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CALGARY, ALBERTA--(Marketwired - July 24, 2014) -
(Canadian dollars except as indicated)
This news release contains "forward-looking information and statements" within the meaning of applicable securities laws. For a full disclosure of the forward-looking information and statements and the risks to which they are subject, see the "Cautionary Statement Regarding Forward-Looking Information and Statements" later in this news release.
The Board of Directors of Precision Drilling Corporation PD PDS ("Precision" or the "Corporation") has declared a dividend on its common shares of $0.06 per common share, payable on August 20, 2014, to shareholders of record on August 8, 2014. For Canadian income tax purposes, all dividends paid by Precision on its common shares are designated as "eligible dividends", unless otherwise indicated by Precision.
We recorded a net loss this quarter of $7 million, or loss per diluted share of $0.02, compared to net earnings of $0.5 million, or $0.00 per diluted share, in the second quarter of 2013. Effective January 1, 2014 we began calculating depreciation on our drilling rigs and service rigs on a straight-line basis which reduced net earnings for the quarter by approximately $14 million or $0.05 per diluted share compared with what net earnings would have been using the previous depreciation method.
Revenue this quarter was $475 million or 25% higher than the second quarter of 2013, mainly due to higher pricing and drilling activity in the U.S. and internationally along with higher drilling activity in Canada.
Earnings before income taxes, finance charges, foreign exchange, and depreciation and amortization (adjusted EBITDA) this quarter were $130 million or 47% higher than the second quarter of 2013. Our activity for the quarter, as measured by drilling rig utilization days, increased 33% in Canada, 16% in the U.S. and 18% internationally, compared to the second quarter of 2013. Our adjusted EBITDA margin was 27% this quarter, compared to 23% in the second quarter of 2013. The increase in adjusted EBITDA margin was mainly due to increases in activity and profitability in our Contract Drilling Services segment partially offset by increases in share based compensation accruals, which were $14 million this quarter. EBITDA margin in our Completion and Production Services segment increased 4 percentage points over the prior year, while activity as measured by service rig hours was down 1%.
Net earnings for the first six months of 2014 were $94 million, or $0.32 per diluted share, compared to net earnings of $94 million, or $0.33 per diluted share in 2013, while revenue was $1,147 million, or 18% higher than in 2013. The impact of the change in calculating depreciation on our drilling and service rigs reduced net earnings by approximately $17 million or $0.06 per diluted share compared with what net earnings would have been using the previous depreciation method.
We are increasing our 2014 capital plan from $833 million to $934 million in response to strong customer demand for Precision new-build Super Series rigs. Today we are announcing firm customer commitments on an additional 13 new-build rigs consisting of two additional deliveries in 2014 and 11 additional deliveries in 2015. We are expanding our long-lead program to shorten construction times for new-build rigs that will provide capacity of three rig deliveries per month starting this October and as many as four rigs per month to start 2015 if U.S., Canadian and international customer demand continues at the current pace. With today's announcement, the number of new-build deliveries scheduled for Precision in 2014 totals 18 rigs (eight in the U.S., seven in Canada and three internationally). For 2015 deliveries, we have announced contracts or firm customer commitments for 16 new-build rigs (15 for the U.S. and one for Kuwait).
Kevin Neveu, Precision's President and Chief Executive Officer, stated: "It is rewarding to see Precision's investment in Super Series rigs deliver record revenue and EBITDA during the second quarter. The superior full cycle pricing performance of these rigs and our High Performance, High Value strategy is evidenced in our premium dayrates, improving margins and best confirmed by the strong customer demand for rig contracts. Precision now has firm customer commitments for 12 new-build rigs to be delivered in the second half of 2014 and 16 new-build rigs in 2015 with deliveries stretching into September of next year."
"Precision's recently announced technology and service agreement and marketing alliance with Schlumberger will serve to enhance the efficiency and performance of our directional drilling operations. I am particularly excited to have the full range of technology to combine with our Super Series rigs. This integrated service offering will create a meaningful value proposition for our customers and further reinforce our competitive advantage."
"Our U.S. drilling operations continued its recent momentum during the quarter with dayrates and margins increasing $470 and $1,880, respectively from the second quarter of 2013 and increasing $174 and $1,167, respectively from the first quarter of 2014. Our drilling activity remains strong with an average of 93 rigs operating this past quarter compared to an average of 80 in the second quarter of last year. Today's active rig count of 96 rigs and scheduled new-build and upgrade deliveries point to higher activity in the second half of the year if commodity prices remain at or near current levels."
"In Canada, our second quarter drilling activity was at the highest level since the second quarter of 2006 averaging 53 rigs, up 13 rigs over the second quarter last year. Our higher activity levels had a positive effect on our margins, which were up over $1,700 per day, while our dayrates were relatively flat versus the second quarter of 2013. The strong activity level for the spring break-up period reflects our recent fleet enhancements, including additional pad capable rigs, and was supported by more favourable weather than last year. Most encouragingly during the quarter, we saw strong customer demand that steadily increased into the beginning of the third quarter. Today's active rig count in Canada is 95 rigs and we expect our activity levels in the latter half of the year to be supported by five scheduled new-build deliveries and multiple upgraded rigs. Longer term we have our eyes on LNG development in Canada where we continue to see signs that development is likely. We expect to be a key player in developing this important energy resource."
"We continue to make progress in our international business with two recent deployments to Kuwait and two additional announced international deployments, one to the Kingdom of Saudi Arabia later this year and one to Kuwait in the middle of 2015. Once these deployments are completed we expect to have nine rigs operating in the Middle East with the scale much closer to the level necessary to generate returns similar to those we are used to in North America. In Mexico, we have four rigs running that were recently signed to long-term contracts and are pleased with that integrated project management work. Currently, we are moving two idle rigs from Mexico to the U.S. where we have secured contracted work."
"Our Completion and Production business continues to face market demand challenges as customer spending on workover of existing wells continue to lag drilling activity. We are confident this lower demand level will not persist and when the market turns, Precision will remain well positioned to take advantage of the opportunity."
"The continued success of Precision will be measured by our ability to execute in the field and our interaction with customers. We will build on our highly skilled employee base and support systems with continued investment in our workforce and management of our assets. Along these lines, we have seen an increase in utilization of our Houston Tech Centre and expect to open our new Nisku Centre later this fall."
"We are encouraged by the results Precision continues to report and the direction of our company within the industry. Most importantly, we are pleased with the size and performance of our Tier 1 drilling fleet, the geographic breadth of our operations and both oil and natural gas creating demand for our services. Our established position is generating robust operating cash flow and presenting a number of high return investment opportunities for future growth. With today's dividend announcement, Precision has declared approximately $125 million in dividends to shareholders since December 2012."
SELECT FINANCIAL AND OPERATING INFORMATION
Adjusted EBITDA and funds provided by operations are additional GAAP measures. See "ADDITIONAL GAAP MEASURES".
Financial Highlights
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Three months ended June 30, Six months ended June 30,
(Stated in thousands
of Canadian dollars,
except per share % %
amounts) 2014 2013 Change 2014 2013 Change
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Revenue 475,174 378,898 25.4 1,147,423 974,618 17.7
Adjusted EBITDA 129,695 88,248 47.0 366,969 303,429 20.9
Adjusted EBITDA % of
revenue 27.3% 23.3% 32.0% 31.1%
Net earnings (loss) (7,174) 473 n/m 94,383 93,786 0.6
Cash provided by
operations 228,412 182,345 25.3 398,539 245,293 62.5
Funds provided by
operations 97,805 33,791 189.4 329,198 178,473 84.5
Capital spending:
Expansion 117,654 81,788 43.9 185,839 158,303 17.4
Upgrade 25,593 34,117 (25.0) 45,450 71,658 (36.6)
Maintenance and
infrastructure 31,607 20,332 55.5 49,564 36,881 34.4
Proceeds on sale (9,979) (4,148) 140.6 (17,236) (6,686) 157.8
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Net capital spending 164,875 132,089 24.8 263,617 260,156 1.3
Earnings (loss) per
share:
Basic (0.02) 0.00 n/m 0.32 0.34 (5.9)
Diluted (0.02) 0.00 n/m 0.32 0.33 (3.0)
Dividends paid per
share 0.06 0.05 20.0 0.12 0.10 20.0
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n/m - calculation not meaningful
Operating Highlights
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Three months ended June 30, Six months ended June 30,
2014 2013 % Change 2014 2013 % Change
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Contract drilling rig
fleet 333 324 2.8 333 324 2.8
Drilling rig
utilization days:
Canada 4,805 3,606 33.3 16,189 14,707 10.1
U.S. 8,490 7,320 16.0 16,963 14,598 16.2
International 962 815 18.0 1,952 1,534 27.2
Service rig fleet 221 219 0.9 221 219 0.9
Service rig operating
hours 51,270 51,677 (0.8) 133,834 141,069 (5.1)
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Financial Position
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(Stated in thousands of Canadian dollars, June 30, December 31,
except ratios) 2014 2013
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Working capital 746,261 305,783
Long-term debt(1) 1,716,314 1,323,268
Total long-term financial liabilities 1,752,815 1,355,535
Total assets 5,061,476 4,579,123
Long-term debt to long-term debt plus equity
ratio(1) 0.41 0.36
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(1) Net of unamortized debt issue costs.
Revenue this quarter was $475 million, or 25% higher than the second quarter of 2013. The increase, of $96 million, was primarily due to a year-over-year increase in activity and rates from our contract drilling operations. Revenue from our Contract Drilling Services and Completion and Production Services segments both increased over the comparative prior year period by 26% and 20%, respectively.
During the quarter we issued US$400 million of 5.25% Senior Notes due in 2024 (the "Notes") in a private offering. The Notes are guaranteed on a senior unsecured basis by current and future U.S. and Canadian subsidiaries that also guarantee our revolving credit facility and certain other indebtedness. We expect to use the net proceeds from this placement for general corporate purposes, including building new drilling rigs.
Our portfolio of term customer contracts, a scalable operating cost structure and economies achieved through vertical integration of the supply chain all help us manage our adjusted EBITDA margin.
Precision's strategic priorities are as follows:
1. Execute our High Performance, High Value strategy - Invest in
Precision's physical and human capital infrastructure to advance field
level professional development, provide industry leading service to
customers and promote safe operations. Continue to measure and benchmark
performance with a view to exceeding the high standards we set.
The construction of our Nisku Centre is underway and we expect to
complete construction in the fall of this year. Our Nisku Centre will
support safety and training for our Canadian workforce.
We recently entered into a technology and service agreement and
marketing alliance with Schlumberger that enables us to market a full
range of directional drilling downhole tools to our customers,
significantly enhancing our technology and service offering to
customers.
2. Leverage our scale in operations - Utilize established systems to
promote consistent and reliable service and to improve operating
efficiencies across all geographies and service lines.
We have demonstrated our ability to increase activity levels while
driving down daily operating cost per rig in our operations.
Additionally, we have increased the utilization of our centralized U.S.
repair and maintenance facilities at our Houston Tech Centre.
3. Execute on existing organic growth opportunities - Deliver new-build and
upgraded rigs to customer contracts, expand international activity in
existing operating regions and grow our Canadian LNG drilling leadership
position. Be a recognized leader in the integrated directional drilling
transformation.
We have announced delivery or planned delivery for 18 new-build rigs in
2014, including six ST-1500 rigs for deep basin and LNG related drilling
in Canada. In addition, we have contracted two new-build rigs for the
Middle East and four existing rigs to long-term contracts for integrated
project management projects in Mexico and began operations with the two
Kuwait new-build rigs near the end of the second quarter. In addition,
we now have signed contracts or firm customer commitments for delivery
of 16 new build rigs in 2015.
4. Increase returns for our investors.
We remain well positioned to increase returns for investors with our
continued strong activity levels and margins, favourable contracted
terms on new-build and upgraded rigs and our low cost and flexible
capital structure.
For the second quarter of 2014, the average natural gas prices and the West Texas Intermediate price of oil were higher than the 2013 averages.
Year ended
Three months ended June 30, Dec 31,
2014 2013 2013
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Average oil and natural gas
prices
Oil
West Texas Intermediate (per
barrel) (US$) 103.14 94.16 98.02
Natural gas
Canada
AECO (per MMBtu) (Cdn$) 4.69 3.53 3.18
U.S.
Henry Hub (per MMBtu) (US$) 4.58 4.01 3.73
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Summary for the three months ended June 30, 2014:
-- As a result of our annual review of the estimated useful lives and
method of depreciation for our property, plant and equipment, effective
January 1, 2014 we are calculating depreciation on our drilling rigs and
service rigs on a straight-line basis. Existing assets were assessed for
their remaining useful lives and are being depreciated prospectively on
a straight-line basis. New drilling rigs will be depreciated based on
the expected life of individual asset components with an approximate
weighted average life of 15 years and approximately 7% salvage value.
New service rigs will be depreciated based on the expected life of the
asset component with an approximate weighted average life of 20 years
with approximately 10% salvage value. The move to straight-line reflects
the demand for technologically advanced assets which are expected to
depreciate over time rather than on a per unit basis. The use of
straight-line depreciation will result in idle assets being more
aggressively depreciated. In the second quarter of 2014 depreciation
expense calculated using the straight-line method with revised asset
life expectancy was $106 million. Had we continued to depreciate assets
using units of production, depreciation would have been $86 million. The
estimated additional depreciation expense for the year ending December
31, 2014 from this change is approximately $45 million.
-- Operating earnings (see "Additional GAAP Measures" in this news release)
this quarter were $24 million, or 5% of revenue, compared to $16 million
and 4% of revenue in 2013. Operating earnings were positively impacted
by the increase in drilling activity and dayrates in our contract
drilling rig operations partially offset by an increase in depreciation
from moving to the straight-line method and the depreciation on asset
additions.
-- General and administrative expenses this quarter were $41 million, $9
million higher than the second quarter of 2013. The increase is
primarily due to higher costs associated with incentive compensation
which are tied to the price of our common shares.
-- Net finance charges were $26 million, an increase of $2 million compared
with the second quarter of 2013 due to the issuance of US$400 million of
5.25% Senior Notes on June 3, 2014.
-- Average revenue per utilization day for contract drilling rigs decreased
slightly in the second quarter of 2014 to $22,217 from the prior year
second quarter of $22,276 in Canada and increased in the U.S. to
US$24,320 from US$23,850. The decrease in revenue rates for Canada is
primarily due to rig mix and competitive pricing in some rig segments
during spring break-up, partially offset by additional Tier 1 and
upgraded rigs entering the fleet compared to the prior year quarter. In
Canada, for the second quarter of 2014, 53% of our utilization days were
achieved from drilling rigs working under term contracts compared to 50%
in the 2013 comparative period. The increase in revenue rates for the
U.S. is primarily due to additional Tier 1 and upgraded rigs entering
the fleet compared to the prior year quarter. In the U.S., for the
second quarter of 2014, 72% of our utilization days were generated from
rigs working under term contracts compared to 58% in the 2013
comparative period. Turnkey revenue for the second quarter of 2014 was
US$20 million compared with US$18 million in the 2013 comparative
period. Within the Completion and Production Services segment, average
hourly rates for service rigs were $961 in the second quarter of 2014
compared to $842 in the second quarter of 2013. The increase in the
average hourly rate is the result of rig mix with the introduction of
coil tubing rigs in the U.S., which command a higher average hourly
rate. Canadian well servicing rig average hourly rate increased by $58
per hour from the second quarter of 2014 compared with the 2013
comparative period.
-- Average operating costs per utilization day for drilling rigs decreased
in the second quarter of 2014 to $11,695 from the prior year second
quarter of $13,497 in Canada while in the U.S. costs decreased to
US$13,502 in 2014 from US$14,912 in 2013. The cost decrease in Canada
was primarily due to lower labour burden, lower repairs and maintenance
expenditures, and a larger activity base to spread fixed costs. The cost
decrease in the U.S. was primarily due to labour efficiencies, reduction
in labour related costs and a larger activity base to spread fixed
costs. Within the Completion and Production Services segment, average
hourly operating costs for service rigs increased to $679 in the second
quarter of 2014 as compared to $627 in the second quarter of 2013
primarily due to costs associated with coil tubing.
-- Precision realized revenue from international contract drilling of $46
million in the second quarter of 2014, a $17 million increase over the
prior year period.
-- Directional drilling services realized revenue of $23 million in the
second quarter of 2014 compared with $27 million in the prior year
period.
-- Funds provided by operations in the second quarter of 2014 were $98
million, an increase of $64 million from the prior year comparative
quarter of $34 million. The increase was primarily the result of
improved operations and a decrease in income tax installments paid.
-- Capital expenditures for the purchase of property, plant and equipment
were $175 million in the second quarter, an increase of $39 million over
the same period in 2013. Capital spending for the second quarter of 2014
included $118 million for expansion capital, $26 million for upgrade
capital and $32 million for the maintenance of existing assets and
infrastructure spending.
Summary for the six months ended June 30, 2014:
-- Revenue for the first half of 2014 was $1,147 million, an increase of
18% from the 2013 period.
-- For the first half of 2014 depreciation expense calculated using the
straight-line method with revised asset life expectancy was $212
million. Had we continued to depreciate assets using units of
production, depreciation would have been $187 million.
-- Operating earnings were $155 million, an increase of $9 million or 6%
from 2013. Operating earnings were 14% of revenue in 2014 compared to
15% in 2013. Operating earnings were positively impacted by the increase
in drilling activity and rates in our contract drilling rig operations
partially offset by an increase in depreciation from moving to the
straight-line method and the depreciation on asset additions.
-- General and administrative costs were $81 million, an increase of $10
million over the first half of 2013 primarily as a result of the
increase in incentive compensation costs tied to the performance of
Precision's common shares in 2014.
-- Net finance charges were $50 million, an increase of $3 million from the
first half of 2013. During the quarter we issued US$400 million of 5.25%
Senior Notes.
-- The change in depreciation calculation added approximately $25 million
to our depreciation expense over the prior period.
-- Funds provided by operations (see "Additional GAAP Measures" in this
news release) in the first half of 2014 were $329 million, an increase
of $151 million from the prior year comparative period of $178 million.
-- Capital expenditures for the purchase of property, plant and equipment
were $281 million in the first half of 2014, an increase of $14 million
over the same period in 2013. Capital spending for 2014 to date included
$186 million for expansion capital, $45 million for upgrade capital and
$50 million for the maintenance of existing assets and infrastructure.
OUTLOOK
Contracts
Our portfolio of term customer contracts provides a base level of activity and revenue and, as of July 23, 2014, we had term contracts in place for an average of 48 rigs in Canada, 51 in the U.S. and 11 internationally for the third quarter of 2014 and an average of 52 rig contracts in Canada, 51 in the U.S. and 11 internationally for the full year. In Canada, term contracted rigs normally generate 250 utilization days per year because of the seasonal nature of well site access. In most regions in the U.S. and internationally, term contracts normally generate 365 utilization days per year.
Drilling Activity
In the U.S., our average active rig count in the quarter was 93 rigs, up 13 rigs over the second quarter in 2013 and in line with the first quarter of 2014. We currently have 96 rigs active in the U.S.
In Canada, our average active rig count in the quarter was 53 rigs, an increase of 13 over the second quarter in 2013. We currently have 95 rigs active in Canada and expect typical seasonal volatility through the third quarter but in general we expect to benefit from the fleet enhancements over the past several years and the delivery of five contracted new-build rigs and several contracted upgrade rigs in the second half of this year.
Internationally, our average active rig count in the quarter was 11 rigs, up two rigs over the second quarter in 2013 and in line with the first quarter of 2014. During the quarter two new-build rigs went to work in Kuwait and both were operating at the end of the quarter. We currently have 11 rigs active internationally and expect delivery of two new-build rigs for the Middle East, one to begin operations in the Kingdom of Saudi Arabia in late 2014 and the other to begin operations in Kuwait in mid-2015. In Mexico, the four recently signed rigs for integrated project management contracts have all begun working while two rigs are currently idle. Two rigs are currently moving from Mexico back to the U.S. to work under contract.
Industry Conditions
To date in 2014, drilling activity has increased relative to this time last year for both Canada and the U.S. According to industry sources, as of July 18, 2014, the U.S. active land drilling rig count was up approximately 6% from the same point last year and the Canadian active land drilling rig count was up approximately 18%. The increase in the North American rig count has been driven by demand for Tier 1 assets, which continues to be strong, benefiting drilling contractors, like Precision, with a high percentage of Tier 1 assets.
Canada has been experiencing an increase in natural gas and gas liquids drilling activity related to deep basin drilling in northwestern Alberta and northeastern British Columbia while the trend towards oil-directed drilling in the U.S. continues. To date in 2014, approximately 60% of the Canadian industry's active rigs and 82% of the U.S. industry's active rigs were drilling for oil targets, compared to 71% for Canada and 78% for the U.S. at the same time last year.
Capital Spending
Capital spending in 2014 is expected to be $934 million:
-- The 2014 capital expenditure plan includes $561 million for expansion
capital, $199 million for sustaining and infrastructure expenditures,
and $174 million to upgrade existing rigs. We expect that the $934
million will be split $894 million in the Contract Drilling segment and
$40 million in the Completion and Production Services segment.
-- Precision's expansion capital plan for 2014 includes 18 new-build
drilling rigs delivered in 2014 including seven for Canada, eight for
the U.S., and three for the Middle East.
The seven rigs for Canada include six Super Triple rigs for northern gas
and gas liquids drilling and one Precision Super Single for heavy oil
development drilling. The U.S. new-builds consist of eight ST-1500 rigs.
Internationally in Kuwait two ST-3000 rigs began operations in the
second quarter with an additional new-build contracted rig, an ST-2000
expected to be deployed to the Kingdom of Saudi Arabia late in 2014 and
an ST-1500 expected to be deployed in Kuwait in mid-2015.
The majority of the remainder of the expansion capital is allocated to
long-lead items which we anticipate using for new-build drilling rigs
for delivery in 2015.
Following is a new-build delivery schedule for deliveries in the first
half of 2014 and expected deliveries in the second half of 2014 and full
year 2015 where we have either a long-term contract or a firm customer
commitment for a long-term contract.
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2014 2015
Q1 Q2 Q3 Q4 Total Q1 Q2 Q3 Q4 Total
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Rig Deliveries
Canada 2 - 1 4 7 - - - - -
U.S. 1 1 1 5 8 6 7 2 - 15
International - 2 - 1 3 - 1 - - 1
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3 3 2 10 18 6 8 2 - 16
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-- The 2014 capital plan includes approximately 20 rig upgrades and will
vary depending on scope of the upgrades.
-- Precision's sustaining and infrastructure capital plan is based upon
currently anticipated activity levels for 2014 and includes a technical
and operational support centre in Nisku, Alberta along with regional
support facilities and corporate systems. The Nisku Centre consolidates
Precision's existing operations and technical support centres and will
contain a new employee training centre complete with a fully functioning
training rig equipped with the latest drilling technology. The centre is
expected to support Canadian operations for several decades, provide
increased capacity and efficiency, and ensure that we continue to
deliver services with highly skilled and well trained field personnel.
This centre accounts for approximately $30 million of the 2014 capital
expenditure plan.
SEGMENTED FINANCIAL RESULTS
Precision's operations are reported in two segments: the Contract Drilling Services segment which includes the drilling rig, directional drilling, oilfield supply and manufacturing divisions; and the Completion and Production Services segment which includes the service rig, snubbing, coil tubing, rental, camp and catering and wastewater treatment divisions.
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Three months ended June 30, Six months ended June 30,
(Stated in thousands
of Canadian % %
dollars) 2014 2013 Change 2014 2013 Change
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Revenue:
Contract Drilling
Services 410,882 327,336 25.5 982,804 823,574 19.3
Completion and
Production
Services 66,508 55,420 20.0 169,573 159,008 6.6
Inter-segment
eliminations (2,216) (3,858) (42.6) (4,954) (7,964) (37.8)
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475,174 378,898 25.4 1,147,423 974,618 17.7
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Adjusted EBITDA:(1)
Contract Drilling
Services 148,491 101,555 46.2 388,189 308,760 25.7
Completion and
Production
Services 5,137 2,293 124.0 24,590 32,408 (24.1)
Corporate and
other (23,933) (15,600) 53.4 (45,810) (37,739) 21.4
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129,695 88,248 47.0 366,969 303,429 20.9
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(1) See "ADDITIONAL GAAP MEASURES".
SEGMENT REVIEW OF CONTRACT DRILLING SERVICES
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Three months ended June 30, Six months ended June 30,
(Stated in thousands
of Canadian dollars,
except where noted) 2014 2013 % Change 2014 2013 % Change
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Revenue 410,882 327,336 25.5 982,804 823,574 19.3
Expenses:
Operating 249,937 213,320 17.2 568,844 490,366 16.0
General and
administrative 12,454 12,461 (0.1) 25,771 24,448 5.4
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Adjusted EBITDA(1) 148,491 101,555 46.2 388,189 308,760 25.7
Depreciation 92,365 63,398 45.7 184,476 137,109 34.5
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Operating earnings(1) 56,126 38,157 47.1 203,713 171,651 18.7
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Operating earnings as
a percentage of
revenue 13.7% 11.7% 20.7% 20.8%
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Drilling rig revenue
per utilization day
in Canada 22,217 22,276 (0.3) 22,608 22,293 1.4
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Drilling rig revenue
per utilization day
in the U.S.(2)(US$) 24,320 23,850 2.0 24,235 23,920 1.3
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(1) See "ADDITIONAL GAAP MEASURES".
(2) Includes revenue from idle but contracted rig days and lump sum payouts
in 2013.
Three months ended June 30,
Canadian onshore drilling
statistics:(1) 2014 2013
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Precision Industry(2) Precision Industry(2)
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Number of drilling rigs (end
of period) 189 810 188 820
Drilling rig operating days
(spud to release) 4,312 18,293 3,213 13,579
Drilling rig operating day
utilization 25% 25% 19% 18%
Number of wells drilled 393 1,430 371 1,162
Average days per well 11.0 12.8 8.7 11.7
Number of metres drilled
(000s) 793 3,430 707 2,604
Average metres per well 2,018 2,399 1,905 2,241
Average metres per day 184 188 220 192
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Six months ended June 30,
Canadian onshore drilling
statistics:(1) 2014 2013
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Precision Industry(2) Precision Industry(2)
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Number of drilling rigs (end
of period) 189 810 188 820
Drilling rig operating days
(spud to release) 14,366 63,070 13,002 56,877
Drilling rig operating day
utilization 42% 43% 38% 39%
Number of wells drilled 1,343 4,881 1,426 4,726
Average days per well 10.7 12.9 9.1 12.0
Number of metres drilled
(000s) 2,627 11,090 2,536 9,951
Average metres per well 1,956 2,272 1,779 2,106
Average metres per day 183 176 195 175
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(1) Canadian operations only.
(2) Canadian Association of Oilwell Drilling Contractors ("CAODC"), and
Precision - excludes non-CAODC rigs and non-reporting CAODC members.
United States onshore
drilling statistics:(1) 2014 2013
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Precision Industry(2) Precision Industry(2)
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Average number of active
land rigs for quarters
ended:
March 31 94 1,724 81 1,706
June 30 93 1,802 80 1,710
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Year to date average 94 1,763 81 1,708
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(1) United States lower 48 operations only.
(2) Baker Hughes rig counts.
Revenue from Contract Drilling Services was $411 million this quarter, or 26% higher than the second quarter of 2013, while adjusted EBITDA increased by 46% to $148 million. The increases were mainly due to higher drilling rig utilization days and dayrates in our U.S. and international drilling business and higher utilization days in Canada.
Operating results for our international business improved as we averaged 11 rigs active compared to nine in the prior year comparative quarter. Drilling rig utilization days in our international operations for the quarter were 962, 18% higher than the prior year comparative period.
Drilling rig utilization days in Canada (drilling days plus move days) during the second quarter of 2014 were 4,805, an increase of 33% compared to 2013 while drilling rig utilization days in the U.S. were 8,490, or 16% higher than the same quarter of 2013. The increase in Canadian and U.S. activity was primarily due to strong demand for Tier 1 assets and resulted in market share gains during the second half of 2013. The majority of our North American activity came from oil and liquids-rich natural gas related plays.
Compared to the same quarter in 2013, drilling rig revenue per utilization day was up 2% in the U.S. while Canada was down slightly. The increase in average dayrates for the U.S. was driven by improved rig mix and higher rates for well-to-well and re-contracted rigs. In Canada the $59 per day in dayrate decrease was the result of rig mix during the quarter and competitive pricing in some rig segments during spring break-up partially offset by additional Tier 1 and upgraded rigs entering the fleet compared to the prior year quarter.
In Canada, 53% of utilization days in the quarter were generated from rigs under term contract, compared to 50% in the second quarter of 2013. In the U.S., 72% of utilization days were generated from rigs under term contract as compared to 58% in the second quarter of 2013. At the end of the quarter, we had 54 drilling rigs under contract in Canada, 61 in the U.S. and 11 internationally.
Operating costs were 61% of revenue for the quarter, which was four percentage points lower than the prior year period. On a per utilization day basis, operating costs for the drilling rig division in Canada were down over the prior year primarily because of the impact of fixed costs on higher activity increase, lower labour burden and lower repair and maintenance costs. In the U.S., operating costs for the quarter on a per day basis were down from the second quarter in 2013 primarily as a result of labour efficiencies and reduction in labour related costs.
Depreciation expense in the quarter was 46% higher than in the second quarter of 2013 due to changes in the estimated remaining useful life of our capital equipment, a change to straight-line depreciation and depreciation expense associated with new equipment. The depreciation variance of moving to straight-line depreciation should be most significant in the second quarter due to lower activity in Canada from spring break-up.
SEGMENT REVIEW OF COMPLETION AND PRODUCTION SERVICES
----------------------------------------------------------------------------
Three months ended June 30, Six months ended June 30,
(Stated in thousands
of Canadian dollars,
except where noted) 2014 2013 % Change 2014 2013 % Change
----------------------------------------------------------------------------
Revenue 66,508 55,420 20.0 169,573 159,008 6.6
Expenses:
Operating 56,564 49,307 14.7 135,548 118,205 14.7
General and
administrative 4,807 3,820 25.8 9,435 8,395 12.4
----------------------------------------------------------------------------
Adjusted EBITDA(1) 5,137 2,293 124.0 24,590 32,408 (24.1)
Depreciation 11,433 7,073 61.6 22,861 16,318 40.1
----------------------------------------------------------------------------
Operating earnings(1)
(loss) (6,296) (4,780) 31.7 1,729 16,090 (89.3)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Operating earnings
(loss) as a
percentage of
revenue (9.5%) (8.6%) 1.0% 10.1%
----------------------------------------------------------------------------
Well servicing
statistics:
Number of service
rigs (end of
period) 221 219 0.9 221 219 0.9
Service rig
operating hours 51,270 51,677 (0.8) 133,834 141,069 (5.1)
Service rig
operating hour
utilization 25% 26% 36% 36%
Service rig revenue
per operating
hour(2) 961 842 14.1 920 834 10.3
----------------------------------------------------------------------------
(1) See "ADDITIONAL GAAP MEASURES".
(2) Prior year comparatives have changed to include U.S. based rig activity.
Revenue from Completion and Production Services was up $11 million or 20% compared to the second quarter of 2013, as higher rates and the expansion of services in the U.S was partially offset by lower demand in the Canadian market. Well servicing activity in the second quarter was 1% lower than the second quarter of 2013, as a decrease in Canadian well servicing activity was offset by an increase in the U.S. Approximately 93% of the second quarter Canadian service rig activity was oil related.
Average service rig revenue per operating hour in the second quarter was $961, or $119 higher than the second quarter of 2013. The increase was primarily the result of increased coil tubing and snubbing operations in the current quarter, which operate at higher rates.
Adjusted EBITDA was $3 million higher than the second quarter of 2013 due to higher average rates in both Canada and in the U.S.
Our rental division activity in the quarter was higher than the second quarter of 2013 mainly due to increased drilling activity.
Operating costs as a percentage of revenue decreased to 85% in the second quarter of 2014, from 89% in the second quarter of 2013. Operating costs per service rig operating hour were higher than in the second quarter of 2013 mainly because of the increase in costs associated with the new coil tubing operations.
Depreciation in the second quarter of 2014 was 62% higher than the second quarter of 2013 because of changes in the estimated remaining useful life of our capital equipment, a change to straight-line depreciation and depreciation expense associated with new equipment. The second quarter is generally the period with the most significant variance due to the lower activity in Canada with spring break-up.
SEGMENT REVIEW OF CORPORATE AND OTHER
Our Corporate and Other segment provides support functions to our operating segments. The Corporate and Other segment had an adjusted EBITDA loss of $24 million for the second quarter of 2014, $8 million higher than 2013 comparative period due primarily to share based incentive compensation.
OTHER ITEMS
Net financial charges for the quarter were $26 million, an increase of $2 million from the second quarter of 2013, driven by the impact of the weaker Canadian dollar on the value of our U.S. dollar denominated debt and the issuance of US$400 million 5.25% Senior Notes on June 3, 2014. We had a foreign exchange gain of $0.3 million during the second quarter of 2014 due to the strengthening of the Canadian dollar versus the U.S. dollar, which affected the net U.S. dollar denominated monetary position in the Canadian dollar-based companies.
Income tax expense for the quarter was $6 million compared with a recovery of $4 million in the same quarter in 2013. The increase is due to improved pretax earnings in the current quarter compared to the prior year period. Our effective tax rate on earnings before income taxes for the six months ended June 30, 2014 was 14%.
In June 2013, a wholly owned subsidiary of Precision lost a tax appeal in the Ontario Superior Court of Justice related to a reassessment of Ontario income tax for the subsidiary's 2001 through 2004 taxation years. Precision appealed the decision to the Ontario Court of Appeal and that appeal was heard in May 2014. We expect the Ontario Court of Appeal to render its decision in the second half of 2014. Despite the decision in the Superior Court, management believes it is more likely than not that Precision will prevail on appeal. Should Precision lose on appeal, approximately $55 million of the long-term income tax recoverable related to this issue would be expensed.
LIQUIDITY AND CAPITAL RESOURCES
The oilfield services business is inherently cyclical in nature. To manage this, we focus on maintaining a strong balance sheet so we have the financial flexibility we need to continue to manage our growth and cash flow, no matter where we are in the business cycle.
We apply a disciplined approach to managing and tracking results of our operations to keep costs down. We maintain a variable cost structure so we can be responsive to changes in demand.
Our maintenance capital expenditures are tightly governed by and highly responsive to activity levels with additional cost savings leverage provided through our internal manufacturing and supply divisions. Term contracts on expansion capital for new-build rig programs provide more certainty of future revenues and return on our capital investments.
Liquidity
During the quarter we issued US$400 million of 5.25% Senior Notes due in 2024 in a private offering. The Notes are guaranteed on a senior unsecured basis by current and future U.S. and Canadian subsidiaries that also guarantee our revolving credit facility and certain other indebtedness. We expect to use the net proceeds from this placement for general corporate purposes, including building new drilling rigs.
In addition, we amended our credit agreement governing our revolving credit facility to, among other things, voluntarily reduce the size of the revolving credit facility from US$850 million to US$650 million and extend the maturity to June 3, 2019.
In addition to a cash balance of $576 million as at June 30, 2014, we had available capacity of $718 million under our secured facilities.
As at June 30, 2014 we had $1,748 million outstanding under our senior unsecured notes.
Amount Availability Used for Maturity
----------------------------------------------------------------------------
Senior facility (secured)
----------------------------------------------------------------------------
US$650 million (extendible, Drawn US$26 General June 3, 2019
revolving term credit facility million in corporate
with US$250 million accordion outstanding purposes
feature) letters of
credit
----------------------------------------------------------------------------
Operating facilities (secured)
----------------------------------------------------------------------------
$40 million Undrawn, Letters of
except $16 credit and
million in general
outstanding corporate
letters of purposes
credit
----------------------------------------------------------------------------
US$15 million Undrawn Short term
working
capital
requirements
----------------------------------------------------------------------------
Demand letter of credit facility (secured)
----------------------------------------------------------------------------
US$25 million Undrawn, Letters of
except US$14 credit
million in
outstanding
letters of
credit
----------------------------------------------------------------------------
Senior notes (unsecured)
----------------------------------------------------------------------------
$200 million Fully drawn Debt repayment March 15, 2019
----------------------------------------------------------------------------
US$650 million Fully drawn Debt repayment November 15,
and general 2020
corporate
purposes
----------------------------------------------------------------------------
US$400 million Fully drawn Capital December 15,
expenditures 2021
and general
corporate
purposes
----------------------------------------------------------------------------
US$400 million Fully drawn Capital November 15,
expenditures 2024
and general
corporate
purposes
----------------------------------------------------------------------------
Our secured facility includes financial ratio covenants that are tested quarterly; we are compliant with these covenants and expect to remain compliant.
The current blended cash interest cost of our debt is approximately 6.2%.
Hedge of investments in U.S. operations
We have designated a portion of our U.S. dollar denominated long-term debt as a hedge of our investment in our operations in the U.S. To be accounted for as a hedge, the foreign currency denominated long-term debt must be designated and documented as such and must be effective at inception and on an ongoing basis. We recognize the effective amount of this hedge (net of tax) in other comprehensive income. We recognize ineffective amounts (if any) in earnings.
Average shares outstanding
The following table reconciles the weighted average shares outstanding used in computing basic and diluted earnings per share:
Three months ended Six months ended
June 30, June 30,
2014 2013 2014 2013
----------------------------------------------------------------------------
Weighted average shares outstanding -
basic 292,511 276,617 292,287 276,558
Effect of warrants - 9,425 - 9,486
Effect of stock options and other
equity compensation plans 1,415 814 424 867
----------------------------------------------------------------------------
Weighted average shares outstanding -
diluted 293,926 286,856 292,711 286,911
----------------------------------------------------------------------------
----------------------------------------------------------------------------
QUARTERLY FINANCIAL SUMMARY
(Stated in thousands of Canadian dollars, except per share amounts)
----------------------------------------------------------------------------
2013 2014
----------------------------------------------------------------------------
Quarters ended September 30 December 31 March 31 June 30
----------------------------------------------------------------------------
Revenue 488,450 566,909 672,249 475,174
Adjusted EBITDA(1) 137,660 197,744 237,274 129,695
Net earnings (loss): 29,443 67,921 101,557 (7,174)
Per basic share 0.11 0.24 0.35 (0.02)
Per diluted share 0.10 0.24 0.35 (0.02)
Funds provided by
operations(1) 127,684 155,816 231,393 97,805
Cash provided by
operations 88,341 94,452 170,127 228,412
Dividends paid per share 0.05 0.06 0.06 0.06
----------------------------------------------------------------------------
----------------------------------------------------------------------------
2012 2013
----------------------------------------------------------------------------
Quarters ended September 30 December 31 March 31 June 30
----------------------------------------------------------------------------
Revenue 484,761 533,948 595,720 378,898
Adjusted EBITDA(1) 151,000 177,026 215,181 88,248
Net earnings (loss): 39,357 (116,339) 93,313 473
Per basic share 0.14 (0.42) 0.34 0.00
Per diluted share 0.14 (0.42) 0.33 0.00
Funds provided by
operations(1) 146,124 142,576 144,682 33,791
Cash provided by
operations 61,183 136,317 62,948 182,345
Dividends paid per share - 0.05 0.05 0.05
----------------------------------------------------------------------------
(1) See "ADDITIONAL GAAP MEASURES".
ADDITIONAL GAAP MEASURES
We reference Generally Accepted Accounting Principles (GAAP) measures that are not defined terms under International Financial Reporting Standards to assess performance because we believe they provide useful supplemental information to investors.
Adjusted EBITDA
We believe that adjusted EBITDA (earnings before income taxes, financing charges, foreign exchange, and depreciation and amortization) as reported in the Consolidated Statement of Earnings (Loss) is a useful measure, because it gives an indication of the results from our principal business activities prior to consideration of how our activities are financed and the impact of foreign exchange, taxation and non-cash depreciation and amortization charges.
Operating Earnings
We believe that operating earnings, as reported in the Consolidated Statements of Earnings (Loss), is a useful measure because it provides an indication of the results of our principal business activities before consideration of how those activities are financed and the impact of foreign exchange and taxation.
Funds Provided by Operations
We believe that funds provided by operations, as reported in the Consolidated Statements of Cash Flow is a useful measure because it provides an indication of the funds our principal business activities generate prior to consideration of working capital, which is primarily made up of highly liquid balances.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION AND STATEMENTS
Certain statements contained in this report, including statements that contain words such as "could", "should", "can", "anticipate", "estimate", "intend", "plan", "expect", "believe", "will", "may", "continue", "project", "potential" and similar expressions and statements relating to matters that are not historical facts constitute "forward-looking information" within the meaning of applicable Canadian securities legislation and "forward-looking statements" within the meaning of the "safe harbor" provisions of the United States Private Securities Litigation Reform Act of 1995 (collectively, "forward-looking information and statements").
In particular, forward looking information and statements include, but are not limited to, the following:
-- the payment of our declared second quarter dividend;
-- expansion of our new build rig program;
-- the expected benefits from our technology and service agreement and
marketing alliance with Schlumberger;
-- the continued development of Canadian LNG and our expectations in
becoming a key player in the sector;
-- the expected use of the net proceeds from our 2014 Notes offering;
-- our capital expenditure plans including the amounts allocated for
expansion capital, sustaining and infrastructure expenditures and rig
upgrades;
-- the timing on delivery and number of new build rigs to be deployed to
Canada, the U.S. and internationally;
-- the expected completion of our Nisku technical support centre and its
impact on our operational capabilities;
-- the outcome of the tax appeal proceedings in Ontario involving one of
our subsidiaries; and
-- our expectations regarding our ability to remain compliant with our
financial ratio covenants under our secured facility.
These forward-looking information and statements are based on certain assumptions and analysis made by Precision in light of our experience and our perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate in the circumstances. These include, among other things:
-- continued strong drilling demand in Canada, the U.S., and our target
international markets;
-- continued market demand for our Super Series rigs;
-- the status of current negotiations with our customers;
-- the economic viability of unconventional North American oil and gas
plays including the growing potential of LNG export development in
Canada; and
-- the general stability of the economic and political environment in the
jurisdictions where we operate;
Undue reliance should not be placed on forward-looking information and statements. Whether actual results, performance or achievements will conform to our expectations and predictions is subject to a number of known and unknown risks and uncertainties which could cause actual results to differ materially from our expectations. Such risks and uncertainties include, but are not limited to:
-- volatility in the price and demand for oil and natural gas;
-- fluctuations in the demand for contract drilling, well servicing and
ancillary oilfield services and its impact on customer spending;
-- the risks associated with our investments in capital assets and changing
technology;
-- shortages, delays and interruptions in the delivery of equipment,
supplies and other key inputs;
-- the effects of seasonal and weather conditions on operations and
facilities;
-- the availability of qualified personnel and management;
-- the existence of competitive operating risks inherent in our businesses;
-- changes in environmental and safety rules or regulations including
increased regulatory burden on horizontal drilling and hydraulic
fracturing;
-- terrorism, social, civil and political unrest in the foreign
jurisdictions where we operate;
-- fluctuations in foreign exchange, interest rates and tax rates; and
-- other unforeseen conditions which could impact the use of services
supplied by Precision and Precision's ability to respond to such
conditions.
Readers are cautioned that the foregoing list of risk factors is not exhaustive. Additional information on these and other factors that could affect our business, operations or financial results are included in reports on file with applicable securities regulatory authorities, including but not limited to Precision's Annual Information Form for the year ended December 31, 2014, which may be accessed on Precision's SEDAR profile at www.sedar.com or under Precision's EDGAR profile at www.sec.gov. The forward-looking statements contained in this news release are made as of the date hereof and Precision undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
INTERIM CONSOLIDATED STATEMENTS OF FINANCIAL POSITION (UNAUDITED)
----------------------------------------------------------------------------
June 30, December 31,
(Stated in thousands of Canadian dollars) 2014 2013
----------------------------------------------------------------------------
ASSETS
Current assets:
Cash $ 576,493 $ 80,606
Accounts receivable 474,063 549,697
Inventory 13,573 12,378
Assets held for sale 24,550 -
----------------------------------------------------------------------------
Total current assets 1,088,679 642,681
Non-current assets:
Income tax receivable 58,435 58,435
Property, plant and equipment 3,598,286 3,561,734
Intangibles 3,615 3,917
Goodwill 312,461 312,356
----------------------------------------------------------------------------
Total non-current assets 3,972,797 3,936,442
----------------------------------------------------------------------------
Total assets $ 5,061,476 $ 4,579,123
----------------------------------------------------------------------------
----------------------------------------------------------------------------
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued liabilities $ 342,235 $ 332,838
Income tax payable 183 4,060
----------------------------------------------------------------------------
Total current liabilities 342,418 336,898
Non-current liabilities:
Share based compensation 19,369 14,431
Provisions and other 17,132 17,836
Long-term debt 1,716,314 1,323,268
Deferred income taxes 497,519 487,347
----------------------------------------------------------------------------
Total non-current liabilities 2,250,334 1,842,882
Shareholders' equity:
Shareholders' capital 2,314,033 2,305,227
Contributed surplus 29,264 29,175
Retained earnings 147,719 88,416
Accumulated other comprehensive loss (22,292) (23,475)
----------------------------------------------------------------------------
Total shareholders' equity 2,468,724 2,399,343
----------------------------------------------------------------------------
Total liabilities and shareholders' equity $ 5,061,476 $ 4,579,123
----------------------------------------------------------------------------
----------------------------------------------------------------------------
INTERIM CONSOLIDATED STATEMENTS OF EARNINGS (LOSS) (UNAUDITED)
----------------------------------------------------------------------------
Three months ended Six months ended
June 30, June 30,
------------------------------------------
(Stated in thousands of Canadian
dollars, except per share
amounts) 2014 2013 2014 2013
----------------------------------------------------------------------------
Revenue $475,174 $378,898 $1,147,423 $974,618
Expenses:
Operating 304,285 258,769 699,438 600,607
General and administrative 41,194 31,881 81,016 70,582
----------------------------------------------------------------------------
Earnings before income taxes,
finance charges, foreign exchange
and depreciation and amortization 129,695 88,248 366,969 303,429
Depreciation and amortization 105,923 72,580 211,628 157,473
----------------------------------------------------------------------------
Operating earnings 23,772 15,668 155,341 145,956
Foreign exchange (298) (5,015) (3,927) (8,309)
Finance charges 25,562 23,950 49,994 46,509
----------------------------------------------------------------------------
Earnings (loss) before income
taxes (1,492) (3,267) 109,274 107,756
Income taxes:
Current 204 2,455 5,648 20,550
Deferred 5,478 (6,195) 9,243 (6,580)
----------------------------------------------------------------------------
5,682 (3,740) 14,891 13,970
----------------------------------------------------------------------------
Net earnings (loss) $ (7,174) $ 473 $ 94,383 $ 93,786
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Net earnings (loss) per share:
Basic $ (0.02) $ 0.00 $ 0.32 $ 0.34
Diluted $ (0.02) $ 0.00 $ 0.32 $ 0.33
----------------------------------------------------------------------------
----------------------------------------------------------------------------
INTERIM CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED)
----------------------------------------------------------------------------
Three months ended Six months ended
June 30, June 30,
----------------------------------------
(Stated in thousands of Canadian
dollars) 2014 2013 2014 2013
----------------------------------------------------------------------------
Net earnings (loss) $ (7,174) $ 473 $ 94,383 $ 93,786
Unrealized gain (loss) on
translation of assets and
liabilities of operations
denominated in foreign currency (64,952) 55,755 5,383 87,875
Foreign exchange gain (loss) on net
investment hedge with U.S.
denominated debt, net of tax 39,585 (37,380) (4,200) (59,115)
----------------------------------------------------------------------------
Comprehensive income (loss) $(32,541) $ 18,848 $ 95,566 $122,546
----------------------------------------------------------------------------
----------------------------------------------------------------------------
INTERIM CONSOLIDATED STATEMENTS OF CASH FLOW (UNAUDITED)
----------------------------------------------------------------------------
Three months ended Six months ended June
June 30, 30,
--------------------------------------------
(Stated in thousands of Canadian
dollars) 2014 2013 2014 2013
----------------------------------------------------------------------------
Cash provided by (used in):
Operations:
Net earnings (loss) $ (7,174) $ 473 $ 94,383 $ 93,786
Adjustments for:
Long-term compensation plans 8,480 4,240 18,791 10,757
Depreciation and
amortization 105,923 72,580 211,628 157,473
Foreign exchange 2,080 (5,246) (2,309) (8,548)
Finance charges 25,562 23,950 49,994 46,509
Income taxes 5,682 (3,740) 14,891 13,970
Other (3,427) 224 (1,928) 1,162
Income taxes paid (3,838) (24,045) (12,869) (94,724)
Income taxes recovered 3,342 1,960 3,354 1,960
Interest paid (38,945) (36,787) (46,970) (44,280)
Interest received 120 182 233 408
----------------------------------------------------------------------------
Funds provided by operations 97,805 33,791 329,198 178,473
Changes in non-cash working
capital balances 130,607 148,554 69,341 66,820
----------------------------------------------------------------------------
228,412 182,345 398,539 245,293
Investments:
Purchase of property, plant
and equipment (174,854) (136,237) (280,853) (266,842)
Proceeds on sale of property,
plant and equipment 9,979 4,148 17,236 6,686
Changes in non-cash working
capital balances 16,612 (10,774) 304 4,967
----------------------------------------------------------------------------
(148,263) (142,863) (263,313) (255,189)
Financing:
Increase in long-term debt 436,600 - 436,600 -
Repayment of long-term debt (13,942) - (30,670) -
Debt issue costs (10,166) - (10,166) -
Dividends paid (17,553) (13,832) (35,080) (27,657)
Issuance of common shares on
the exercise of options 3,493 240 6,103 720
----------------------------------------------------------------------------
398,432 (13,592) 366,787 (26,937)
----------------------------------------------------------------------------
Effect of exchange rate changes
on cash and cash equivalents (8,253) 6,667 (6,126) 11,459
----------------------------------------------------------------------------
Increase (decrease) in cash and
cash equivalents 470,328 32,557 495,887 (25,374)
Cash and cash equivalents,
beginning of period 106,165 94,837 80,606 152,768
----------------------------------------------------------------------------
Cash and cash equivalents, end
of period $ 576,493 $ 127,394 $ 576,493 $ 127,394
----------------------------------------------------------------------------
----------------------------------------------------------------------------
INTERIM CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (UNAUDITED)
----------------------------------------------------------------------------
(Stated in Accumulated
thousands of other
Canadian Shareholders' Contributed comprehensive Retained Total
dollars) capital surplus loss earnings equity
----------------------------------------------------------------------------
Balance at
January 1,
2014 $ 2,305,227 $ 29,175 $ (23,475) $ 88,416 $2,399,343
Net earnings
for the
period - - - 94,383 94,383
Other
comprehensive
income for
the period - - 1,183 - 1,183
Dividends - - - (35,080) (35,080)
Share options
exercised 8,806 (2,703) - - 6,103
Share based
compensation
expense - 2,792 - - 2,792
----------------------------------------------------------------------------
Balance at
June 30, 2014 $ 2,314,033 $ 29,264 $ (22,292)$ 147,719 $2,468,724
----------------------------------------------------------------------------
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(Stated in Accumulated
thousands of other Retained
Canadian Shareholders' Contributed comprehensive earnings Total
dollars) capital surplus loss (deficit) equity
----------------------------------------------------------------------------
Balance at
January 1,
2013 $ 2,251,982 $ 24,474 $ (60,535)$ (44,621) $2,171,300
Net earnings
for the
period - - - 93,786 93,786
Other
comprehensive
income for
the period - - 28,760 - 28,760
Dividends - - - (27,657) (27,657)
Issued on
redemption of
non-
management
director DSUs 634 (598) 36
Share options
exercised 1,097 (377) - - 720
Share based
compensation
expense - 3,565 - - 3,565
----------------------------------------------------------------------------
Balance at
June 30, 2013 $ 2,253,713 $ 27,064 $ (31,775) $ 21,508 $2,270,510
----------------------------------------------------------------------------
----------------------------------------------------------------------------
SECOND QUARTER 2014 EARNINGS CONFERENCE CALL AND WEBCAST
Precision Drilling Corporation has scheduled a conference call and webcast to begin promptly at 12:00 noon MT (2:00 p.m. ET) on Thursday, July 24, 2014.
The conference call dial in numbers are 1-866-226-1793 or 416-340-2216.
A live webcast of the conference call will be accessible on Precision's website at www.precisiondrilling.com by selecting "Investor Centre", then "Webcasts". Shortly after the live webcast, an archived version will be available for approximately 30 days.
An archived recording of the conference call will be available approximately one hour after the completion of the call until August 24, 2014 by dialing 1-800-408-3053 or 905-694-9451, pass code 4696487.
About Precision
Precision is a leading provider of safe and High Performance, High Value services to the oil and gas industry. Precision provides customers with access to an extensive fleet of contract drilling rigs, directional drilling services, well service and snubbing rigs, coil tubing services, camps, rental equipment, and wastewater treatment units backed by a comprehensive mix of technical support services and skilled, experienced personnel.
Precision is headquartered in Calgary, Alberta, Canada. Precision is listed on the Toronto Stock Exchange under the trading symbol "PD" and on the New York Stock Exchange under the trading symbol "PDS".
FOR FURTHER INFORMATION PLEASE CONTACT:
Precision Drilling Corporation
Carey Ford
Vice President, Finance and Investor Relations
403.716.4575
403.716.4755 (FAX)
Precision Drilling Corporation
Suite 800, 525 - 8th Avenue S.W.
Calgary, Alberta, Canada T2P 1G1
www.precisiondrilling.com
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