CALGARY,
Oct. 30, 2013 /CNW/ - Western Energy
Services Corp. ("Western" or the "Company") (TSX: WRG) is pleased
to release its third quarter 2013 financial and operating
results. Additional information relating to the Company,
including the Company's financial statements and management's
discussion and analysis as at and for the three and nine months
ended September 30, 2013 and 2012
will be available on SEDAR at www.sedar.com. All amounts are
denominated in Canadian dollars (CDN$) unless otherwise
identified.
Third Quarter 2013 Highlights:
- Operating Revenue totalled $96.5
million, a $31.5 million
increase (or 48%) over the same period in the prior year as a
result of the increased size and scale of Western's production
services segment following the acquisition of IROC Energy Services
Corp. ("IROC") on April 22, 2013, as
well as a larger average drilling rig fleet and increased
utilization in the contract drilling segment in both Canada and the
United States;
- Utilization in the Canadian contract drilling segment improved
to 56% as compared to the CAODC industry average of 40%, which was
unchanged from the same period in the prior year, and Western's
third quarter 2012 average of 53%. In the United States, contract drilling
utilization averaged 88% as compared to 60% in the same period of
the prior year due to increased marketing efforts and strong
operational performance;
- Total well servicing hours in Western's production services
segment increased significantly following the acquisition of IROC
in the second quarter, increasing by 1,586% as compared to the same
period in the prior year. Likewise, well servicing
utilization averaged 51% as compared to 39% in the same period of
the prior year;
- EBITDA totalled $30.3 million, a
$6.4 million increase (or 27%) over
the same period in the prior year. While the Company was able
to effectively control costs in the contract drilling segment
quarter over quarter, as a percentage of Operating Revenue, EBITDA
declined from 37% in the third quarter of 2012 to 31% in the third
quarter of 2013, mainly due to lower contract drilling day rates in
both Canada and the United States;
- Capital expenditures totalled $31.0
million and include $25.5
million of expansion capital, $3.0
million of maintenance capital and $2.5 million for critical spares and mainly
relate to the drilling rig build program in the contract drilling
segment.
Year to Date Highlights:
- Operating Revenue totalled $234.6
million, a $28.2 million
increase (or 14%) over the same period in the prior year due to
increased revenue in the production services segment subsequent to
the acquisition of IROC and increased operating days in the
contract drilling segment, partially offset by lower pricing in the
contract drilling segment in both Canada and the
United States;
- Contract drilling utilization in Canada remained relatively constant averaging
52% as compared to the CAODC industry average of 39% and 53% in the
prior year. In the United
States, contract drilling utilization averaged 60% in 2013
as compared to 69% in the same period of the prior year mainly due
to lower activity levels in the first half of 2013, partially
offset by increased activity in the third quarter of 2013;
- Subsequent to the acquisition of IROC, total well servicing
hours in the production services segment significantly increased by
1,413% as compared to the same period in the prior year. Year
to date well servicing utilization has averaged 40% in 2013 as
compared to 31% in the same period of the prior year;
- EBITDA totalled $73.9 million, a
$3.7 million decrease (or 5%) as
compared to the same period of the prior year. While Western was
able to effectively control costs in the contract drilling segment
year over year on a per operating day basis, the decrease in EBITDA
is mainly due to lower contract drilling rates in both Canada and the
United States, partially offset by an increased contribution
from the production services segment following the acquisition of
IROC;
- Capital expenditures totalled $67.7
million and include $55.3
million of expansion capital, $6.6
million of maintenance capital and $5.8 million for critical spares, and mainly
relate to the drilling rig build program in the contract drilling
segment.
|
Selected Financial Information |
(stated in
thousands, except share and per share amounts) |
|
Three months ended Sept 30 |
|
Nine months ended Sept 30 |
Financial Highlights |
2013 |
2012 |
Change |
|
2013 |
2012 |
Change |
Revenue |
101,389 |
69,573 |
46% |
|
250,230 |
225,279 |
11% |
Operating Revenue(1) |
96,473 |
64,999 |
48% |
|
234,563 |
206,401 |
14% |
Gross Margin(1) |
37,547 |
29,382 |
28% |
|
94,579 |
93,703 |
1% |
Gross Margin as a percentage of
operating revenue |
39% |
45% |
(13%) |
|
40% |
45% |
(11%) |
EBITDA(1) |
30,297 |
23,944 |
27% |
|
73,880 |
77,550 |
(5%) |
EBITDA as a percentage of operating
revenue |
31% |
37% |
(16%) |
|
31% |
38% |
(18%) |
Cash flow from operating
activities |
6,667 |
9,248 |
(28%) |
|
77,492 |
93,895 |
(17%) |
Capital expenditures |
31,002 |
30,898 |
- |
|
67,705 |
106,903 |
(37%) |
Net income |
7,927 |
8,251 |
(4%) |
|
19,449 |
32,086 |
(39%) |
|
- basic net income per share |
0.11 |
0.14 |
(21%) |
|
0.29 |
0.55 |
(47%) |
|
- diluted net income per share |
0.11 |
0.14 |
(21%) |
|
0.28 |
0.53 |
(47%) |
Weighted average number of shares |
|
|
|
|
|
|
|
|
- basic |
73,351,805 |
58,581,133 |
25% |
|
67,569,459 |
58,549,352 |
15% |
|
- diluted |
73,793,367 |
60,700,338 |
22% |
|
68,587,001 |
60,618,945 |
13% |
Outstanding common shares as at period
end |
73,366,253 |
59,427,143 |
23% |
|
73,366,253 |
59,427,143 |
23% |
Dividends declared |
5,502 |
4,457 |
23% |
|
15,478 |
4,457 |
247% |
(1) See financial measures
reconciliations. |
|
Financial Position at (stated in
thousands) |
|
Sept 30, 2013 |
Sept 30, 2012 |
|
Change |
Dec 31, 2012 |
Change |
Working capital |
|
45,862 |
62,753 |
|
(27%) |
77,628 |
(41%) |
Property and equipment |
|
770,770 |
558,248 |
|
38% |
568,157 |
36% |
Total assets |
|
947,836 |
727,113 |
|
30% |
749,448 |
26% |
Long term debt |
|
263,050 |
176,739 |
|
49% |
186,948 |
41% |
|
|
|
|
|
|
|
|
|
Three months ended
Sept 30 |
|
Nine months ended
Sept 30 |
Operating Highlights |
2013 |
2012 |
Change |
|
2013 |
2012 |
Change |
Contract Drilling |
|
|
|
|
|
|
|
Canadian Operations: |
|
|
|
|
|
|
|
Contract drilling rig fleet: |
|
|
|
|
|
|
|
|
- Average |
45 |
42 |
7% |
|
45 |
41 |
10% |
|
- End of period |
46 |
43 |
7% |
|
46 |
43 |
7% |
Operating revenue per operating day
(CDN$)(1) |
25,385 |
26,837 |
(5%) |
|
26,918 |
29,189 |
(8%) |
Drilling rig operating
days(2) |
2,335 |
2,055 |
14% |
|
6,345 |
5,928 |
7% |
Drilling rig utilization per revenue
day(3) |
62% |
58% |
7% |
|
57% |
59% |
(3%) |
Drilling rig utilization rate per
operating day(2) |
56% |
53% |
6% |
|
52% |
53% |
(2%) |
CAODC industry average utilization
rate(2) |
40% |
40% |
- |
|
39% |
42% |
(7%) |
|
|
|
|
|
|
|
|
United States Operations: |
|
|
|
|
|
|
|
Contract drilling rig fleet: |
|
|
|
|
|
|
|
|
- Average |
5 |
5 |
- |
|
5 |
5 |
- |
|
- End of period |
5 |
5 |
- |
|
5 |
5 |
- |
Operating revenue per operating day
(US$)(1) |
24,410 |
32,137 |
(24%) |
|
27,128 |
32,850 |
(17%) |
Drilling rig operating
days(2) |
403 |
275 |
47% |
|
825 |
952 |
(13%) |
Drilling rig utilization per revenue
day(3) |
98% |
73% |
34% |
|
74% |
87% |
(15%) |
Drilling rig utilization per operating
day(2) |
88% |
60% |
47% |
|
60% |
69% |
(13%) |
|
|
|
|
|
|
|
|
Production Services |
|
|
|
|
|
|
|
Well servicing rig fleet: |
|
|
|
|
|
|
|
|
- Average |
65 |
5 |
1,200% |
|
46 |
4 |
1,050% |
|
- End of period |
65 |
5 |
1,200% |
|
65 |
5 |
1,200% |
Operating revenue per service hour
(CDN$)(1) |
743 |
582 |
28% |
|
740 |
581 |
27% |
Total service hours |
30,328 |
1,799 |
1,586% |
|
46,476 |
3,072 |
1,413% |
Service rig utilization
rate(4) |
51% |
39% |
31% |
|
40% |
31% |
29% |
(1) |
Operating revenue per operating day and per service hour are
calculated using operating revenue divided by operating days and
service hours, respectively. |
(2) |
Drilling rig utilization rate per operating day and drilling
rig operating days are calculated on operating days only
(i.e. spud to rig release basis). |
(3) |
Drilling rig utilization rate per revenue day is calculated
based on operating and move days. |
(4) |
Service rig utilization rate calculated based on full
utilization of 10 hours per day, 365 days per year. |
|
|
Outlook
Western's operations are focused on three core
business lines: contract drilling, well servicing and oilfield
equipment rental services. Western currently has a drilling
rig fleet of 51 rigs, with an average age of approximately six
years, with three additional rigs under construction consisting of
two telescopic ELR double drilling rigs, one of which will be the
Company's second convertible pad rig, and the re-commissioning of a
single drilling rig. Western is the sixth largest drilling
contractor in Canada with a fleet
of 46 rigs operating through Horizon Drilling. Additionally,
Western has five ELR triple drilling rigs deployed in the United States operating through
Stoneham Drilling. Western
is also the seventh largest well servicing company in Canada with a fleet of 65 rigs operating
through Eagle Well Servicing. Western's well servicing fleet
is one of the newest in the Western Canadian Sedimentary Basin,
with an average age of approximately four years. Western's
oilfield equipment rental division operates through AERO Rental
Services, which provides advanced designed oilfield equipment used
in drilling and completions processes by oil and gas producers and
oilfield service companies.
Western's drilling rig fleet is specifically
suited for the current market which is focused on drilling
horizontal wells of increased complexity. In total, 96% of
Western's fleet are ELR drilling rigs with depth ratings greater
than 3,000 meters and all of Western's rigs are capable of drilling
resource based horizontal wells. Approximately one third of
Western's fleet is currently under long term take-or-pay contracts,
an increase from the second quarter when approximately one quarter
of the fleet was under long term contracts. The increase is
due to improved demand, as the 2014 winter drilling season
approaches, for high quality deep drilling rigs such as
Western's. The average remaining term on these contracts is
approximately two years, which provides a base level of
revenue. These contracts typically generate 250 operating
days per year in Canada, as spring
breakup restricts activity during the second quarter, while in
the United States these contracts
typically range from 330 to 365 revenue generating days per
year.
Western's approved capital spending for 2013
totals approximately $118 million,
including $98 million in expansion
capital, $14 million in maintenance
capital and $6 million in critical
spare equipment. In total, budgeted capital spending has
increased by $24 million from the
previously disclosed $94
million. The Company's expansion capital has increased
by $29 million from the previously
disclosed $69 million, mainly related
to additional capital in the Canadian contract drilling segment for
the previously noted additional telescopic ELR double drilling rig,
which is expected to be commissioned in the first quarter of 2014,
and capital related to re-commissioning and upgrading a single
drilling rig for oil sands work in Northern Alberta with one of Western's largest
customers. The re-commissioning of the single drilling rig is
expected to be completed by the end of 2013. The increase in
expansion capital has been partially offset by the cancellation of
previously budgeted capital items related to spare equipment.
Western will continue to take a conservative approach to capital
spending and will make appropriate adjustments to the capital
program as required. Currently, Western expects approximately
$15 million of its capital spending
to carry over into 2014.
Approved capital spending for 2013 in the
contract drilling segment totals $105
million and consists of $88
million in expansion capital, $11
million in maintenance capital and $6
million in critical spare equipment. Budgeted
expansion capital in the contract drilling segment mainly relates
to Western's drilling rig build program, capital to increase our
drilling rig fleet's pumping capacity in Canada, as well as the addition of moving
systems on select drilling rigs in the
United States and additional drill pipe and other drilling
equipment. Budgeted maintenance capital in the contract
drilling segment includes additional drilling equipment, drill pipe
and equipment recertifications.
In the production services segment, which
includes both well servicing and oilfield equipment rentals,
approved capital spending for 2013 totals $12 million and consists of $10 million in expansion capital and $2 million in maintenance capital. Budgeted
expansion capital in the production services segment mainly relates
to the completion of Eagle's well servicing rig build program and
the purchase of additional oilfield rental equipment for
AERO. During the third quarter of 2013, as part of the 2013
capital plan, AERO expanded and opened a field office in
Grande Prairie, Alberta to serve
northern Alberta and northeast
British Columbia. AERO's
main operating base is located in Red
Deer, Alberta.
Western expects to finance its 2013 capital
expenditure budget substantially from operating cash flows while
maintaining our well-structured balance sheet in 2013 thereby
positioning the Company for future opportunities.
During 2013, the price for crude oil has
improved with the three and nine months ended September 30, 2013 Edmonton Par price increasing
by 24% and 10% respectively, as compared to the same periods in the
prior year. Natural gas prices have also improved; although
they remain low by historical standards, the three and nine months
ended September 30, 2013 AECO 30-day
spot rate increased on average by 10% and 35% respectively, as
compared to the same periods in the prior year. With an
increase in oilfield services activity in the second half of 2013,
the Company expects utilization in 2013, as compared to 2012, to
remain relatively consistent in the Canadian contract drilling
segment with higher utilization expected in the United States contract drilling segment
and in Western's production services segment. Additionally,
Western continues to believe oilfield services activity in 2014 and
beyond will improve, and additional rig build opportunities in the
contract drilling segment will be available, as liquefied natural
gas projects gain approval, crude oil transportation capacity
increases through rail and pipeline development, drilling activity
increases in the Duvernay and
Montney resource plays in
Alberta and northeast British Columbia, and as foreign investment
continues to flow into Canada. Currently, the largest
challenges facing the oilfield services industry are producer
spending constraints, pricing differentials on Canadian crude oil,
historically low natural gas prices, and the challenge to attract
and retain skilled labour. The Company believes Western's
modern drilling and well servicing rig fleet and corporate culture
will provide a distinct advantage in retaining and attracting
qualified individuals. Western is of the view, that its
modern fleet, strong customer base and solid reputation provide a
competitive advantage which will enable the Company to continue its
growth strategy and higher than industry average utilization.
Quarterly Dividend
On October 30,
2013, Western's Board of Directors declared a quarterly
dividend of $0.075 per share, which
will be paid on January 14, 2014, to
shareholders of record at the close of business on December 31, 2013. The dividends are
eligible dividends for Canadian income tax purposes. On a
prospective basis, the declaration of dividends will be determined
on a quarter-by-quarter basis by the Board of Directors.
Credit Facility Extension
Subsequent to September
30, 2013, Western extended the maturity date on its
$125.0 million extendible revolving
credit facility to October 18,
2017. There were no other material changes to the
terms of the revolving credit facility.
Financial Measures Reconciliations
Western uses certain measures in this press
release which do not have any standardized meaning as prescribed by
International Financial Reporting Standards ("IFRS"). These
measures which are derived from information reported in the
condensed consolidated statements of operations and comprehensive
income may not be comparable to similar measures presented by other
reporting issuers. These measures have been described and
presented in this press release in order to provide shareholders
and potential investors with additional information regarding the
Company.
Operating Revenue
Management believes that in addition to revenue,
Operating Revenue is a useful supplemental measure as it provides
an indication of the revenue generated by Western's principal
operating activities, excluding third party charges.
The following table provides a reconciliation of
revenue under IFRS as disclosed in the condensed consolidated
statements of operations and comprehensive income to Operating
Revenue:
|
|
|
|
|
|
Three months ended
Sept 30 |
|
Nine months ended
Sept 30 |
(stated in thousands) |
2013 |
2012 |
|
2013 |
2012 |
Operating Revenue |
|
|
|
|
|
|
Drilling |
69,499 |
63,952 |
|
193,715 |
204,616 |
|
Production services |
27,003 |
1,047 |
|
40,877 |
1,785 |
|
Less: inter-company eliminations |
(29) |
- |
|
(29) |
- |
|
96,473 |
64,999 |
|
234,563 |
206,401 |
Third party charges |
4,916 |
4,574 |
|
15,667 |
18,878 |
Revenue |
101,389 |
69,573 |
|
250,230 |
225,279 |
|
|
|
|
|
|
Gross Margin
Management believes that in addition to net
income, Gross Margin is a useful supplemental measure as it
provides an indication of the results generated by Western's
principal operating activities prior to considering administrative
expenses, depreciation and amortization, how those activities are
financed, the impact of foreign exchange, how the results are
taxed, how funds are invested, and how non-cash items and one-time
gains and losses affect results.
EBITDA
Management believes that in addition to net
income, earnings before interest and finance costs, taxes,
depreciation and amortization, other non-cash items and one-time
gains and losses ("EBITDA") is a useful supplemental measure as it
provides an indication of the results generated by the Company's
principal operating segments similar to Gross Margin but also
factors in the cash administrative expenses incurred in the
period.
Operating Earnings
Management believes that in addition to net
income, Operating Earnings is a useful supplemental measure as it
provides an indication of the results generated by the Company's
principal operating segments similar to EBITDA but also factors in
the depreciation expense charged in the period.
The following table provides a reconciliation of net income
under IFRS as disclosed in the condensed consolidated statements of
operations and comprehensive income to Gross Margin, EBITDA and
Operating Earnings:
|
|
|
|
|
|
|
Three months ended
Sept 30 |
|
Nine months ended
Sept 30 |
(stated in thousands) |
2013 |
2012 |
|
2013 |
2012 |
|
|
|
|
|
|
Gross Margin |
37,547 |
29,382 |
|
94,579 |
93,703 |
Add (subtract): |
|
|
|
|
|
|
Administrative expenses |
(8,116) |
(5,965) |
|
(22,968) |
(17,837) |
|
Depreciation - administrative |
347 |
234 |
|
1,086 |
606 |
|
Stock based compensation - administrative |
519 |
293 |
|
1,183 |
1,078 |
EBITDA |
30,297 |
23,944 |
|
73,880 |
77,550 |
|
Depreciation - operating |
(13,262) |
(8,218) |
|
(31,785) |
(22,823) |
|
Depreciation - administrative |
(347) |
(234) |
|
(1,086) |
(606) |
Operating Earnings |
16,688 |
15,492 |
|
41,009 |
54,121 |
|
Stock based compensation - operating |
(271) |
(126) |
|
(643) |
(384) |
|
Stock based compensation - administrative |
(519) |
(293) |
|
(1,183) |
(1,078) |
|
Finance costs |
(4,149) |
(3,169) |
|
(11,903) |
(9,200) |
|
Other items |
(175) |
(477) |
|
(133) |
(173) |
|
Income taxes |
(3,647) |
(3,176) |
|
(7,698) |
(11,200) |
Net income |
7,927 |
8,251 |
|
19,449 |
32,086 |
|
|
|
|
|
|
2013 Third Quarter Results Conference Call
and Webcast
Western has scheduled a conference call and
webcast to begin promptly at 12:00 p.m.
MST (2:00 p.m. EST) on
October 31, 2013.
The conference call dial-in number is
1-888-231-8191.
A live webcast of the conference call will be
accessible on Western's website at www.wesc.ca by selecting
"Investors", then "Webcasts". Shortly after the
live webcast, an archived version will be available for
approximately 14 days.
An archived recording of the conference call
will also be available approximately one hour after the completion
of the call until November 14, 2013
by dialing 1-855-859-2056 or 1-416-849-0833, passcode 82899652.
Forward-Looking Statements and Information
This press release contains certain statements
or disclosures relating to Western that are based on the
expectations of Western as well as assumptions made by and
information currently available to Western which may constitute
forward-looking information under applicable securities laws.
All such statements and disclosures, other than those of historical
fact, which address activities, events, outcomes, results or
developments that Western anticipates or expects may, or will occur
in the future (in whole or part) should be considered
forward-looking information. In some cases forward-looking
information can be identified by terms such as "forecast",
"future," "may", "will", "expect", "anticipate,", "believe",
"potential", "enable", "plan", "continue", "contemplate",
"pro-forma", or other comparable terminology.
In particular, forward-looking information in
this press release includes, but is not limited to, statements
relating to, future dividends; the demand for Company's services
and equipment; the terms of existing and future drilling contracts
in Canada and the US; the
Company's expansion and maintenance capital plans for the remainder
of 2013 and into 2014, and the Company's expected sources of
funding to support such capital plans; the Company's expected
utilization for its contract drilling and production services
divisions; industry activity levels and pricing; and commodity
pricing.
Although Western believes that the expectations
and assumptions on which such forward-looking statements and
information are based are reasonable, undue reliance should not be
placed on the forward-looking statements and information as Western
cannot give any assurance that they will prove to be correct.
Since forward-looking statements and information address future
events and conditions, by their very nature they involve inherent
risks and uncertainties. Actual results could differ
materially from those currently anticipated due to a number of
factors and risks. These include, but are not limited to,
general industry, economic, market and business conditions.
Readers are cautioned that the foregoing list of risks,
uncertainties and assumptions are not exhaustive. Additional
information on these risks, uncertainties, assumptions and other
risk factors that could affect Western's operations and financial
results are included in Western's annual information form which may
be accessed through the SEDAR website at www.sedar.com. The
forward-looking statements and information contained in this press
release are made as of the date hereof and Western does not
undertake any obligation to update publicly or revise any
forward-looking statements and information, whether as a result of
new information, future events or otherwise, unless so required by
applicable securities laws.
SOURCE Western Energy Services Corp.