ACHESON, ALBERTA (TSX: NOA)(NYSE: NOA) today announced results
for the three months (second quarter) and six months (first half)
ended September 30, 2007.
All dollar amounts discussed are in Canadian dollars.
Consolidated Financial Highlights (in millions except per share
information and equipment hours)
Three Months Ended Six Months Ended
Sept 30, Sept 30,
2007 2006 2007 2006
------------------- -------------------
Revenue $ 223.6 $ 130.1 $ 391.2 $ 268.2
Gross profit $ 35.2 $ 20.2 $ 50.1 $ 52.8
Gross profit 15.7% 15.5% 12.8% 19.7%
Operating income $ 17.1 $ 9.7 $ 16.6 $ 32.8
Net Income (loss) $ 2.1 $ (4.8) $ (8.3) $ 13.1
Earnings (loss) per share:
Basic $ 0.06 $ (0.26) $ (0.23) $ 0.71
Diluted $ 0.06 $ (0.26) $ (0.23) $ 0.53
Consolidated EBITDA(1) $ 27.9 $ 15.8 $ 37.6 $ 47.3
Capital spending $ 33.4 $ 10.0 $ 43.5 $ 19.3
Equipment hours 323,971 236,711 602,210 480,716
(1) A definition of Consolidated EBITDA and a reconciliation to net income
can be found on page 9 of this press release.
"Successful bidding, underpinned by our strong reputation and
coupled with improved execution, contributed to solid second
quarter results," said Rod Ruston, President and CEO of NAEP. "Our
revenue grew 72% year-over-year, reflecting the ever-expanding
activity in the Alberta oil sands and the initiation of a major
pipeline contract."
"Despite continuing cost pressures and a significant investment
in internal initiatives, we were successful in carrying our revenue
growth through to our bottom line," added Ruston. "Gross profit
grew by 74% and Consolidated EBITDA was up 77%. We ended the
quarter with net income of $2.1 million, compared to a net loss of
$4.8 million during the same period last year. These gains reflect
the return to profitability in our Pipeline division supported by
continued good performance throughout the rest of our
business."
Segment Financial Highlights (in millions)
Three Months Ended Six Months Ended
Sept 30, Sept 30,
2007 2006 2007 2006
------------------- -------------------
Heavy Construction and Mining
Revenue $ 149.8 $ 100.2 $ 276.7 $ 211.6
Segment profit $ 21.0 $ 12.5 $ 40.5 $ 38.6
Segment profit % 14.0% 12.5% 14.6% 18.2%
Piling
Revenue $ 42.4 $ 27.0 $ 77.9 $ 50.2
Segment profit $ 11.1 $ 9.2 $ 20.3 $ 15.3
Segment profit % 26.2% 34.1% 26.1% 30.5%
Pipeline
Revenue $ 31.3 $ 2.9 $ 36.5 $ 6.3
Segment profit $ 2.4 $ 0.4 $ 1.2 $ 1.1
Segment profit % 7.7% 13.8% 3.3% 17.5%
The Heavy Construction and Mining division performed
particularly well in the second quarter increasing revenue by 50%
and gross profit by 68%. The Company continued to expand its heavy
construction business with the execution of contracts for Suncor
Energy Inc.'s (Suncor) Millennium Naptha Unit (MNU) and Voyageur
projects and completion of the design-build contract for the
construction of Albian Sands Energy Inc.'s (Albian) Aerodrome.
Increased demand was experienced under the Company's multi-year
site service agreements with Albian and Syncrude Canada Ltd.
(Syncrude). In addition, the Company continued to execute large
amounts of work at Albian's Jackpine Mine and De Beers Canada
Inc.'s (De Beers) Victor diamond mine and continued to increase
production under its 10-year mining contract with Canadian Natural
Resources Ltd. (Canadian Natural).
The Piling segment also contributed excellent second quarter
results, achieving a 57% increase in revenue and a 21% improvement
in gross profit, compared to last year. Piling margins decreased
from the prior year but were still very healthy at 26%. The margin
decrease was due to a combination of changed product mix and
contract mix coupled with a higher proportion of flow-through costs
in current projects.
"Our revenue gains in these two segments were bolstered by
significantly higher revenue from our Pipeline division as we began
work on a major contract with Kinder Morgan Canada (Kinder Morgan)
for construction of its TMX Anchor Loop project," said Ruston.
"Second quarter Pipeline revenue jumped to $31.3 million from $2.9
million last year. The division returned to profitability this
quarter and we expect further margin improvement going forward.
While completing the remaining fixed-price contract we incurred
approximately $2 million of additional costs in the second quarter
resulting in a 7.7% segment margin compared to 13.8% in the prior
year. We are working with our clients to resolve cost overruns that
occurred on this and other fixed-price pipeline projects as a
result of poor weather, difficult ground conditions and changing
work scope."
"Overall, we are pleased with our second quarter results and we
anticipate continued growth through the third quarter. Development
of the Alberta oil sands continues at a rapid pace, work on the TMX
Anchor Loop pipeline project is proceeding well and business
conditions remain very strong throughout western Canada. We are
capitalizing on these opportunities and improving our execution at
the same time," said Ruston.
Consolidated Second Quarter Results
Second quarter consolidated revenue increased to $223.6 million,
a 72% gain over the same period last year. While improvements were
achieved in all operating segments, most of the $93.5 million gain
was driven by a combination of increased Heavy Construction and
Mining activity in the oil sands, increased demand in piling and
the initiation of a major contract in the Pipeline division.
Second quarter gross profit increased to $35.2 million, up 74%
over the same period last year, reflecting increased sales and
higher profit margins. As a percentage of revenue, gross profit
increased to 15.7% from 15.5%, due to higher project margins in
Heavy Construction and Mining offset by lower margins in Piling and
the losses on Pipeline's fixed-price contracts.
Net income increased to $2.1 million in the second quarter, from
a net loss of $4.8 million last year. Earnings per share for the
second quarter were $0.06 compared to a loss of $0.26 per share in
the prior year. Improvements in operating income were partially
offset by impacts of the new Canadian accounting standards that
require companies to account for changes in the fair value of
embedded derivative financial instruments in various contracts and
to modify the method of amortizing deferred financing costs. These
standards, adopted in the previous quarter, resulted in an
incremental non-cash charge to income of approximately $5 million
in the second quarter.
Consolidated First Half Results
First half consolidated revenue increased to $391.2 million, a
46% gain over the same period last year. While revenue gains were
realized in all operating segments, the most significant increases
were achieved in the Heavy Construction and Mining division, most
notably due to the work on Albian's Aerodrome and Suncor's MNU
project as well as increased demand under the Company's service
agreements with Albian and Syncrude.
First half gross profit was $50.1 million, compared to $52.8
million a year ago and represented 12.8% of revenue during the
period, compared to 19.7% last year. The change in gross profit
margin reflects higher equipment costs, mostly related to
significantly increased tire costs caused by the shortage of large
truck tires, as well as a first quarter loss on disposal of surplus
equipment recorded as depreciation. It also reflects losses in the
Pipeline segment related to fixed-price contracts that were
completed in the second quarter. Gross margin in the prior year
period was higher than normal due to the settlement of a $6.1
million claim.
The Company incurred a net loss of $8.3 million or $0.23 per
share in the first half, compared to net income of $13.1 million or
$0.71 per share during the same period last year. The
year-over-year change in net income primarily reflects an
incremental non-cash charge to first half income of approximately
$15 million related to the adoption of the previously mentioned new
Canadian accounting standards for financial instruments relating to
embedded derivatives in certain contracts. Higher first half
general and administrative expenses resulting from first quarter
bonus payments for past service and additional costs related to
business improvement initiatives and reporting and control
enhancements have also contributed to the year-to-date net
loss.
Outlook
Management's outlook for the balance of the fiscal year remains
positive. Project activity in the Alberta oil sands continues to
accelerate despite recent changes to Alberta's royalty rates. The
changes, which were announced by the Alberta government in October,
were significant but lower than the increases recommended to the
government by the Royalty Review Panel. While some of NAEP's
customers have announced intentions to reduce oil and gas
investment in Alberta as a result of the royalty changes, to date
the areas affected by these investment reductions do not include
oil sands mining projects. Oil sands mines are long-term projects
that require a significant initial capital investment to develop.
As a result, management perceives the risk that customers will
cancel, delay or reduce the scope of any significant projects
presently underway, as a result of the royalty changes, to be low.
The Company is continuing to experience increasing requests for
services under existing contracts with its major oil sands
customers, in spite of the recent royalty changes.
In the Heavy Construction and Mining division, NAEP is working
on major oil sands projects including Suncor's MNU and Voyageur
projects under a five-year site services agreement. The Company is
also working on Canadian Natural's Horizon project under a 10-year
overburden removal contract. In addition, NAEP provides ongoing
services, under multi-year contracts, for site development and to
support mining operations at Albian's Muskeg River site and
Syncude's Aurora and Base Plant mine sites. Responding to
customers' needs NAEP's Heavy Construction & Mining Division
has broadened its overall service offering by entering into a
number of industrial construction contracts where, in addition to
providing traditional services, NAEP is also acting as the general
contractor. In this expanded role, the Company will supervise a
variety of subcontractors, procure supplies and materials for
projects and coordinate the work of other contractors. These
services, although additive to revenues and earnings, are performed
at lower margins than the traditional heavy construction and mining
work but with very little capital employed.
Demand for piling services is expected to remain high through
the balance of the year as a result of oil sands development and
continued strong commercial and industrial construction activity in
Western Canada. The outlook for the Pipeline division is also
positive with all remaining fixed-price contracts completed and the
construction of the $185 million TMX Anchor Loop project now
underway.
Overall, management expects operating performance will continue
to improve as a result of the strong market demand for NAEP's
services and the positive impact of a number of internal
initiatives focused on enhancing performance.
Consolidated Balance Sheets
As at September 30 (in thousands of Canadian dollars)
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September 30, 2007 March 31,2007
--------------------------------------------------------------------------
(unaudited)
Assets
Current assets:
Cash and cash equivalents $ - $ 7,895
Accounts receivable 124,048 93,220
Unbilled revenue 72,689 82,833
Inventory 154 156
Asset held for sale - 8,268
Prepaid expenses and deposits 7,187 11,932
Other assets 5,468 10,164
Future income taxes 21,956 14,593
--------------------------------------------------------------------------
231,502 229,061
Future income taxes 26,007 14,364
Plant and equipment 280,490 255,963
Goodwill 200,056 199,392
Intangible assets, net of accumulated
amortization of $18,738
(March 31, 2007 - $17,608) 2,883 600
Deferred financing costs, net of
accumulated amortization of $nil
(March 31,2007 - $7,595) - 11,356
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$ 740,938 $ 710,736
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Liabilities and Shareholders' Equity
Current liabilities:
Cheques issued in excess of cash deposits $ 4,669 $ -
Revolving credit facility - 20,500
Accounts payable 130,057 94,548
Accrued liabilities 21,067 23,393
Billings in excess of costs incurred
and estimated earnings on uncompleted
contracts 1,979 2,999
Current portion of capital lease obligations 3,224 3,195
Current portion of derivative financial
instruments 4,458 2,669
Future income taxes 14,405 4,154
--------------------------------------------------------------------------
179,859 151,458
Deferred lease inducements 993 -
Capital lease obligations 5,169 6,514
Senior notes 190,860 230,580
Derivative financial instruments 104,080 58,194
Future income taxes 24,243 19,712
--------------------------------------------------------------------------
505,204 466,458
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--------------------------------------------------------------------------
Shareholders' equity:
Common shares (authorized - unlimited
number of voting and non voting common
shares; issued and outstanding -
35,752,060 voting common shares
(March 31, 2007 - 35,192,260 voting
common shares and 412,400 non-voting
common shares)) 297,216 296,198
Contributed surplus 4,075 3,606
Deficit (65,557) (55,526)
--------------------------------------------------------------------------
235,734 244,278
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$ 740,938 $ 710,736
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Consolidated Statements of Operations and Deficit
For the three and six months ended September 30
(in thousands of Canadian dollars, except per share amounts)
--------------------------------------------------------------------------
Three Months Ended Six Months Ended
September 30, September 30,
(unaudited) (unaudited)
2007 2006 2007 2006
--------------------------------------------------------------------------
Revenue $ 223,575 $ 130,066 $ 391,202 $ 268,166
Project costs 135,266 73,083 229,939 140,092
Equipment costs 42,212 25,598 87,351 49,533
Equipment operating lease
expense 3,569 6,369 7,504 13,569
Depreciation 7,318 4,822 16,294 12,134
--------------------------------------------------------------------------
Gross profit 35,210 20,194 50,114 52,838
General and administrative costs 17,360 10,012 31,987 19,247
Loss on disposal of plant and
equipment 576 345 845 458
Loss on disposal of asset held
for sale - - 316 -
Amortization of intangible
assets 182 182 323 365
--------------------------------------------------------------------------
Operating income before the
undernoted 17,092 9,655 16,643 32,768
Interest expense 6,196 10,326 12,934 20,494
Foreign exchange (gain) loss (14,252) 72 (31,352) (13,394)
Realized and unrealized loss on
derivative financial
instruments 21,236 3,786 45,185 11,782
Financing costs - 53 - 53
Other income (128) (8) (236) (591)
--------------------------------------------------------------------------
Income (loss) before income
taxes 4,040 (4,574) (9,888) 14,424
Income taxes
Current income taxes - (2,712) 21 (2,844)
Future income taxes 1,972 2,895 (1,654) 4,131
--------------------------------------------------------------------------
Net income (loss) and
comprehensive income (loss)
for the period 2,068 (4,757) (8,255) 13,137
Deficit, beginning of period
- as previously reported (67,625) (58,652) (55,526) (76,546)
Change in accounting policy
related to financial
instruments - - (1,776) -
--------------------------------------------------------------------------
Deficit, end of period $ (65,557) $ (63,409) $ (65,557) $ (63,409)
--------------------------------------------------------------------------
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Net income (loss) per share
- basic $ 0.06 $ (0.26) $ (0.23) $ 0.71
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Net income (loss) per share
- diluted $ 0.06 $ (0.26) $ (0.23) $ 0.53
--------------------------------------------------------------------------
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Consolidated Statements of Cash Flows
For the three and six months ended September 30
(in thousands of Canadian dollars)
--------------------------------------------------------------------------
Three Months Ended Six Months Ended
September 30, September 30,
(unaudited) (unaudited)
2007 2006 2007 2006
--------------------------------------------------------------------------
Cash provided by (used in):
Operating activities:
Net income (loss) for the
period $ 2,068 $ (4,757) $ (8,255) $ 13,137
Items not affecting cash:
Depreciation 7,318 4,822 16,294 12,134
Write-down of other assets
to replacement cost 1,848 - 1,848 -
Amortization of intangible
assets 182 182 323 365
Amortization of deferred
lease inducements (52) - (52) -
Amortization of deferred
financing costs - 948 - 1,835
Loss on disposal of plant
and equipment 576 345 845 458
Loss on disposal of asset
held for sale - - 316 -
Unrealized foreign exchange
(gain) loss on senior notes (13,864) 78 (31,014) (13,493)
Amortization of bond issue
costs 110 - 507 -
Unrealized loss on derivative
financial instruments 20,569 3,019 43,850 10,438
Stock-based compensation
expense 388 809 747 1,121
Accretion of redeemable
preferred shares - 965 - 1,910
Future income taxes 1,972 2,895 (1,654) 4,131
Net changes in non-cash
working capital 1,175 (4,768) 4,825 (14,751)
--------------------------------------------------------------------------
22,290 4,538 28,580 17,285
--------------------------------------------------------------------------
Investing activities:
Acquisition, net of cash
acquired - (1,496) (1,581) (1,496)
Purchase of plant and
equipment (33,352) (9,973) (43,545) (19,309)
Additions to assets held
for sale - - (2,248) -
Proceeds on disposal of
plant and equipment 226 99 3,916 572
Proceeds on disposal of
assets held for sale - - 10,200 -
Net changes in non-cash working
capital 17,493 1,678 14,249 1,474
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(15,633) (9,692) (19,009) (18,759)
--------------------------------------------------------------------------
Financing activities:
Decrease in revolving credit
facility (20,000) - (20,500) -
Repayment of capital lease
obligations (806) (848) (1,608) (1,621)
Financing costs - (2,403) (767) (3,021)
Issue of common shares - 139 740 139
--------------------------------------------------------------------------
(20,806) (3,112) (22,135) (4,503)
--------------------------------------------------------------------------
Decrease in cash and cash
equivalents (14,149) (8,266) (12,564) (5,977)
Cash and cash equivalents,
beginning of period 9,480 45,093 7,895 42,804
--------------------------------------------------------------------------
Cash and cash equivalents
(cheques issued in excess
of cash deposits), end of
period $ (4,669) $ 36,827 $ (4,669) $ 36,827
--------------------------------------------------------------------------
--------------------------------------------------------------------------
Consolidated EBITDA
EBITDA is calculated as net income (loss) before interest
expense, income taxes, depreciation and amortization. Consolidated
EBITDA is defined as EBITDA, excluding the effects of foreign
exchange gain or loss, realized and unrealized gain or loss on
derivative financial instruments, non-cash stock-based compensation
expense, gain or loss on disposal of plant and equipment and
certain other non-cash items included in the calculation of net
income (loss). We believe that EBITDA is a meaningful measure of
the performance of our business because it excludes items, such as
depreciation and amortization, interest and taxes, which are not
directly related to the operating performance of our business.
Management reviews EBITDA to determine whether plant and equipment
are being allocated efficiently. In addition, our revolving credit
facility requires us to maintain a minimum interest coverage ratio
and a maximum senior leverage ratio, which includes the reference
to Consolidated EBITDA. Non-compliance with this financial covenant
could result in our being required to immediately repay all amounts
outstanding under our revolving credit facility. EBITDA and
Consolidated EBITDA are not measures of performance under Canadian
GAAP or U.S. GAAP and our computations of EBITDA and Consolidated
EBITDA may vary from others in our industry. EBITDA and
Consolidated EBITDA should not be considered as alternatives to
operating income or net income as measures of operating performance
or cash flows as measures of liquidity. EBITDA and Consolidated
EBITDA have important limitations as analytical tools and you
should not consider them in isolation or as substitutes for
analysis of our results as reported under Canadian GAAP or U.S.
GAAP. A reconciliation of net income (loss) to EBITDA and
Consolidated EBITDA is as follows:
Three Months Ended Six Months Ended
Sept 30, Sept 30,
2007 2006 2007 2006
------------------- -------------------
Net income (loss) $ 2.1 $ (4.8) $ (8.3) $ 13.1
Adjustments:
Interest expense 6.2 10.3 12.9 20.5
Income taxes 1.9 0.3 (1.6) 1.3
Depreciation 7.3 4.8 16.3 12.1
Amortization of intangible
assets 0.2 0.2 0.4 0.4
------------------- -------------------
EBITDA $ 17.7 $ 10.8 $ 19.7 $ 47.4
------------------- -------------------
EBITDA $ 17.7 $ 10.8 $ 19.7 $ 47.4
Adjustments:
Unrealized foreign exchange
(gain) loss on senior notes (13.8) 0.1 (31.0) (13.5)
Realized and unrealized loss on
derivative financial instruments 21.2 3.8 45.2 11.8
Loss on disposal of
equipment and assets held
for sale 0.6 0.3 1.2 0.5
Stock-based compensation 0.4 0.8 0.7 1.1
Write down of other assets to
replacement cost 1.8 - 1.8 -
------------------- -------------------
Consolidated EBITDA $ 27.9 $ 15.8 $ 37.6 $ 47.3
------------------- -------------------
About the Company
North American Energy Partners Inc. (www.nacg.ca) is one of the
largest providers of mining and site preparation, piling and
pipeline installation services in Western Canada. For more than 50
years, NAEP has provided services to large oil, natural gas and
resource companies, with a principal focus on the Canadian oil
sands. The Company maintains one of the largest independently owned
equipment fleets in the region.
Forward Looking Statements
The release contains forward-looking statements. Forward-looking
statements include statements preceded by, followed by or that
include the words "may", "could", "would", "should", "believe",
"expect", "anticipate", "plan", "estimate", "target", "project",
"intend", "continue", "further" or similar expressions. Actual
results could differ materially from those contemplated by such
forward-looking statements as a result of any number of factors and
uncertainties, many of which are beyond our control. Important
factors that could cause actual results to differ materially from
those in forward-looking statements include success of business
development efforts, changes in oil and gas prices, availability of
a skilled labour force, internal controls, general economic
conditions, terms of our debt instruments, exchange rate
fluctuations, weather conditions, performance of our customers,
access to equipment, changes in laws and our ability to execute
transactions. Undue reliance should not be placed upon
forward-looking statements and we undertake no obligation, other
than as required by applicable law, to update or revise those
statements.
For more complete information about us, you should read our
disclosure documents that we have filed with the Securities and
Exchange Commission and the Canadian Securities Administration. You
may obtain these documents for free by visiting EDGAR on the SEC
website at www.sec.gov or SEDAR on the CSA website at
www.sedar.com.
Contacts: North American Energy Partners Inc. Kevin Rowand
Investor Relations, Manager (780) 960-4531 (780) 960-7103 (FAX)
Email: krowand@nacg.ca Website: www.nacg.ca
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