116.9 137.8 Long term debt / bank operating loan(1) 0.3 14.4 6.4 0.3 12.2 5.8 - - Total well completions 2,197 2,611 4,760 3,861 2,765 3,495 4,350 2,873 (1) Net working capital and long term debt/bank operating loan amounts are as at quarter end 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 oilfield sales activity for the Company.  Oilfield sales 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 sales typically outpaces 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, current taxes payable, note payable and other current liabilities) and borrowing levels follow similar seasonal patterns as sales. Liquidity and Capital Resources The Company's primary internal source of liquidity is cash flow from operating activities before changes in non-cash net working capital balances.  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 March 31, 2012, the Company had $3.6 million of cash on hand and had no long term debt. Cash decreased by $12.2 million from December 31, 2011 as the Company generated $9.7 million of cashflow from operating activities, before net changes in non-cash working capital balances. Net working capital increased by $22.0 million in the quarter.  Capital expenditures in the quarter amounted to $0.3 million.  Nominal activity occurred under the Company's Normal Course Issuer bid ("NCIB") program.  Subsequent to quarter end, the Company terminated its NCIB program for this year. As at March 31, 2011, the Company had $3.2 million of cash and cash equivalents and no borrowings under its revolving term credit facility, a net decrease of $9.4 million from December 31, 2010.  Borrowing levels have decreased due to the Company generating $4.4 million in cash flow from operating activities, before net changes in non-cash working capital balances of a $5.6 million reduction in net working capital.  This was offset by $0.5 million in capital and other expenditures and $0.2 million for the purchase of shares to resource share unit plan obligations and the repurchase of shares under the NCIB program. Net working capital was $137.8 million at March 31, 2012, an increase of $21.0 million from December 31, 2011. Accounts receivable at March 31, 2012 was $103.9 million, an increase of $5.7 million (5.8%) from December 31, 2011, due to the 4% increase in first quarter sales compared to the fourth quarter of 2011.  Days sales outstanding in accounts receivable ("DSO") at the end of the first quarter of 2012 was 52 days which is consistent with where the fourth quarter of 2011 ended.  DSO is calculated using average sales per day for the quarter compared to the period end customer accounts receivable balance.  Inventory at March 31, 2012 was $113.1 million, up $1.4 million (1.3%) from December 31, 2011.  Inventory turns at the end of the first quarter of 2012 were 4.6 turns were consistent with the fourth quarter of 2011.  Inventory turns are calculated using cost of goods sold for the quarter on an annualized basis, compared to the period end inventory balance.  Accounts payable and accrued liabilities at March 31, 2012 were $79.9 million, a decrease of $13.7 million (15%) compared to the fourth quarter of 2011. Capital expenditures in Q1 2012 were $0.3 million, an increase of $0.2 million (49%) from Q4 2011 expenditures. Expenditures in 2012 were directed towards facility expansion and maintenance, business system expansion and vehicles and operating equipment.  The majority of the expenditures in Q1 2012 were directed towards similar items as they were in 2011. Capital expenditures in 2012 are anticipated to be in the $4.0 million to $5.0 million range and will be directed towards business system, branch facility, vehicle and operating equipment upgrades and replacements. In July 2011, the Company renewed its $60.0 million revolving term credit facility that matures in July 2014 (the "Credit Facility").   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 the Company to maintain the ratio of its debt to debt plus equity at less than 40%.  As at December 31, 2011, this ratio was 0%.  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 March 31, 2012, this ratio was 51.3 times.  The Credit Facility contains certain other covenants with which the Company is in compliance.  As at March 31, 2012, the Company had no borrowings under the facility and had available undrawn borrowing capacity of $60.0 million under the Credit Facility. Contractual Obligations There have been no material changes in off-balance sheet contractual commitments since December 31, 2011. Capital Stock As at March 31, 2012 and 2011, the following shares and securities convertible into shares were outstanding: (millions) March 31, 2012 March31, 2011 Shares Shares Shares outstanding 17.5 17.5 Stock options 0.7 1.0 Share unit plan 0.7 0.7 obligations Shares outstanding 18.9 19.2 and issuable The weighted average number of shares outstanding during the first quarter of 2012 was 17.4 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 18.1 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 month period ended March 31, 2012, nil common shares were purchased by the trust (March 31, 2011 - 25,000 common shares at an average cost of $8.75 per share). As at March 31, 2012, the trust held 566,277 shares (March 31, 2011 - 462,753). On December 20, 2011, the Company announced the renewal of the NCIB effective January 3, 2012, to purchase up to 850,000 common shares through the facilities of NASDAQ, representing approximately 5% of its outstanding common shares.  During the three month period ended March 31, 2012, the Company purchased 8,625 shares at an average cost of $8.11 (March 31, 2011: 3,102 shares purchased at an average cost of $7.56). Subsequent to the quarter end, the Company has cancelled its NCIB program.  At the time the program was cancelled, the Company had acquired 9,225 shares at an average cost of $8.59 per share. Critical Accounting Estimates There have been no material changes to critical accounting estimates since December 31, 2011. The Company is not aware of any environmental or asset retirement obligations that could have a material impact on its operations. Subsequent Events Subsequent to March 31, 2012, the Company announced that the Board of Directors and the Special Committee of the Board of Directors have decided it is in the best interest of CE Franklin and all shareholders to formally commence a strategic review process.  Further to the announcement of a Strategic Review Process, the Company adopted a Shareholders' Rights Plan to ensure that, in the context of a bid for control of CE Franklin, the Board of Directors would have sufficient time to consider the bid and conduct the Strategic Review Process.  Additionally, the Shareholders' Rights Plan gives shareholders an equal opportunity to participate in such a bid; and gives them adequate time to properly assess the bid.  The Shareholders' Rights Plan is not intended to and will not prevent a sale of CE Franklin. 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 three months ended March 31, 2012 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, 2011 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 2012 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 outcome of the Company's strategic review process -- 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 first quarter 2012 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 March 31 As at December 31 (in thousands of Canadian dollars) 2012 2011 Assets Current assets Cash and cash equivalents (Note 3,619 15,830 3) Accounts receivable (Note 4) 103,887 98,190 Inventories (Note 5) 113,122 111,661 Other 3,050 2,565 223,678 228,246 Non-current assets Property and equipment 9,403 9,709 Goodwill 20,570 20,570 Deferred tax assets (Note 6) 1,741 1,969 Other assets 155 171 Total Assets 255,547 260,665 Liabilities Current liabilities Accounts payable and accrued 79,874 93,613 liabilities (Note 7) Current taxes payable (Note 6) 2,079 1,663 Note payable (Note 8) 290 290 Total Liabilities 82,243 95,566 Shareholders' equity Capital stock (Note 11) 22,930 22,536 Contributed surplus 20,459 20,529 Retained earnings 129,915 122,034 173,304 165,099 Total Liabilities and Shareholders' 255,547 260,665 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 Capital Stock dollars and number of shares in thousands) Number of Contributed Retained Shareholders' Shares $ Surplus Earnings Equity Balance - 17,474 23,078 19,716 107,742 150,536 January 1, 2011 Stock based - - 426 - 426 compensation expense (Note 11 (b) and (c)) Normal (3) (4) - (19) (23) course issuer bid (Note 11 (d)) Stock 51 400 (400) - - options exercised (Note 11 (b)) Share Units 13 77 (77) - - exercised (Note 11 (c)) Purchase of (25) (219) - - (219) shares in trust for Share Unit Plans (Note 11 (c)) Net earnings - - - 3,375 3,375 Balance - 17,510 23,332 19,665 111,098 154,095 March 31, 2011 Balance - 17,440 22,536 20,529 122,034 165,099 January 1, 2012 Stock based - - 335 - 335 compensation expense (Note 11 (b) and (c)) Normal (9) (11) - (59) (70) Course Issuer Bid (Note 11 (d)) Stock 11 71 (71) - - options exercised (Note 11 (b)) Share Units 14 334 (334) - - exercised (Note 11 (c)) Net earnings - - - 7,940 7,940 Balance - 17,456 22,930 20,459 129,915 173,304 March 31, 2012 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 March 31 March 31 (in thousands of Canadian dollars) 2012 2011 Revenue 160,253 137,701 Cost of sales 130,901 115,424 Gross profit 29,352 22,277 Other expenses Selling, general and administrative expenses 17,771 16,980 (Note 14) Depreciation 579 602 18,350 17,582 Operating profit 11,002 4,695 Foreign exchange loss and other 320 10 Interest expense 34 94 Earnings before tax 10,648 4,591 Income tax expense (recovery) (Note 6) Current 2,480 1,360 Deferred 228 (144) 2,708 1,216 Net earnings and comprehensive income 7,940 3,375 Net earnings per share (Note 12) Basic 0.46 0.19 Diluted 0.44 0.19 Weighted average number of share outstanding ('000s) Basic 17,443 17,488 Diluted (Note 12) 18,149 18,052 See accompanying notes to these condensed interim consolidated financial statements CE Franklin Ltd. CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CASH FLOWS - UNAUDITED Three months ended March 31 March 31 (in thousands of Canadian dollars) 2012 2011 Cash flows from operating activities Net earnings for the period 7,940 3,375 Items not affecting cash: Depreciation 579 602 Deferred income tax expense (recovery) 228 (144) Stock based compensation expense 385 466 Foreign exchange and other 534 90 9,666 4,389 Net change in non-cash working capital balances related to operations: Accounts receivable (5,714) (678) Inventories (1,461) (5,853) Other current assets (1,006) (79) Accounts payable and accrued liabilities (13,790) 12,208 Current taxes payable 416 101 (11,889) 10,088 Cash flows used in investing activities Net purchase of property and equipment (252) (492) (252) (492) Cash flows used in financing activities Decrease in bank operating loan - (6,140) Purchase of capital stock through normal course (70) (23) issuer bid Purchase of capital stock in trust for Share Unit - (219) Plans (70) (6,382) Change in cash and cash equivalents during the (12,211) 3,214 period Cash and cash equivalents at the beginning of the 15,830 - period Cash and cash equivalents at the end of the period 3,619 3,214 Cash paid during the period for: Interest 34 94 Income taxes 2,158 1,260 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, Alberta, Canada. The Company is an indirect subsidiary of Schlumberger Limited, a global energy services company. The address of the Company's registered office is 1800, 635 8(th) 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 39 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. Basis of preparation and accounting policies Basis of preparation These condensed interim consolidated financial statements for the three months ended March 31, 2012 have been prepared in accordance with IAS 34, Interim Financial Reporting, as issued by the International Accounting Standards Board ("IASB").  These condensed interim consolidated financial statements should be read in conjunction with the annual financial statements for the year ended December 31, 2011, which have been prepared in accordance with International Financial Reporting Standards ("IFRS"). Accounting policies The accounting policies adopted are consistent with those of the previous financial year. 3. Cash and cash equivalents March 31, 2012 December 31, 2011 Cash at bank and on hand 3,619 15,830 Cash is held at a major Canadian chartered bank. 4. Accounts receivable March 31, 2012 December 31, 2011 Current 53,205 46,556 Less than 60 days overdue 37,041 36,732 Greater than 60 days overdue 6,220 8,328 Total Trade receivables 96,466 91,616 Allowance for credit losses (1,737) (1,615) Net trade receivables 94,729 90,001 Other receivables 9,158 8,189 103,887 98,190 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: Three months ended Year ended March31, 2012 December 31, 2011 Opening balance as at January 1 4,590 5,000 Additions 478 2,495 Utilization through write-downs (558) (2,905) Closing balance 4,510 4,590 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 March 31 2012 % 2011 % Earnings before income taxes 10,648 4,591 Income taxes calculated at statutory rates 2,694 25.3 1,227 26.7 Non-deductible items 26 0.2 18 0.4 Share based compensation 5 0.1 12 0.3 Adjustments for filing returns and others (17) (0.1) (41) (0.9) 2,708 25.5 1,216 26.5 As at March 31, 2012, income taxes payable was $1.6 million (December 31, 2011 - $1.7 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 March 31, 2012 December 31, 2011 Assets Property and equipment 896 883 Stock based compensation 1,044 951 expense Other 156 609 2,096 2,443 Liabilities Goodwill and other (355) (474) Net Deferred taxasset 1,741 1,969 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 March31, 2012 December 31, 2011 Current Trade payables 13,269 10,919 Other payables 2,235 3,834 Accrued compensation expenses 1,478 4,683 Other accrued liabilities 62,892 74,177 79,874 93,613 8. Note payable March 31,2012 December 31, 2011 JEN Supply debt 290 290 In July of 2011, the Company renewed its $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 March 31, 2012, this ratio was nil (December 31, 2011 - nil). 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 March 31, 2012, this ratio was 51.3 times (December 31, 2011 - 34.5 times).  The credit facility contains certain other covenants, with which the Company is in compliance and has been for the comparative periods. As at March 31, 2012, the Company had borrowed nil and had available undrawn borrowing capacity of $60.0 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 note payable is unsecured and bears interest at the floating Canadian bank prime rate and is repayable in November 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: March 31, 2012 December 31, 2011 Shareholders' equity 173,466 165,099 Net working capital 137,816 116,850 Net working capital is defined as current assets less cash and cash equivalents, accounts payable and accrued liabilities, current taxes payable, note payable and other current liabilities. 10. Related party transactions Schlumberger indirectly 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 three months ended March 31 2012 2011 Cost of sales for the three months ended 3,761 2,285 Inventory 5,971 4,443 Accounts payable and accrued liabilities 1,935 1,081 Accounts receivable 203 - 11. Capital Stock a) The Company has authorized an unlimited number of common shares with no par value. As at March 31, 2012, the Company had 17.5 million common shares, 0.7 million stock options and 0.7 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 three month periods ended March 31 was as follows: (000's) 2012 2011 Outstanding - January 1 745 1,073 Exercised (11) (51) Forfeited (4) (32) Outstanding at March 31 730 990 Exercisable at March 31 730 826 Stock based compensation expense recorded for the three month period ended March 31, 2012 was $2,000 (2011 - $67,000) and is included in selling, general and administrative expenses on the consolidated statement of earnings and comprehensive income.  No options were granted during the three month period ended March 31, 2012. Options vest one third or one fourth per year from the date of grant. 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"), whereby RSUs, PSUs and DSUs 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. DSUs 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 three month period ended March 31, 2012 the fair value of the RSU, PSU and DSU units granted was $1,660,000 (2011 - $1,830,000) and $383,000 of compensation expense was recorded (2011 - $358,000). Share Unit Plan activity for the periods ended March 31, 2012, and December 31, 2011 was as follows: (000's) March 31, 2012 December 31, 2011 Number of Units Number of Units RSU PSU DSU Total RSU PSU DSU Total Outstanding at January 1 307 162 102 571 273 97 80 450 Granted 88 86 - 174 130 117 22 269 Performance adjustments - - - - - 4 - 4 Exercised (11) (3) - (14) (34) (12) - (46) Forfeited (1) - - (1) (62) (44) - (106) Outstanding at end of 383 245 102 730 307 162 102 571 period Exercisable at end of 184 81 102 367 93 33 102 228 period 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 three month period ended March 31, 2012, nil common shares were purchased by the trust (2011 - 25,000 common shares at an average cost of $8.75 per share).  As at March 31, 2012, the trust held 566,277 shares (2011 - 462,753). d) Normal Course Issuer Bid ("NCIB") On December 20, 2011, the Company announced the renewal of the NCIB effective January 3, 2012, to purchase up to 850,000 common shares through the facilities of NASDAQ, representing approximately 5% of its outstanding common shares.  During the three month period ended March 31, 2012, the Company purchased 8,625 shares at an average cost of $8.11 (2011: 3,102 shares purchased at an average cost of $7.56). Subsequent to the quarter end, the Company has cancelled its NCIB program.  At the time the program was cancelled, the Company had acquired 9,225 shares at an average cost of $8.59 per share. 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 RSUs, PSUs, DSUs 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 Months Ended March 31 2012 2011 Net earnings and comprehensive income 7,940 3,375 Weighted average number of common shares issued 17,443 17,488 (000's) Adjustments for: Stock options 291 255 Share Units 415 309 Weighted average number of ordinary shares for 18,149 18,052 dilutive Net earnings per share: Basic 0.46 0.19 Net earnings per share: Diluted 0.44 0.19 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 note payable. The fair values of these financial instruments approximate their carrying amounts due to their short-term maturity. 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 March 31, 2012, a change of one percent in interest rates would decrease or increase the Company's annual net income by nil. 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 March 31, 2012, the Company had contracted to purchase US$11.6 million at fixed exchange rates with terms not exceeding two months (December 31, 2011 - $18.3 million). The fair market values of the contracts were a loss of $0.3 million at March 31, 2012 (a gain of $0.2 million at December 31, 2011). The Company recorded on these contracts an unrealized loss of $0.3 million for the three months ended March 31, 2012, which has been recorded in foreign exchange loss and other in the condensed interim consolidated statements of earnings and comprehensive income.  As at March 31, 2012, 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. 14. Selling, general and administrative ("SG&A") Costs Selling, general and administrative costs for the three month period ended March 31 are as follows: Three months ended 2012 2011 $ % $ % Salaries and Benefits 10,960 61% 10,291 61% Selling Costs 1,910 11% 1,472 9% Facility and office costs 3,476 20% 3,712 22% Other 1,425 8% 1,505 8% SG&A costs 17,771 100% 16,980 100% 15. Segmented reporting The Company distributes oilfield products principally through its network of 39 branches located in western Canada primarily to oil and gas industry customers.  Accordingly, the Company has determined that it operates 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 outpaces 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. 17. Subsequent events Subsequent to March 31, 2012, the Company announced that the Board of Directors and the Special Committee of the Board of Directors have decided it is in the best interest of CE Franklin and all shareholders to formally commence a strategic review process.  Further to the announcement of a Strategic Review Process, the Company adopted a Shareholders' Rights Plan to ensure that, in the context of a bid for control of CE Franklin, the Board of Directors would have sufficient time to consider the bid and conduct the Strategic Review Process.  Additionally, the Shareholders' Rights Plan gives shareholders an equal opportunity to participate in such a bid; and gives them adequate time to properly assess the bid.  The Shareholders' Rights Plan is not intended to and will not prevent a sale of CE Franklin. CE Franklin Ltd. CONTACT: Investor Relations800-345-2858403-531-5604investor@cefranklin.com

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