CALGARY, July 29 /PRNewswire-FirstCall/ - CE FRANKLIN LTD.
(TSX.CFT, NASDAQ.CFK) reported a net loss of $0.1 million or $0.01 per share for the second quarter ended
June 30, 2010, compared to net income
of $0.6 million or $0.04 per share earned in the second quarter
ended June 30, 2009.
Financial Highlights
--------------------
(millions of Cdn. $
except per share data) Three Months Ended Six Months Ended
------------------- -------------------
June 30 June 30
2010 2009 2010 2009
------------------- -------------------
Unaudited Unaudited
Sales $ 99.9 $ 109.1 $ 221.8 $ 249.9
Gross Profit $ 15.6 $ 17.5 $ 35.2 $ 43.9
Gross Profit - % of sales 15.6% 16.0% 15.9% 17.6%
EBITDA(1) $ 0.7 $ 1.7 $ 4.9 $ 11.3
EBITDA(1) % of sales 0.7% 1.6% 2.2% 4.5%
Net income (loss) $ (0.1) $ 0.6 $ 2.1 $ 6.6
Per share
Basic $ (0.01) $ 0.04 $ 0.12 $ 0.37
Diluted $ (0.01) $ 0.03 $ 0.12 $ 0.36
Net working capital(2) $ 111.8 $ 137.0
Bank operating loan(2) $ - $ 25.3
(1) EBITDA represents net income 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 sales 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
amortization 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. Amortization expense is a
necessary component of the Company's expenses because the Company
uses property and equipment to generate sales. 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 income, 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 income 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 excluding cash, less
accounts payable and accrued liabilities, income taxes payable and
other current liabilities, excluding the bank operating loan. Net
working capital and bank operating loan are as at quarter end.
"Second quarter demand, which declines seasonally from the first
quarter due to spring breakup, showed year over year improvement in
both well completions and rig counts and sales strengthened as the
quarter progressed. This momentum should continue as the year
progresses," said Michael West,
President and CEO.
The Company recorded a net loss for the second quarter of 2010
of $0.1 million, down $0.7 million from the second quarter of 2009.
Second quarter sales are seasonally low as oilfield project
activity is impacted by the spring breakup. Sales were $99.9 million, a decrease of $9.2 million (8%) from the second quarter of 2009
as a 26% increase ($17.5 million) in
oilfield sales was more than offset by the absence of a
$32.4 million sale of oil sands pipe
in the second quarter of 2009. The rollover in tubular and other
steel product prices that commenced in the second quarter of 2009,
also contributed to the reduction in capital project sales and
margins in the second quarter of 2010. Increased oilfield supply
sales were driven by a 72% increase in industry well completions
over the prior year period and by the acquisition of a western
Canadian oilfield supply competitor in June
2009 (the "Oilfield Supply Acquisition"). Gross profit was
down $1.9 million (11%) due to the
reduction of sales combined with a 0.4% decline in average margins
from the prior year period. The highly competitive environment
continues to impact margins. Selling, general and administrative
expenses decreased by $1.1 million
(7%) to $14.7 million for the quarter
compared to the prior year period with the majority of the decrease
attributable to a $0.8 million
recovery of bad debts and reduced compensation and operating costs.
Income taxes decreased by $0.4
million in the second quarter of 2010 compared to the prior
year period due to lower pre-tax earnings. The weighted average
number of shares outstanding (basic) during the second quarter
decreased by 0.2 million shares (1%) from the prior year period
principally due to shares purchased for cancellation pursuant to
the Company's Normal Course Issuer Bid ("NCIB"). Net loss per share
(basic) was $0.01 in the second
quarter of 2010, compared to net income per share of $0.04 earned in the prior year period.
Net income for the first half of 2010 was $2.1 million, down $4.5
million from the first half of 2009. Sales were $221.8 million, a decrease of $28.1 million (11%) from the first half of 2009
as the absence of a $32.4 million
sale of oil sands pipe in the second quarter of 2009 and the impact
of a 3% reduction in year to date industry well completions more
than offset incremental sales contributed by the Oilfield Supply
Acquisition. The rollover of tubular and other steel product prices
contributed to the reduction in capital project sales and margins
compared to the prior year period. Gross profit was down
$8.7 million (20%) due to the
reduction of sales combined with a 1.7% decline in average margins
from the prior year period. The highly competitive environment
continues to impact margins. Selling, general and administrative
expenses decreased by $2.3 million
(7%) to $30.3 million for the first
half of the year due to a $0.8
million recovery of amounts previously written off to bad
debts and reduced compensation and operating costs. Income taxes
decreased by $2.1 million in the
first half of 2010 compared to the prior year period due to lower
pre-tax earnings. The weighted average number of shares outstanding
(basic) during the second quarter decreased by 0.3 million shares
(2%) from the prior year period principally due to shares purchased
for cancellation pursuant to the Company's NCIB. Net income per
share (basic) was $0.12 in the first
half of 2010, compared to $0.37
earned in the first half of 2009.
Business Outlook
Oil and gas industry activity in 2010 is expected to increase
modestly from the decade-low levels experienced in 2009. Natural
gas prices remain depressed as North American production capacity
and inventory levels currently dominate demand. Natural gas capital
expenditure activity is focused on the emerging shale gas plays in
north eastern British Columbia
where the Company has a strong market position. Conventional and
heavy oil economics are reasonable at current price levels leading
to moderate activity in eastern Alberta and south east Saskatchewan. The reduction in Alberta royalty rates announced during the
second quarter is expected to result in improved drilling economics
and industry activity. Industry well completions, which drive
demand for the Company's capital project related products, have
begun to accelerate in response to the significant increase in
average rig count activity compared to the prior year period. Oil
sands project announcements are gaining momentum with the recovery
in oil prices and access to capital markets. Approximately 50% to
60% of the Company's total sales are driven by our customer's
capital expenditure requirements. CE Franklin's revenues are
expected to increase modestly in the second half of 2010 due to
increased oil and gas industry activity and the expansion of the
Company's product lines.
The oilfield supply industry continues to work off excess
inventories, complicated by product deflation in certain product
lines that will support continued aggressive price competition and
lower realized gross profit margins. 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 will 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.
Additional Information
----------------------
Additional information relating to CE Franklin, including its
second quarter 2010 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 2010 second quarter results,
which is open to the public, will be held on Friday, July 30, 2010 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 1:00 p.m. Eastern Time on the same day by calling
1-416-849-0833 in Toronto or
dialing 1-800-642-1687 and entering the Passcode of 83905559 and
may be accessed until midnight Wednesday,
August 13, 2010.
The call will also be webcast live at:
http://www.newswire.ca/en/webcast/viewEvent.cgi?eventID=3126420 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 Mark Schweitzer, 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 49 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 July 29, 2010
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 discussion should be read
in conjunction with the Company's interim consolidated financial
statements for the three and six month period ended June 30, 2010, the interim consolidated financial
statements and MD&A for the three month period ended
March 31, 2010 and the MD&A and
the consolidated financial statements for the year ended
December 31, 2009. All amounts are
expressed in Canadian dollars and in accordance with Canadian
generally accepted accounting principles ("Canadian GAAP"), except
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 through
its 49 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 required 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 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. Smith International Inc. ("Smith"), a major
oilfield service company based in the
United States, owns approximately 55% 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-site needs of large and
emerging customers in the energy sector. Organic growth is expected
to 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 down hole pump repair, oilfield engine maintenance, well
optimization and on site project management. This is expected to
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.
Business Outlook
Oil and gas industry activity in 2010 is expected to increase
modestly from the decade-low levels experienced in 2009. Natural
gas prices remain depressed as North American production capacity
and inventory levels currently dominate demand. Natural gas capital
expenditure activity is focused on the emerging shale gas plays in
north eastern British Columbia
where the Company has a strong market position. Conventional and
heavy oil economics are reasonable at current price levels leading
to moderate activity in eastern Alberta and south east Saskatchewan. The reduction in Alberta royalty rates announced during the
second quarter is expected to result in improved drilling economics
and industry activity. Industry well completions, which drive
demand for the Company's capital project related products, have
begun to accelerate in response to the significant increase in
average rig count activity compared to the prior year period. Oil
sands project announcements are gaining momentum with the recovery
in oil prices and access to capital markets. Approximately 50% to
60% of the Company's total sales are driven by our customer's
capital expenditure requirements. CE Franklin's revenues are
expected to increase modestly in the second half of 2010 due to
increased oil and gas industry activity and the expansion of the
Company's product lines.
The oilfield supply industry continues to work off excess
inventories, complicated by product deflation in certain product
lines that will support continued aggressive price competition and
lower realized gross profit margins. 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 will 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.
Second Quarter Operating Results
The following table summarizes CE Franklin's results of
operations:
(In millions of Cdn. Dollars except per share data and may not add due to
rounding to millions)
Three Months Ended June 30
------------------- -------------------
2010 2009
------------------- -------------------
Sales 99.9 100.0% 109.1 100.0%
Cost of Sales (84.3) (84.4)% (91.6) (84.0)%
------------------- -------------------
Gross profit 15.6 15.6% 17.5 16.0%
Selling, general and admin-
istrative expenses (14.7) (14.7)% (15.8) (14.5)%
Foreign exchange and other (0.2) 0.2% 0.0 0.0%
------------------- -------------------
EBITDA(1) 0.7 1.1% 1.7 1.6%
Amortization (0.6) (0.6)% (0.6) (0.5)%
Interest (0.2) (0.2)% (0.1) (0.1)%
------------------- -------------------
------------------- -------------------
Income (loss) before taxes (0.1) 0.3% 1.0 0.9%
Income tax expense 0.0 0.0% (0.4) (0.4)%
------------------- -------------------
Net income (loss) (0.1) 0.3% 0.6 0.5%
------------------- -------------------
------------------- -------------------
Net income per share
Basic $ (0.01) $ 0.04
Diluted $ (0.01) $ 0.03
Weighted average number of
shares outstanding (000's)
Basic 17,514 17,707
Diluted 17,785 18,151
Six Months Ended June 30
------------------- -------------------
2010 2009
------------------- -------------------
Sales 221.8 100.0% 249.9 100.0%
Cost of Sales (186.6) (84.1)% (206.0) (82.4)%
------------------- -------------------
Gross profit 35.2 15.9% 43.9 17.6%
Selling, general and admin-
istrative expenses (30.3) (13.7)% (32.6) (13.0)%
Foreign exchange and other (0.1) 0.1% 0.0 0.0%
------------------- -------------------
EBITDA(1) 4.9 2.2% 11.3 4.5%
Amortization (1.2) (0.5)% (1.1) (0.4)%
Interest (0.4) (0.2)% (0.4) (0.2)%
------------------- -------------------
------------------- -------------------
Income (loss) before taxes 3.2 1.5% 9.8 3.9%
Income tax expense (1.1) (0.5)% (3.2) (1.3)%
------------------- -------------------
Net income (loss) 2.1 1.0% 6.6 2.6%
------------------- -------------------
------------------- -------------------
Net income per share
Basic $ 0.12 $ 0.37
Diluted $ 0.12 $ 0.36
Weighted average number of
shares outstanding (000's)
Basic 17,546 17,871
Diluted 17,818 18,189
(1) EBITDA represents net income 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 sales 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
amortization expenses. Interest expense is a necessary component of
the Company's expenses because the Company borrows money to finance
its working capital and capital income taxes. Amortization expense is
a necessary component of the Company's expenses because the Company
is required to pay cash equipment to generate sales. 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 incomes, 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 income 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.
Second Quarter Results
The Company recorded a net loss for the second quarter of 2010
of $0.1 million, down $0.7 million from the second quarter of 2009.
Second quarter sales are seasonally low as oilfield project
activity is impacted by the spring breakup. Sales were $99.9 million, a decrease of $9.2 million (8%) from the second quarter of 2009
as a 26% increase ($17.5 million) in
oilfield sales was more than offset by the absence of a
$32.4 million sale of oil sands pipe
in the second quarter of 2009. The rollover in tubular and other
steel product prices that commenced in the second quarter of 2009,
also contributed to the reduction in capital project sales and
margins in the second quarter of 2010. Increased oilfield supply
sales were driven by a 72% increase in industry well completions
over the prior year period and by the acquisition of a western
Canadian oilfield supply competitor in June
2009 (the "Oilfield Supply Acquisition"). Gross profit was
down $1.9 million (11%) due to the
reduction of sales combined with a 0.4% decline in average margins
from the prior year period. The highly competitive environment
continues to impact margins. Selling, general and administrative
expenses decreased by $1.1 million
(7%) to $14.7 million for the quarter
compared to the prior year period with the majority of the decrease
attributable to a $0.8 million
recovery of bad debts and reduced compensation and operating costs.
Income taxes decreased by $0.4
million in the second quarter of 2010 compared to the prior
year period due to lower pre-tax earnings. The weighted average
number of shares outstanding (basic) during the second quarter
decreased by 0.2 million shares (1%) from the prior year period
principally due to shares purchased for cancellation pursuant to
the Company's Normal Course Issuer Bid ("NCIB"). Net loss per share
(basic) was $0.01 in the second
quarter of 2010, compared to net income per share of $0.04 earned in the prior year period.
Year to date Results
Net income for the first half of 2010 was $2.1 million, down $4.5
million from the first half of 2009. Sales were $221.8 million, a decrease of $28.1 million (11%) from the first half of 2009
as the absence of a $32.4 million
sale of oil sands pipe in the second quarter of 2009 and the impact
of a 3% reduction in year to date industry well completions more
than offset incremental sales contributed by the Oilfield Supply
Acquisition. The rollover of tubular and other steel product prices
contributed to the reduction in capital project sales and margins
compared to the prior year period. Gross profit was down
$8.7 million (20%) due to the
reduction of sales combined with a 1.7% decline in average margins
from the prior year period. The highly competitive environment
continues to impact margins. Selling, general and administrative
expenses decreased by $2.3 million
(7%) to $30.3 million for the first
half of the year due to a $0.8
million recovery of amounts previously written off to bad
debts and reduced compensation and operating costs. Income taxes
decreased by $2.1 million in the
first half of 2010 compared to the prior year period due to lower
pre-tax earnings. The weighted average number of shares outstanding
(basic) during the second quarter decreased by 0.3 million shares
(2%) from the prior year period principally due to shares purchased
for cancellation pursuant to the Company's NCIB. Net income per
share (basic) was $0.12 in the first
half of 2010, compared to $0.37
earned in the first half of 2009.
Sales
Sales for the second quarter ended June
30, 2010, were $99.9 million,
down 8% from the quarter ended June 30,
2009, as detailed above in the "Second Quarter results"
discussion.
(in millions of Cdn. $)
Three months ended Six months ended
June 30 June 30
------------------------ ------------------------
2010 2009 2010 2009
------------------------ ------------------------
End use sales demand $ % $ % $ % $ %
Capital projects 54.3 54 63.7 58 115.8 52 151.2 60
Maintenance, repair and
operating supplies
(MRO) 45.6 46 45.4 42 106.0 48 98.7 40
------------------------ ------------------------
Total Sales 99.9 100 109.1 100 221.8 100 249.9 100
Note: Capital project end use sales are defined by the Company as
consisting of the tubular and 80% of pipe, flanges and fittings; and
valves and accessories product sales respectively; MRO Sales 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 sales respectively.
The relative level of oil and gas commodity prices are a key
driver of industry capital project activity as product 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 six month periods ended June 30, 2010 and 2009 are provided in the table
below.
Q2 Average % YTD Average %
------------------------ ------------------------
2010 2009 change 2010 2009 change
-------- ------- ------- ------- -------- -------
Gas - Cdn. $/gj
(AECO spot) $ 3.91 $ 3.46 13% $ 4.42 $ 4.19 5%
Oil - Cdn. $/bbl
(synthetic crude) $ 78.07 $ 67.42 16% $ 80.28 $ 61.87 30%
Average rig count 165 95 74% 300 207 45%
Well completions:
Oil 1,077 422 155% 2,432 1,376 77%
Gas 1,120 852 31% 2,611 3,845 (32)%
-------- ------- ------- ------- -------- -------
Total well completions 2,197 1,274 72% 5,043 5,221 (3)%
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
Sales of capital project related products were $54.3 million in the second quarter of 2010, down
15% ($9.4 million) from the second
quarter of 2009 due to the absence of a $32.4 million oil sands pipe sale in the second
quarter of 2009, partially offset by increased oilfield capital
project sales due to increased industry well completions. Total
well completions increased by 72% in the second quarter of 2010 and
the average working rig count increased by 74% compared to the
prior year period. Gas wells comprised 51% of the total wells
completed in western Canada in the
second quarter of 2010 compared to 67% in the second quarter of
2009. Spot gas prices ended the second quarter at $3.72 per GJ (AECO), a decrease of 5% from second
quarter average prices. Oil prices ended the second quarter at
$78.15 per bbl (Synthetic Crude),
consistent with second quarter average prices. Depressed gas prices
are expected to continue to negatively impact gas drilling activity
over the remainder of 2010, which in turn is expected to constrain
demand for the Company's products.
MRO product sales are related to overall oil and gas industry
production levels and tend to be more stable than capital project
sales. MRO product sales for the quarter ended June 30, 2010 were $45.6
million consistent with $45.4
million in the quarter ended June 30,
2009 and comprised 46% of the Company's total sales.
The Company's strategy is to grow profitability by focusing on
its core western Canadian oilfield product distribution business,
complemented by an increase in the product life cycle services
provided to its customers and the focus on the emerging oil sands
capital project and MRO sales opportunities. Sales results of these
initiatives to date are provided below:
Q2 2010 Q2 2009 YTD 2010 YTD 2009
------------------------ ------------------------
Sales ($millions) $ % $ % $ % $ %
Oilfield 85.6 86 68.1 63 188.4 85 194.4 78
Oil sands 10.9 11 38.6 35 26.1 12 51.0 20
Production services 3.4 3 2.4 2 7.3 3 4.5 2
------------------------ ------------------------
Total sales 99.9 100 109.1 100 221.8 100 249.9 100
Sales of oilfield products to conventional western Canada oil and gas end use applications were
$85.6 million for the second quarter
of 2010, up 26% from the second quarter of 2009. This increase was
driven by the 72% increase in well completions compared to the
prior year period and by sales contributed by the Oilfield Supply
Acquisition which comprised approximately 9% of second quarter 2010
oilfield sales.
Sales to oil sands end use applications were $10.9 million in the second quarter, a decrease
of $27.7 million (72%) as the second
quarter of 2009 included a $32.4
million oil sands pipe sale that did not repeat in the
second quarter of 2010. The Company continues to position its sales
focus, Distribution Centre and Fort
McMurray branch to penetrate this emerging market for
capital project and MRO products.
Production service sales were $3.4
million in the second quarter of 2010, an increase of
$1.0 million compared to sales in the
second quarter of 2009, reflecting improved oil production
economics resulting in increased customer maintenance activities
that were deferred in 2009.
Gross Profit
Q2 2010 Q2 2009 YTD 2010 YTD 2009
------------------------ ------------------------
Gross profit (millions) $ 15.6 $ 17.5 $ 35.2 $ 43.9
Gross profit margin as a
% of sales 15.6% 16.0% 15.9% 17.6%
Gross profit composition
by product sales category:
Tubulars 2% 2% 2% 7%
Pipe, flanges and fittings 30% 37% 29% 36%
Valves and accessories 19% 20% 19% 18%
Pumps, production equipment
and services 13% 11% 13% 11%
General 36% 30% 37% 28%
------------------------ ------------------------
Total gross profit 100% 100% 100% 100%
Gross profit was $15.6 million in
the second quarter of 2010, down $1.9
million (11%) from the second quarter of 2009 due to the 8%
decline in sales combined with lower gross profit margins. Gross
profit margins declined from 16.0% in the second quarter of 2009 to
15.6% in the second quarter of 2010. Reduced pipe, flange and
fittings gross profit composition in the second quarter of 2010
reflect the absence of a large oil sands pipe sale in the prior
year period. The increase in general products gross profit
composition reflects the increase in MRO end use sales mix to 46%
of total sales in the quarter, compared to 42% in the prior year
period. Lower year to date tubular gross profit composition
reflects the rollover of tubular prices and margins that commenced
in the second quarter of 2009.
Selling, General and Administrative ("SG&A") Costs
Q2 2010 Q2 2009 YTD 2010 YTD 2009
------------------------ ------------------------
Sales ($millions) $ % $ % $ % $ %
People costs 8.7 59 8.7 55 17.6 58 18.8 57
Facility and office
costs 3.4 7 3.4 11 6.9 9 6.7 11
Selling costs 1.0 23 1.8 22 2.7 23 3.5 21
Other 1.6 11 1.9 12 3.1 10 3.6 11
------------------------ ------------------------
SG&A costs 14.7 100 15.8 100 30.3 100 32.6 100
------------------------ ------------------------
SG&A costs as % of
sales 15% 14% 14% 13%
SG&A costs decreased $1.1
million (7%) in the second quarter of 2010 from the prior
year period and represented 15% of sales compared to 14% in the
prior year period. The majority of the $1.1
million decrease in expenses was attributable to an
$0.8 million reduction in selling
costs resulting from the recovery of accounts receivable previously
written off to bad debts in the third quarter of 2009 and Oilfield
Supply Acquisition integration costs of $0.3
million in the previous year period. The expansion of the
Company's branch network from 44 to 49 branches resulting from the
Oilfield Supply Acquisition increased SG&A costs by
approximately $0.5 million in the
second quarter compared to the prior year period, offset by reduced
compensation and operating costs.
Amortization Expense
Amortization expense of $0.6
million in the second quarter of 2010 was comparable to the
second quarter of 2009.
Interest Expense
Interest expense of $0.2 million
in the second quarter of 2010 was comparable to the second quarter
of 2009.
Foreign Exchange (Gain) Loss
Foreign exchange losses on United
States dollar denominated product purchases and net working
capital liabilities were $0.2 million
in the second quarter of 2010 and were nominal in the second
quarter of 2009.
Income Tax Expense
The Company's effective tax rate for the second quarter of 2010
was 2% compared to 37.5% in the second quarter of 2009 due to
minimal profitability compared to the prior year period.
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 Canadian GAAP. This information is
derived from the Company's unaudited quarterly financial
statements.
Unaudited Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2
2008 2008 2009 2009 2009 2009 2010 2010
------ ------ ------ ------ ------ ------ ------ ------
Sales $149.3 $161.2 $140.7 $109.1 $ 94.1 $ 93.0 $121.9 $ 99.9
Gross profit 27.8 33.9 26.4 17.5 17.4 15.3 19.7 15.6
Gross profit % 18.6% 21.0% 18.8% 16.0% 18.5% 16.5% 16.1% 15.6%
EBITDA 9.1 14.3 9.6 1.7 0.5 0.6 4.1 0.7
EBITDA as a %
of sales 6.1% 8.9% 6.8% 1.6% 0.5% 0.6% 3.4% 0.7%
Net income (loss) 5.7 8.8 6.0 0.6 0.2 (0.5) 2.2 (0.1)
Net income (loss)
as a % of sales 3.8% 5.5% 4.3% 0.5% 0.2% (0.5%) 1.8% (0.1%)
Net income (loss)
per share
Basic $ 0.31 $ 0.48 $ 0.33 $ 0.04 $ 0.01 ($0.03)$ 0.13 ($0.01)
Diluted $ 0.31 $ 0.47 $ 0.33 $ 0.03 $ 0.01 ($0.03)$ 0.12 ($0.01)
Net working
capital(1) 123.1 142.8 153.2 137.0 131.1 136.6 113.9 111.8
Bank operating
loan(1) 20.9 34.9 40.2 25.3 21.3 26.5 1.1 0.0
Total well
completions 4,392 6,971 3,947 1,274 1,468 1,576 2,846 2,197
(1) Net working capital and 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 sales activity for the
Company. 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 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 excluding cash, less accounts payable
and accrued liabilities, income taxes payable and other current
liabilities, excluding the bank operating loan) and bank operating
loan 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 net changes in non-cash working
capital balances. Cash flow from operating activities and the
Company's revolving term credit facility are used to finance the
Company's net working capital, capital expenditures and
acquisitions.
As at June 30, 2010, there were no
borrowings under the Company's bank operating loan, a decrease of
$26.5 million from December 31, 2009. The Company had cash of
$0.9 million at June 30, 2010 (2009 - nil). Borrowing levels have
decreased since December 31, 2009 due
to the Company generating $4.2
million in cash flow from operating activities, before net
changes in non-cash working capital balances and a $25.1 million reduction in net working capital.
This was offset by $0.5 million in
capital and other expenditures, $0.2
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.
As at June 30, 2009, borrowings
under the Company's bank operating loan were $25.3 million, a decrease of $9.6 million from December
31, 2008. Borrowing levels decreased due to the Company
generating $8.8 million in cash flow
from operating activities, before net changes in non-cash working
capital balances and a $13.1 million
reduction in net working capital. This was offset by $1.6 million in capital and other expenditures,
$8.1 million related to the Oilfield
Supply Acquisition and $2.6 million
for the purchase of shares to resource stock compensation
obligations and the repurchase of shares under the Company's NCIB.
The remaining $3.2 million
acquisition cost payable was paid in the third quarter of 2009.
Net working capital was $111.8
million at June 30, 2010, a
decrease of $24.8 million from
December 31, 2009. Accounts
receivable decreased by $5.7 million
(9%) to $61.7 million at June 30, 2010 from December 31, 2009 due mainly to a 13% improvement
in Days Sales Outstanding ("DSO"). DSO in the second quarter of
2010 was 52 days compared to 60 days in the fourth quarter of 2009
and 44 days in the second quarter of 2009. The DSO performance in
the second quarter of 2009 was positively impacted by the Oilfield
Supply Acquisition as no receivables were acquired with the
business. DSO is calculated using average sales per day for the
quarter compared to the period end accounts receivable balance.
Inventory decreased by $7.3 million
(7%) at June 30, 2010 from
December 31, 2009. Inventory turns
for the second quarter of 2010 were improved to 3.5 turns compared
to 3.0 turns in the fourth quarter of 2009 and 3.1 turns in the
second quarter of 2009. 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 $8.8 million
(23%) to $47.3 million at
June 30, 2010 from December 31, 2009, responsive to increased
purchasing and sales levels.
Capital expenditures in the second quarter of 2010 were
$0.3 million, a reduction of
$0.7 million compared to the prior
year period. The majority of the capital expenditures in both
periods were directed towards branch facility expansions.
On July 8, 2010, a new
$60.0 million revolving term bank
credit facility was entered into. The credit facility matures in
July 2013 and provides lower
borrowing costs and improved covenant flexibility. Previously the
Company had a $60 million, 364 day
bank operating facility. The maximum amount available to borrow
under the Credit Facility is subject to a borrowing base formula
applied to accounts receivable and inventories. Under the terms of
the Credit Facility, the Company must maintain the ratio of its
debt to debt-plus-equity at less than 40% (Nil at June 30, 2010) and coverage of net operating free
cash flow as defined in the Credit Facility agreement over interest
expense for the trailing 12 month period of greater than 1.25 times
(5.4 times at June 30, 2010). The
Credit Facility contains certain other covenants, which the Company
is in compliance with.
Contractual Obligations
There have been no material changes in off-balance sheet
contractual commitments since December 31,
2009.
Capital Stock
As at June 30, 2010 and 2009, the
following shares and securities convertible into shares were
outstanding:
(millions) June 30, June 30,
2010 2009
Shares Shares
----------------------
Shares outstanding 17.4 17.7
Stock options 1.2 1.2
Share unit plan obligations 0.6 0.5
----------------------
Shares outstanding and issuable 19.2 19.4
The weighted average number of shares outstanding during the
second quarter of 2010 was 17.5 million, a decrease of 0.2 million
shares from the prior year's second quarter due principally to the
purchases of common shares under its NCIB and to resource share
unit plan obligations. The diluted weighted average number of
shares outstanding was 17.8 million, a decrease of 0.3 million
shares from the prior year's second 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 six month periods ended
June 30, 2010, 92,500 and 129,300
common shares were acquired by the trust at an average cost per
share of $6.85 and $6.83 respectively. (Three and six months ended
June 30, 2009 - 25,000 and 75,000 at
an average cost per share of $5.68
and $5.23 respectively). As at
June 30, 2009, the trust held 448,581
shares (June 30, 2009 - 366,087
shares).
On December 23, 2009, the Company
announced the renewal of the NCIB, to purchase up to 880,000 common
shares representing approximately 5% of its outstanding common
shares. Shares may be purchased up to December 31, 2010. As at June 30, 2010, the Company had purchased 49,278
shares at an average cost of $6.61
per share (June 30, 2009 - 454,848
shares at an average cost of $4.98
per share).
The Company settles exercises of stock options through payment
of cash in order to manage share dilution while resourcing its long
term incentive plan on a tax efficient basis. As a result, the
Company's stock option obligations (subject to vesting) are
classified as a current liability (June 30,
2010 - $1.6 million) based on
the positive difference between the Company's closing stock price
at period end and the underlying option exercise price. The offset
to the generation of the current liability is contributed surplus,
up to the cumulative expensed Black Scholes valuation, and
compensation expense for the excess of the intrinsic value over the
cumulative expensed Black Scholes value. The liability is marked to
market at each period end, with any adjustment allocated to the
relevant account as detailed above. On March
4, 2010, the federal government introduced its 2010 budget
which contained provisions which if enacted, could result in future
stock option settlement payments no longer being deductible by the
Company for tax purposes. This would result in the accounting write
off of approximately $0.4 million of
related future tax assets. No accounting recognition will be made
until such time and to the extent that proposed changes to the
deductibility of stock option payments for tax purposes has been
substantively enacted.
Critical Accounting Estimates
There have been no material changes to critical accounting
estimates since December 31, 2009.
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
There have been no changes to accounting policies since
December 31, 2009.
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.
Project Structure and Governance
A Steering Committee has been established to provide leadership
and guidance to the project team, assist in developing accounting
policy recommendations and ensure there is adequate resources and
training available. Management provides status updates to the Audit
Committee on a quarterly basis.
Resources and Training
CE Franklin's project team has been assembled and has developed
a detailed workplan that includes training, detailed Canadian GAAP
to IFRS analysis, technical research, policy recommendations and
implementation. The project team completed initial training and
ongoing training will continue through the project as required. The
Company's Leadership Team and the Audit Committee have also
participated in IFRS awareness sessions.
IFRS Progress
The project team is advanced in its assessment of the
differences between Canadian GAAP and IFRS. A risk based approach
has been used to identify significant differences based on possible
financial impact and complexity. No accounting policy differences
have been identified to date that would give rise to significant
differences between Canadian GAAP and IFRS. Similarly, there have
been no significant information system change requirements
identified in order to adopt IFRS. The project team is currently
assessing changes to financial statement presentation, disclosure
and related internal controls over financial reporting that will be
required to adopt IRFS. There are a number of IFRS standards in the
process of being amended by the International Accounting Standards
Board and are expected to continue until the transition date of
January 1, 2011. The Company is
actively monitoring proposed changes.
At this stage in the project, CE Franklin cannot reasonably
determine the full impact that adopting IFRS would have on its
financial position and future results.
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 Canadian GAAP
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 six months ended June 30,
2010 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 year ended
December 31, 2009 have occurred that
would materially change the 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 2010 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
second quarter 2010 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.
Interim Consolidated Balance Sheets - Unaudited
-------------------------------------------------------------------------
June 30 December 31
(in thousands of Canadian dollars) 2010 2009
-------------------------------------------------------------------------
Assets
Current assets
Cash 962 -
Accounts receivable 61,706 67,443
Inventories 95,321 102,669
Other 2,093 4,960
-------------------------------------------------------------------------
160,082 175,072
Property and equipment 9,807 10,517
Goodwill 20,570 20,570
Future income taxes (note 5) 1,428 1,457
Other 270 339
-------------------------------------------------------------------------
192,157 207,955
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Liabilities
Current liabilities
Bank operating loan (note 6) - 26,549
Accounts payable and accrued liabilities 47,319 38,489
-------------------------------------------------------------------------
47,319 65,038
Long term debt 290 290
-------------------------------------------------------------------------
47,609 65,328
-------------------------------------------------------------------------
Shareholders' Equity
Capital stock 22,637 23,284
Contributed surplus 17,908 17,184
Retained earnings 104,003 102,159
-------------------------------------------------------------------------
144,548 142,627
-------------------------------------------------------------------------
192,157 207,955
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to these interim consolidated financial
statements.
CE Franklin Ltd.
Interim Consolidated Statements of Operations - Unaudited
-------------------------------------------------------------------------
Three Months Ended Six Months Ended
(in thousands of Canadian --------------------- ---------------------
dollars except shares June 30 June 30 June 30 June 30
and per share amounts) 2010 2009 2010 2009
-------------------------------------------------------------------------
Sales 99,905 109,125 221,784 249,865
Cost of sales 84,335 91,630 186,554 206,002
-------------------------------------------------------------------------
Gross profit 15,570 17,495 35,230 43,863
Other expenses
Selling, general and
administrative expenses 14,700 15,782 30,304 32,642
Amortization 618 586 1,235 1,141
Interest expense 191 154 431 347
Foreign exchange (gain)/
loss 161 (30) 85 (29)
-------------------------------------------------------------------------
15,670 16,492 32,055 34,101
-------------------------------------------------------------------------
Income (loss) before
income taxes (100) 1,003 3,175 9,762
Income tax expense
(recovery) (note 5)
Current 61 529 1,076 3064
Future (59) (153) (6) 69
-------------------------------------------------------------------------
2 376 1,070 3,133
-------------------------------------------------------------------------
Net income (loss) and comp-
rehensive income (loss) (102) 627 2,105 6,629
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Net income (loss) per share
(note 4)
Basic (0.01) 0.04 0.12 0.37
Diluted (0.01) 0.03 0.12 0.36
-------------------------------------------------------------------------
Weighted average number of
shares outstanding (000's)
Basic 17,514 17,707 17,546 17,871
Diluted (note 4(e)) 17,785 18,151 17,818 18,189
-------------------------------------------------------------------------
See accompanying notes to these interim consolidated financial
statements.
CE Franklin Ltd.
Interim Consolidated Statements of Cash Flow - Unaudited
-------------------------------------------------------------------------
Three Months Ended Six Months Ended
--------------------- ---------------------
(in thousands of June 30 June 30 June 30 June 30
Canadian dollars) 2010 2009 2010 2009
-------------------------------------------------------------------------
Cash flows from operating
activities
Net income (loss) for the
period (102) 627 2,105 6,629
Items not affecting cash -
Amortization 618 586 1,235 1,141
Future income tax
expense (recovery) (59) (153) (6) 69
Stock based compensation
expense 418 676 792 983
Other 189 (75) 113 (74)
-------------------------------------------------------------------------
1,064 1,661 4,239 8,748
Net change in non-cash
working capital balances
related to operations -
Accounts receivable 13,144 33,529 5,737 43,395
Inventories (5,442) 6,669 7,348 11,559
Other current assets (731) (255) 1,966 7,747
Accounts payable and
accrued liabilities (4,682) (15,983) 9,099 (45,368)
Income taxes payable /
receivable (62) (565) 948 (4,190)
-------------------------------------------------------------------------
3,291 25,056 29,337 21,891
-------------------------------------------------------------------------
Cash flows (used in)/
from financing activities
Decrease in bank
operating loan (1,078) (14,887) (26,549) (9,680)
Issuance of capital
stock- Stock options
exercised 19 48 19 166
Settlement of share unit
plan obligations (178) - (178) -
Purchase of capital stock
through normal course
issuer bid (131) (881) (326) (2,266)
Purchase of capital stock
in trust for Share Unit
Plans (634) (141) (883) (394)
-------------------------------------------------------------------------
(2,002) (15,861) (27,917) (12,174)
-------------------------------------------------------------------------
Cash flows used in investing
activities
Purchase of property and
equipment (327) (1,070) (458) (1,592)
Business acquisition
(note 2) - (8,125) - (8,125)
-------------------------------------------------------------------------
(327) (9,195) (458) (9,717)
-------------------------------------------------------------------------
Change in cash and cash
equivalents during the
period 962 - 962 -
Cash and cash equivalents
at the beginning of the
period - - - -
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Cash and cash equivalents
at the end of the period 962 - 962 -
-------------------------------------------------------------------------
Cash paid during the period
for:
Interest 191 154 431 347
Income taxes 240 1,094 240 7,254
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to these interim consolidated financial
statements.
CE Franklin Ltd.
Interim Consolidated Statements of Changes in Shareholders' Equity -
Unaudited
-------------------------------------------------------------------------
(in thousands
of Canadian Capital Stock
dollars and ---------------------- Share
number of Number of Contributed Retained holders'
shares) Shares $ Surplus Earnings Equity
-------------------------------------------------------------------------
Balance -
December 31,
2008 18,094 22,498 18,835 97,990 139,323
Normal Course
Issuer Bid (note
4 (d)) (455) (595) - (1,671) (2,266)
Stock based comp-
ensation (notes 4
(a) and (b)) - - 983 - 983
Stock options
excercised (note
4 (a)) 55 248 (82) - 166
Purchase of shares
in trust for Share
Unit Plans (note 4
(c)) (75) (394) - - (394)
Share Units ex-
ercised (note 4
(b)) 53 980 (980) - -
Net income - - - 6,629 6,629
-------------------------------------------------------------------------
Balance -
June 30, 2009 17,672 22,737 18,756 102,948 144,441
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Balance -
December 31,
2009 17,581 23,284 17,184 102,159 142,627
Normal Course
Issuer Bid (note
4 (d)) (49) (65) - (261) (326)
Stock based comp-
ensation (notes 4
(a) and (b)) - - 1,183 - 1,183
Purchase of shares
in trust for Share
Unit Plans (note 4
(c)) (129) (883) - - (883)
Share Units ex-
ercised (note 4
(b)) 38 281 (281) - -
Options exercised
from treasury
(note 4 (a)) 3 20 - 20
Deferred stock unit
exercise (note 4
(b)) - - (178) (178)
Net income - - - 2,105 2,105
-------------------------------------------------------------------------
Balance -
June 30, 2010 17,444 22,637 17,908 104,003 144,548
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to these interim consolidated financial
statements.
CE Franklin Ltd.
Notes to Interim Consolidated Financial Statements -
Unaudited
(tabular amounts in thousands of Canadian dollars, except share
and per share amounts)
Note 1 - Accounting Policies
These interim consolidated financial statements have been
prepared in accordance with accounting principles generally
accepted in Canada applied on a
consistent basis with CE Franklin Ltd's (the "Company") annual
consolidated financial statements for the year ended December 31, 2009. These interim consolidated
financial statements should be read in conjunction with the annual
consolidated financial statements and the notes thereto for the
year ended December 31, 2009, but do
not include all disclosures required by Generally Accepted
Accounting Principles (GAAP) for annual financial statements.
Recent Canadian GAAP pronouncements include CICA section 1582-
Business Combinations, CICA section 1601 - Consolidated Financial
Statements and CICA section 1602 - Non- Controlling interests. The
overall objective of the standards issued is to update the
standards pertaining to business combinations and allow convergence
with International Financial Reporting Standards by January 1, 2011. The adoption of these standards
is expected to have no impact on the Company.
These unaudited interim consolidated financial statements
reflect all adjustments which are, in the opinion of management,
necessary for a fair presentation of the results for the interim
periods presented. All such adjustments are of a normal recurring
nature.
The Company's sales typically peak in the first quarter when oil
and gas drilling activity is at its highest levels. Sales then
seasonally decline through the second and third quarters, rising
again in the fourth quarter when preparation for the next drilling
season commences. Similarly, net working capital levels are
typically at seasonally high levels at the end of the first
quarter, declining in the second and third quarters, and then
rising again in the fourth quarter.
Note 2 - Business Combinations
On June 1st 2009, the Company
acquired the net assets of a western Canadian oilfield equipment
distributor, for total consideration of $11.3 million, after $0.7
million post closing adjustments related principally to
inventory reductions.
Using the purchase method of accounting for acquisitions, the
Company consolidated the assets from the acquisition and allocated
the consideration paid as follows:
Cash consideration paid and payable 11,286
--------
--------
Net assets acquired:
Inventory 10,462
Property, equipment and other 824
--------
11,286
--------
--------
Note 3 - Inventory
Inventories consisting primarily of goods purchased for resale
are valued at the lower of average cost or net realizable value.
Inventory net realizable value expense was recognized in the three
and six months period ending June 30,
2010 of $305,000 and
$610,000 respectively (2009 - nil and
$945,000 respectively). As at
June 30, 2010 and December 31, 2009, the Company had recorded
inventory valuation reserves of $5.6
million and $6.3 million
respectively.
During the three and six months ended June 30, 2010, inventory valuation reserves of
$0.2 million and $0.4 million respectively were reversed.
Note 4 - Share Data
At June 30, 2010, the Company had
17.4 million common shares, 1.2 million stock options and 0.6
million share units outstanding.
a) Stock options
Option activity for each of the six month periods ended
June 30 was as follows:
000's 2010 2009
-------------------------------------------------------------------------
Outstanding at January 1 1,195 1,294
Granted - -
Exercised (15) (55)
Forfeited (7) (33)
-------------------------------------------------------------------------
Outstanding at June 30 1,173 1,206
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Exercisable at June 30 870 757
There were no options granted during the three and six month
periods ended June 30, 2010 and
June 30, 2009.
During the quarter ended September 30,
2009, the Company modified its stock option plan to include
a cash settlement mechanism. As a result, the Company's stock
option obligations are now classified as current obligations
(subject to vesting) based on the positive difference between the
Company's closing stock price at period end and the underlying
option exercise price. As at June 30,
2010, the Company's accrued stock option liability was
$1,642,000. As the stock option
obligations are now recorded as a liability on the Company's
balance sheet, stock options are no longer included in the
calculation of the diluted number of shares outstanding (note
4(e)).
Stock option compensation expense recorded in the three and six
month period ended June 30, 2010 was
$117,000 (2009 - $177,000) and $171,000 (2009 - $355,000) respectively. Stock option compensation
expense is included in selling, general and administrative expenses
on the Consolidated Statement of Operations.
b) 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 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. RSU's and PSU's are granted to the Company's officers and
employees and vest one third per year over the three year period
from the date of grant. DSU's are granted to the independent
members of the Company's Board of Directors ("Board"), vest on the
date of grant, and can only be redeemed when the Director resigns
from the Board. 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. 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 settled. Share Unit Plan activity for the six month
periods ended June 30 was as
follows:
OOO's 2010 Total 2009 Total
-------------------------------------------------------------------------
RSU PSU DSU RSU PSU DSU
Outstanding at January 1 223 53 98 374 161 - 70 231
Granted 139 132 29 300 176 161 28 365
Exercised (33) (7) (26) (66) (53) - - (53)
Forfeited (3) (1) 0 (4) - - - -
-------------------------------------------------------------------------
Outstanding at June 30 326 177 101 604 284 161 98 543
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Exercisable at June 30 89 15 101 205 112 - 98 210
Share Unit Plan compensation expense recorded in the three and
six month periods ended June 30,
2010, were $301,000 (2009
-$ 501,000) and $621,000 (2009 - $628,000).
c) The Company's intention is to settle Share Unit Plan
obligations from an independent trust established by the Company to
purchase common shares of the Company on the open-market. The trust
is considered to be a variable interest entity and is consolidated
in the Company's financial statements with the number and cost of
shares held in trust, reported as a reduction of capital stock.
During the three and six month periods ended June 30, 2010, 92,500 and 129,300 common shares
were acquired respectively, by the trust (2009 - 25,000 and 75,000)
at a cost of $633,000 for the three
month period and $883,000 for the six
month period.
d) Normal Course Issuer Bid ("NCIB")
On December 23, 2009, the Company
announced the renewal of the NCIB to purchase up to 880,000 common
shares through the facilities of NASDAQ, representing approximately
5% of its outstanding common shares. Shares may be purchased up to
December 31, 2010. As at June 30, 2010, the Company purchased 49,278
shares (2009 - 454,848) at an average cost of $6.61 per share (2009 - $4.98) for an aggregate cost of $326,000 (2009 - $2,266,000).
e) Reconciliation of weighted average number of diluted common
shares outstanding (in 000's)
The following table summarizes the common shares in calculating
net earnings per share.
Three Months Ended Six Months Ended
--------------------- ---------------------
June 30 June 30
2010 2009 2010 2009
-------------------------------------------------------------------------
Weighted average common
shares outstanding- basic 17,514 17,707 17,546 17,871
Effect of Stock options
(note 4(a)) - 219 - 156
Effect of Share Unit Plans 271 225 273 162
-------------------------------------------------------------------------
Weighted average common
shares outstanding- diluted 17,785 18,151 17,818 18,189
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Note 5 - Income taxes
a) 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 Six Months Ended
June 30 June 30
2010 % 2009 % 2010 % 2009 %
-------------------------------------------------------------------------
Income (loss) before
income taxes (100) 1,003 3,175 9,762
-------------------------------------------------------------------------
Income taxes
calculated at
expected rates (29) 28.5 294 29.3 905 28.5 2,859 29.3
Non-deductible items 28 (28.0) (7) (0.7) 55 1.7 158 1.6
Share based
compensation 55 (55.0) 14 1.4 130 4.1 30 0.3
Adjustments on filing
returns & other (53) 52.5 75 7.5 (20) (0.6) 86 0.9
-------------------------------------------------------------------------
2.0 (2.0) 376 37.5 1,070 33.7 3,133 32.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
As at June 30, 2010 included in
other current assets are income taxes receivable of $111,000 (December 31,
2009 - $1,029,000).
b) Future income taxes reflect the net effects of temporary
differences between the carrying amounts of assets and liabilities
for financial reporting purposes and the amounts used for income
tax purposes. Significant components of future income tax assets
and liabilities are as follows:
June 30 December 31
2010 2009
-------------------------------------------------------------------------
Assets
Property and equipment 883 852
Share based compensation 870 856
Other 126 127
-------------------------------------------------------------------------
1,879 1,835
Liabilities
Goodwill and other 451 378
-------------------------------------------------------------------------
Net future income tax asset 1,428 1,457
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The Company believes it is more likely than not that all future
income tax assets will be realized.
Note 6 - 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 term bank credit facility (the "Credit Facility') that is
used to finance its net working capital and general corporate
requirements. The Credit Facility was entered into on July 8, 2010 and matures in July, 2013.
Previously, the Company had a $60
million, 364 day bank operating borrowing facility.
The maximum amount available to borrow under the Credit Facility
is subject to a borrowing base formula applied to accounts
receivable and inventories. Under the terms of the Credit Facility,
the Company must maintain the ratio of its debt to debt-plus-equity
at less than 40% (0% at June 30,
2010) and coverage of net operating free cash flow as
defined in the Credit Facility agreement over interest expense for
the trailing 12 month period of greater than 1.25 times (5.4 times
at June 30, 2010). The Credit
Facility contains certain other covenants, which the Company is in
compliance with. 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 anticipated
contractual commitments.
Note 7 - Financial Instruments and Risk Management
a) Fair Values
The Company's financial instruments recognized on the
consolidated balance sheet consist of cash, accounts receivable,
accounts payable and accrued liabilities, bank operating loan 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 June 30,
2010, the fair value of the long term debt approximated its
carrying value due to its floating interest rate nature and short
term maturity. There is no active market for these financial
instruments.
b) Credit Risk
A substantial portion of the Company's accounts receivable
balance is with customers in the oil and gas industry and is
subject to normal industry credit risks. The Company follows a
program of credit evaluations of customers and limits the amount of
credit extended when deemed necessary.
The Company maintains provisions for possible credit losses that
are charged to selling, general and administrative expenses by
performing an analysis of specific accounts. Movement of the
allowance for credit losses for the six months ended June 30, 2010 and June 30,
2009 was as follows:
As at June 30 2010 2009
-------------------------------------------------------------------------
Opening balance 2,335 2,776
Write-offs (147) (477)
Change in provision for credit losses (424) 164
-------------------------------------------------------------------------
Closing balance 1,764 2,463
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Included in the June 30, 2010
change in provision for credit losses are recoveries of
$675,000 for items previously
provided for (2009 - nil).
Trade receivables outstanding greater than 90 days were 8% of
total trade receivables as at June 30,
2010 (2009 - 13%).
c) Market Risk
The Company's bank operating loan and long term debt bear
interest based on floating rates. As a result the Company is
exposed to market risk from changes in the Canadian prime interest
rate which can impact borrowing costs. The Company purchases
certain products in US dollars and sells such products to its
customers typically priced in Canadian dollars, thus leading to
accounts receivable and accounts payable balances that are subject
to foreign exchange gains and losses upon translation. As a result,
fluctuations in the value of the Canadian dollar relative to the US
dollar can result in foreign exchange gains and losses.
d) Risk Management
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 purchase
commitments. The Company's foreign exchange risk arises principally
from the settlement of United
States dollar denominated net working capital balances as a
result of product purchases denominated in United States dollars. As at June 30, 2010, the Company had contracted to
purchase US$8.9 million at fixed
exchange rates with terms not exceeding six months. The fair market
values of the contracts were nominal.
Note 8 - Related Party Transactions
Smith International Inc. ("Smith") owns approximately 55% of the
Company's outstanding shares. The Company is the exclusive
distributor in Canada of down hole
pump production equipment manufactured by Wilson Supply, a division
of Smith. Purchases of such equipment conducted in the normal
course on commercial terms were as follows:
June 30 June 30
2010 2009
-------------------------------------------------------------------------
Cost of sales for the three months ended 1,582 771
Cost of sales for the six months ended 3,697 2,445
Inventory 3,631 3,920
Accounts payable and accrued liabilities 601 602
The Company pays facility rental expense to an operations
manager in the capacity of landlord, reflecting market based rates.
For the three and six month period ended June 30, 2010, these costs totaled $181,000 and $425,000 (2009: $124,000 and $334,000).
Note 9 - Segmented reporting
The Company distributes oilfield products principally through
its network of 49 branches located in western Canada to oil and gas industry customers.
Accordingly, the Company has determined that it operated through a
single operating segment and geographic jurisdiction.
SOURCE CE Franklin Ltd.