Trican Well Service Ltd.
TSX : TCW

Trican Well Service Ltd.

July 29, 2014 17:27 ET

Trican Reports Second Quarter Results for 2014

CALGARY, ALBERTA--(Marketwired - July 29, 2014) - Trican Well Service Ltd. (TSX:TCW)

Financial Review

Three months ended Six months ended
June 30, June 30, June 30, June 30,
($ millions, except per share amounts; unaudited) 2014 2013 2014 2013
Revenue $534.6 $396.6 $1,177.8 $1,015.0
Operating income / (loss) * 1.3 (14.8 ) 43.7 71.4
Profit / (loss) (43.1 ) (56.4 ) (51.6 ) (31.2 )
Earnings / (loss) per share (basic ) ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )
(diluted ) ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )
Adjusted profit / (loss) * (41.2 ) (50.4 ) ($47.5 ) (23.0 )
Adjusted profit / (loss) per share* (basic ) ($0.28 ) ($0.34 ) ($0.32 ) ($0.15 )
(diluted ) ($0.28 ) ($0.34 ) ($0.32 ) ($0.15 )
Funds provided by / (used in) operations* (11.5 ) (29.1 ) 26.5 28.9

Notes:

* Trican makes reference to operating income/(loss), adjusted profit/(loss) and funds provided by/(used in) operations. These are measures that are not recognized under International Financial Reporting Standards (IFRS). Management believes that, in addition to net income/(loss), operating income/(loss), adjusted profit/(loss) and funds provided by/(used in) operations are useful supplemental measures. Operating income/(loss) provides investors with an indication of net income/(loss) before depreciation and amortization, foreign exchange gains and losses, other income, finance costs and income tax expense. Adjusted profit/(loss) provides investors with information on net income/(loss) excluding one-time non-cash charges and the non-cash effect of stock-based compensation expense. Funds provided by/(used in) operations provide investors with an indication of cash available for capital commitments, debt repayments and other expenditures. Investors should be cautioned that operating income/(loss), adjusted profit/(loss), and funds provided by/(used in) operations should not be construed as an alternative to net income/(loss) and cash provided/(used in) operations determined in accordance with IFRS as an indicator of Trican's performance. Trican's method of calculating operating income/(loss), adjusted profit/(loss) and funds provided by/(used in) operations may differ from that of other companies and accordingly may not be comparable to measures used by other companies.

SECOND QUARTER HIGHLIGHTS

Consolidated revenue for the second quarter of 2014 was $534.6 million, an increase of 35% compared to the second quarter of 2013. The adjusted consolidated net loss was $41.2 million compared to $50.4 million, and adjusted diluted loss per share was $0.28 compared to $0.34 for the same period in 2013. Funds used in operations were $11.5 million compared to $29.1 million in the second quarter of 2013.

Our Canadian operations generated quarterly revenue of $171.9 million and an operating loss of $8.0 million during the second quarter of 2014. Canadian revenue increased year-over-year by 48% and operating margins improved by 640 basis points as demand for services during the second quarter increased substantially compared to the second quarter of 2013. The second quarter in Canada is typically impacted by spring break-up conditions; however, an improving macro-economic environment for the Canadian pressure pumping market, combined with an extended winter drilling season in April, contributed to the year-over-year increases. Although Canadian operating margins benefitted from higher activity during the second quarter, increased costs combined with weak pricing continued to negatively impact operating income. To improve profitability, a 7% price book increase was released in the second quarter and is expected to be phased-in over the second half of 2014. Given the strong demand expected in Canada during the second half of 2014, we anticipate that pricing improvement initiatives will be successful and expect second half margins to benefit from sequential pricing increases.

Our U.S. operations generated second quarter revenue of $267.6 million, an increase of 33% compared to the second quarter of 2013. Strong demand and operational performance in the Marcellus and Permian regions contributed to the increase in revenue and led to sequential improvements in operating margins. Pricing increases were obtained in both regions late in the second quarter that are expected to benefit U.S. operations in the second half of 2014. Demand for our services continued to be strong in the Bakken region during the second quarter due to strong operational performance. A second crew will be deployed in the Bakken region during the third quarter of 2014 in response to the strong demand in the region. Gains in the Marcellus, Permian and Bakken regions were partially offset by losses relating to the closure of our operating base in Woodward, Oklahoma. The Woodward fracturing crew was re-located to the Permian region during the second quarter and we are currently working to place this crew into an acceptable contract later in 2014. Operations in the Barnett, Oklahoma and Haynesville regions performed below expectations during the second quarter and also had a negative impact on second quarter operating margins. We have recently obtained contracts with customers in the Barnett and Oklahoma regions that are expected to improve utilization and profitability in these regions during the third quarter.

Second quarter revenue for our international operations was $95.1 million, an increase of 20% compared to the second quarter of 2014. The substantial increase in revenue led to a quarterly operating margin of 16.4% for our international operations. Our Russian operations comprise the majority of our international results, and record quarterly revenue was achieved in Russia during the second quarter. A rise in horizontal drilling and completions activity continued to benefit pressure pumping demand in Russia. In addition, our Russian customers were able to catch-up up on work programs that were behind schedule due to cold weather in the first quarter of 2014. Our international operations also benefitted from strong results from our North Sea completions tools business as year-over-year revenue for this division increased by almost 200% during the second quarter. Positive results in Russia and the North Sea were partially offset by operating losses in Algeria and start-up costs in Saudi and Colombia. Active operations commenced in both Saudi Arabia and Colombia during the second quarter, which is expected to improve the financial results for these regions during the second half of 2014.

On July 17, 2014, we increased our Revolving Credit Facility (the "Facility") from $500.0 million to $575.0 million. Commitments for the increase came from both existing and new banks. All other terms and conditions of the Facility remained unchanged, including its current maturity date of October 17, 2017.

In addition, subsequent to the end of the second quarter of 2014, we obtained a commitment from an institutional investor to issue $20 million of senior unsecured notes. The notes will have a ten year maturity, a coupon of 5.75% and will rank equally with all other senior indebtedness. Management expects this note issuance to close and fund during the third quarter of 2014.

MANAGEMENT'S DISCUSSION AND ANALYSIS

OVERVIEW

Headquartered in Calgary, Alberta, Trican has operations in Canada, the U.S., Russia, Kazakhstan, Algeria, Australia, Saudi Arabia, Colombia and Norway. Trican provides a comprehensive array of specialized products, equipment and services that are used during the exploration and development of oil and gas reserves.

COMPARATIVE QUARTERLY INCOME STATEMENTS ($ thousands, unaudited)
Three months ended June 30, 2014 % of
Revenue
2013 % of
Revenue
Quarter-
Over-
Quarter
Change
%
Change
Revenue 534,599 100.0 % 396,607 100.0 % 137,992 35 %
Expenses
Materials and operating 498,052 93.2 % 384,069 96.8 % 113,983 30 %
General and administrative 35,264 6.6 % 27,352 6.9 % 7,912 29 %
Operating income/(loss)* 1,283 0.2 % (14,814 ) (3.7 %) 16,097 (109 %)
Finance costs 9,536 1.8 % 8,554 2.2 % 982 11 %
Depreciation and amortization 49,136 9.2 % 50,613 12.8 % (1,477 ) (3 %)
Goodwill impairment - 0.0 % 4,123 1.0 % (4,123 ) (100 %)
Foreign exchange (gain)/loss 4,992 0.9 % (1,510 ) (0.4 %) 6,502 (431 %)
Other income (1,359 ) (0.3 %) (1,454 ) (0.4 %) 95 (7 %)
Loss before income taxes (61,022 ) (11.4 %) (75,140 ) (18.9 %) 14,118 (19 %)
Income tax recovery (17,470 ) (3.3 %) (18,751 ) (4.7 %) 1,281 7 %
Non-controlling interest (448 ) (0.1 %) (125 ) 0.0 % (323 ) 258 %
Net loss (43,104 ) 8.1 % (56,264 ) (14.2 %) 13,160 23 %

* see first page of this report

CANADIAN OPERATIONS

($ thousands, except revenue per job, unaudited)
Three months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
March 31,
2014
% of
Revenue
Revenue 171,937 116,061 353,342
Expenses
Materials and operating 171,763 99.9 % 121,446 104.6 % 283,280 80.2 %
General and administrative 8,213 4.8 % 7,443 6.4 % 7,543 2.1 %
Total expenses 179,976 104.7 % 128,889 111.1 % 290,823 82.3 %
Operating income/(loss)* (8,039 ) (4.7 %) (12,828 ) (11.1 %) 62,519 17.7 %
Number of jobs 3,628 3,096 6,396
Revenue per job 47,568 37,046 55,200

* see first page of this report

Sales Mix

Three months ended, (unaudited) June 30, June 30, March 31,
2014 2013 2014
% of Total Revenue
Fracturing 62% 61% 67%
Cementing 19% 14% 19%
Nitrogen 7% 5% 6%
Industrial services 4% 9% 1%
Coiled Tubing 4% 4% 3%
Acidizing 2% 3% 2%
Other 2% 4% 2%
Total 100% 100% 100%

Operations Review

Canadian activity levels in the second quarter of 2014 were up significantly compared to the second quarter of 2013 as demand for Canadian pressure pumping services benefitted from increased customer spending. Customer cash flows have increased throughout the first half of 2014 as Canadian commodity prices and a stronger U.S. dollar have improved the economics of the key Canadian oil and gas plays. The improved cash flows contributed to the year-over-year increase in second quarter activity levels and are also expected to result in higher pressure pumping demand in the second half of 2014. Demand for fracturing services also benefitted from an increase in fracturing intensity per well during the second quarter. We continue to see an increase in sand volumes and fracturing stages per well, which is leading to an increase in fracturing demand.

Cold weather throughout March and early April led to an extended winter drilling season and activity levels in early April were stronger compared to previous years. For the remainder of the second quarter and consistent with expectations, activity was impacted by spring break-up conditions when frozen ground begins to thaw and road bans and weight restrictions limit oil and gas activity levels. The favorable weather conditions in April combined with increased customer spending contributed to a 34% year-over-year increase in the second quarter average Canadian rig count.

Although Canadian operating margins benefitted from higher activity during the second quarter, increased costs combined with weak pricing continued to negatively impact operating income. Our Canadian cost structure increased compared to the second quarter of 2013 due to product and product transportation cost increases, wage inflation, higher diesel prices, and a weaker Canadian dollar. In addition, no significant fixed cost reductions were contemplated in the second quarter in anticipation of the strong second half activity in Canada.

Given the increased cost structure, one of the primary areas of focus in Canada continues to be on raising prices. A new Trican price book was released in mid-May that reflected a 7% price increase. The new price book will be gradually phased-in to our Canadian customer base with full implementation expected by the end of 2014. The new price book had a minimal impact on our second quarter Canadian results as most of the implementation is expected in the second half of 2014.

Our completions tools business in Canada was also negatively impacted by spring break-up during the second quarter, which led to sequential declines in revenue and operating income for this segment of our Canadian operations. However, this business continues to grow and revenue increased by 40% on a year-over-year basis in the second quarter of 2014. We expect continued growth of the Canadian completions tools business in the second half of 2014 with a continued focus on improving and increasing our tool manufacturing capabilities and leveraging off of our Canadian pressure pumping customer base.

Q2 2014 versus Q2 2013

Canadian revenue for the second quarter of 2014 increased by 48% compared to the second quarter of 2013. The job count increased by 17% due to increased customer spending combined with favorable weather conditions early in the second quarter. Revenue per job increased by 28% as larger fracturing job sizes and a higher proportion of fracturing revenue were partially offset by lower pricing.

Materials and operating expenses decreased to 99.9% of revenue compared to 104.6% for the same period in 2013. Increased activity led to improved operational leverage on our fixed cost structure in Canada, which was partially offset by increased costs and lower pricing compared to the second quarter of 2013. General and administrative expenses increased by $0.8 million due largely to higher share-based employee expenses.

Q2 2014 versus Q1 2014

Canadian revenue for the second quarter of 2014 decreased by 51% compared to the first quarter of 2014. The job count decreased by 43%, which compared to the 61% sequential drop in the Canadian rig count during the quarter caused by spring break-up conditions. Revenue per job decreased by 14% largely due to the decrease in fracturing revenue relative to total revenue.

As a percentage of revenue, materials and operating expenses increased to 99.9% compared to 80.2% in the first quarter of 2014. Lower activity levels led to reduced operating leverage on our cost structure, which contributed to most of the operating margin decrease. General and administrative costs increased by $0.7 million due mainly to higher share-based employee expenses.

UNITED STATES OPERATIONS

($ thousands, except revenue per job, unaudited)
Three months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
March 31,
2014
% of
Revenue
Revenue 267,564 201,538 211,040
Expenses
Materials and operating 246,540 92.1 % 186,795 92.7 % 205,207 97.2 %
General and administrative 9,071 3.4 % 6,246 3.1 % 6,868 3.3 %
Total expenses 255,611 95.5 % 193,041 95.8 % 212,075 100.5 %
Operating income (loss)* 11,953 4.5 % 8,497 4.2 % (1,035 ) (0.5 %)
Number of jobs 3,002 2,208 3,218
Revenue per job 86,387 92,096 61,776

* see first page of this report

Sales Mix

Three months ended, (unaudited) June 30, June 30, March 31,
2014 2013 2014
% of Total Revenue
Fracturing 92% 90% 90%
Cementing 6% 7% 6%
Coil Tubing 2% 3% 4%
Total 100% 100% 100%

Operations Review

Second quarter results for our U.S. operations benefitted from sequential revenue and operating margin increases for our Marcellus and Permian operations. The first quarter of 2014 was negatively impacted by cold weather in both of these regions, which contributed to sequential utilization improvement. Revenue generated by our Marcellus operations during the second quarter also benefitted from the addition of a fourth fracturing crew in late May. The utilization of this crew was strong upon deployment as demand remained robust in this region. Revenue generated by our Permian operations also benefitted from improved operational performance, which led to utilization increases for all crews in this region.

Improvements in the Marcellus and Permian regions were partially offset by costs incurred in closing our operating base in Woodward, Oklahoma. One fracturing crew had been operating out of Woodward and was transferred to the Permian basin during the second quarter. We are currently working to place this crew into an acceptable contract later in 2014.

Second quarter financial results were also negatively impacted by weak utilization for our fracturing crews operating in the Barnett and Oklahoma regions, and weak pricing and operating margins for our Haynesville fracturing crew. We have recently obtained contracts with customers in the Barnett and Oklahoma regions that are expected to improve utilization and profitability in these regions in the third quarter.

Stable regional demand combined with strong operational performance, led to sequential improvements in revenue and operating margins for our Bakken operations. We will be deploying a second crew into this region during the third quarter of 2014. Activity remained stable for our two fracturing crews operating in the Eagle Ford basin.

U.S. pricing levels are trending up in high activity areas such as the Permian and Marcellus plays. Pricing improvements were obtained in both regions late in the second quarter and are expected to benefit third quarter financial results. Product and product transportation cost increases were noted during the second quarter, but these were largely passed on to customers across all regions. Cost flow-through aside, pricing remains competitive in all other operating regions and remained relatively flat sequentially during the second quarter of 2014.

Revenue and operating income decreased sequentially for the U.S. Completion Tools division as one of our major customers reduced activity levels during the second quarter. Despite the lower financial results, we were able to expand our customer base for this division during the second quarter, which is expected to have a favorable impact on operating margins going forward. We also focused on improving manufacturing and supply-chain capabilities during the second quarter that will allow us to respond to increasing U.S. demand for our completion tools technology. Overall, we are pleased with the customer acceptance of this technology in the U.S. and expect financial results to improve for this division over the second half of 2014.

Q2 2014 versus Q2 2013

U.S. revenue in the second quarter of 2014 was up 33% compared to the second quarter of 2013. Revenue per job decreased by 6% due to pricing reductions and a change in fracturing job mix, which was partially offset by a stronger U.S. dollar relative to the Canadian dollar. The job count increased by 36% due largely to increased fracturing activity in the Marcellus, Permian and Bakken regions.

As a percentage of revenue, materials and operating expenses decreased to 92.1% from 92.7%. Increased operational leverage due to higher revenue was largely offset by lower average pricing, costs relating to the closure of the Woodward base, and higher product transportation costs. General and administrative costs increased by $2.8 million due largely to increased share-based compensation, office and insurance costs.

Q2 2014 versus Q1 2014

On a sequential basis, U.S. revenue increased by 27%. Revenue per job increased by 40% due to an increase in fracturing job size combined with a change in customer mix. Fewer jobs per crew were completed due to the substantial increase in fracturing job sizes. As a result, the job count decreased by 7% despite the increased activity levels.

Materials and operating expenses decreased to 92.1% from 97.2% due to increased operational leverage on our fixed cost structure from higher activity. This was partially offset by costs relating to the closure of the Woodward base and higher product transportation expenses. General and administrative expenses increased by $2.2 million due mainly to increased share-based compensation costs.

INTERNATIONAL OPERATIONS

($ thousands, except revenue per job, unaudited)
Three months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
March 31,
2014
% of
Revenue
Revenue 95,099 79,007 78,835
Expenses
Materials and operating 74,066 77.9 % 70,723 89.5 % 73,299 93.0 %
General and administrative 5,469 5.8 % 4,637 5.9 % 5,256 6.7 %
Total expenses 79,535 83.6 % 75,360 95.4 % 78,555 99.7 %
Operating (loss) income* 15,564 16.4 % 3,647 4.6 % 280 0.3 %
Number of jobs 1,225 962 966
Revenue per job 75,917 76,235 73,520

* see first page of this report

Sales Mix

Three months ended, (unaudited) June 30, June 30, March 31,
2014 2013 2014
% of Total Revenue
Fracturing 79% 83% 85%
Coiled Tubing 9% 8% 6%
Cementing 6% 5% 5%
Nitrogen 4% 2% 2%
Other 2% 2% 2%
Total 100% 100% 100%

Operations Review

Our international operations include the financial results for operations in Russia, Kazakhstan, Algeria, Australia, Saudi Arabia, Colombia and Norway.

Our Russian operations comprise the majority of our international results and activity levels in Russia were strong during the second quarter of 2014. Increased horizontal drilling and completions activity in Russia contributed to strong utilization for our pressure pumping fleet during the quarter. In addition, our Russian customer base was able to catch-up on programs that were behind schedule due to cold weather throughout most of the first quarter.

An additional fracturing fleet was deployed in Russia during the second quarter using existing spare capacity in the region. The additional crew combined with strong demand led to record quarterly revenue during the second quarter for our Russian operations.

We are continuing to monitor the conflict in the Ukraine and the impact that existing and potential economic sanctions may have on our Russian operations. Currently, the impact on our Russian operations has been minimal and we do not anticipate any disruptions to our Russian business throughout the remainder of 2014 based upon the sanctions that have been imposed to date. However, we will continue to monitor this situation closely as it does raise additional business risks in the region. The potential financial impact, if any, to Trican from existing and additional economic sanctions in the future is unknown at this time.

Second quarter financial results were strong in Kazakhstan for our two fracturing crews operating in the region and remained relatively consistent with the first quarter of 2014. Our Algerian operations incurred an operating loss during the second quarter due to continued weak utilization in the region.

Revenue for our Australian business increased sequentially by 15% during the second quarter. We continued to focus on expanding our customer base and increasing work volumes with existing customers during the quarter.

We began active operations in both Colombia and Saudi Arabia during the second quarter with positive operational results. We are currently offering cementing services in Colombia and coiled tubing and industrial services in Saudi Arabia. Both regions incurred operating losses in the second quarter; however, both Colombia and Saudi Arabia are expected to generate positive operating cash-flows in the second half of 2014 as utilization increases.

Second quarter financial results were strong for the Norwegian Completion Tools division for the second consecutive quarter. Customer acceptance of the technology, combined with strong operational execution, led to a year-over-year revenue increase of almost 200% for this international division.

Q2 2014 versus Q2 2013

Second quarter revenue in 2014 for our international operations increased by 20% compared to the second quarter of 2013. The job count increased by 27% due largely to higher activity in Russia, and to a lesser extent, higher activity in Saudi, Colombia and Australia. Revenue per job decreased by less than 1% as a decrease in fracturing revenue relative to total revenue was offset by an increase in job size. The increase in horizontal completions and multi-stage fracturing for our Russian operations led to an increase in job size for all pressure pumping service lines in the region.

As a percentage of revenue, materials and operating expenses decreased to 77.9% from 89.5% compared to the second quarter of 2013. International operating margins benefitted from increased activity in Russia and higher margins in Norway, offset partially by operating losses in Algeria. General and administrative costs increased by $0.8 million due largely to an increase in share-based employee costs in Russia.

Q2 2014 versus Q1 2014

International revenue increased by 21%, sequentially, due largely to job count increases in Russia and, to a lesser extent, increased activity in Saudi Arabia and Colombia. The revenue per job increased by 3% due to larger job sizes in Russia, which was offset by less fracturing revenue relative to total revenue.

Materials and operating expenses decreased to 77.9% compared to 93.0% in the first quarter of 2013 due largely to increased operational leverage on our fixed cost structure in Russia. General and administrative costs were up $0.2 million due to increased share-based expenses.

CORPORATE

($ thousands, unaudited)
Three months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
March 31,
2014
% of
Revenue
Expenses
Materials and operating 5,683 1.1 % 5,413 1.4 % 6,491 1.0 %
General and administrative 12,511 2.3 % 9,026 2.3 % 12,869 2.0 %
Total expenses 18,194 3.4 % 14,439 3.6 % 19,360 3.0 %
Operating loss* (18,194 ) (14,439 ) (19,360 )

* see first page of this report

Q2 2014 versus Q2 2013

Corporate expenses for the second quarter of 2014 increased by $3.8 million compared to the second quarter of 2013 due largely to an increase in the accrual for share-based employee expenses. Trican's share price increased by approximately 23% during the second quarter of 2014 compared to a decrease of approximately 6% during the second quarter of 2013.

Q2 2014 versus Q1 2014

Sequentially, corporate expenses decreased by $1.2 million as an increase in share-based employee expenses was more than offset by lower profit sharing expenses due to the decrease in second quarter consolidated operating income.

OTHER EXPENSES AND INCOME

Finance costs for the second quarter of 2014 increased by $1.0 million compared to the same period in 2013 due to higher average debt balances. Depreciation and amortization decreased slightly by $1.5 million compared to the same period last year as capital additions have been minimal for the last twelve months.

Foreign exchange losses of $5.0 million have been recorded in the second quarter of 2014, compared to gains of $1.5 million for the same period in 2013. This change is largely due to the net impact of fluctuations in the U.S. dollar and the Russian ruble relative to the Canadian dollar. Other income for the second quarter of 2014 was relatively consistent with the second quarter of 2013. Other income is mainly comprised of interest income earned on cash balances and gains on asset sales.


COMPARATIVE YEAR-TO-DATE INCOME STATEMENTS ($ thousands, unaudited)
Six months ended June 30, 2014 % of
Revenue
2013 % of
Revenue
Quarter-
Over-
Quarter
Change
%
Change
Revenue 1,177,816 100 % 1,014,983 100 % 162,833 16 %
Expenses
Materials and operating 1,066,329 90.5 % 886,094 87.3 % 180,235 20 %
General and administrative 67,800 5.8 % 57,539 5.7 % 10,261 18 %
Operating income* 43,687 3.7 % 71,350 7.0 % (27,663 ) (39 %)
Finance costs 19,763 1.7 % 16,535 1.6 % 3,228 20 %
Depreciation and amortization 101,887 8.7 % 97,672 9.6 % 4,215 4 %
Goodwill impairment, net - 0.0 % 4,123 0.4 % (4,123 ) (100 %)
Foreign exchange (gain)/loss 2,700 0.2 % (3,236 ) (0.3 %) 5,922 (183 %)
Other income (3,963 ) (0.3 %) (3,524 ) (0.3 %) (439 ) 12 %
Income/(loss) before income taxes (76,700 ) (6.5 %) (40,220 ) (4.0 %) (36,480 ) 91 %
Income tax expense/(recovery) (24,038 ) (2.0 %) (9,024 ) (0.9 %) (15,014 ) 166 %
Non-controlling interest (1,077 ) (0.1 %) (296 ) (0.0 %) (781 ) (264 %)
Net Income/(loss) (51,585 ) (4.6 %) (30,900 ) (3.1 %) (20,685 ) 67 %

* see first page of this report

CANADIAN OPERATIONS

($ thousands, except revenue per job, unaudited)
Six months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
Period-Over-Period
Change
Revenue 525,279 454,774 16 %
Expenses
Materials and operating 455,043 86.6 % 362,919 79.8 % 25 %
General and administrative 15,756 3.0 % 14,312 3.1 % 10 %
Total expenses 470,798 89.6 % 377,231 82.9 % 25 %
Operating income* 54,481 10.4 % 77,543 17.1 % (30 %)
Number of jobs 10,024 10,051 (0 %)
Revenue per job 52,438 44,819 17 %

* see first page of this report

Canadian revenue for the six months ended June 30, 2014, was 16% higher than the same period in 2013. A significant portion of this increase arose in the second quarter of 2014 when fracturing and cementing activity levels were up substantially compared to the second quarter of 2013. Increased second quarter activity was partially offset by lower year-over-year pricing. Revenue has also benefitted from larger fracturing job sizes as we continue to see a trend in Canada towards increased sand volumes and more fracturing stages per well.

As a percentage of revenue, materials and operating expenses increased to 86.8% from 79.8% compared to the same period in 2013. Increased activity levels, which led to improved operating leverage on our cost structure, was more than offset by lower pricing and increased costs. Higher product costs, wage inflation, increased diesel costs and a weaker Canadian dollar have all contributed to the higher cost structure. General and administrative expenses increased by $1.4 million due largely to increased share-based costs.

UNITED STATES OPERATIONS

($ thousands, except revenue per job, unaudited)
Six months ended, June 30,
2014
% of
Revenue
June 30,
2013
% of
Revenue
Period-Over-Period
Change
Revenue 478,604 412,223 16 %
Expenses
Materials and operating 451,747 94.4 % 373,008 90.5 % 21 %
General and administrative 15,939 3.3 % 12,729 3.1 % 25 %
Total expenses 467,686 97.7 % 385,738 93.6 % 21 %
Operating income/(loss)* 10,918 2.3 % 26,486 6.4 % 59 %
Number of jobs 6,220 4,243 47 %
Revenue per job 73,655 97,660 (25 %)

* see first page of this report

U.S. revenue for the first six months of 2014 increased by 16% compared to the first six months of 2013. The job count increased by 46% due to substantially higher fracturing activity in the Marcellus, Permian and Bakken regions. The addition of a fourth fracturing crew during the second quarter, combined with strong utilization, contributed to the increase in the Marcellus region. A substantial increase in utilization for our fracturing crews operating in the Permian and Bakken plays led to job count growth in these regions. These increases were offset partially by decreased utilization for our fracturing crews in the Haynesville and Oklahoma regions. Revenue per job decreased by 25% due to pricing reductions and a change in fracturing job mix, which was partially offset by a stronger U.S. dollar.

As a percentage of revenue, materials and operating expenses increased to 94.4% from 90.5%. An increase in product and product transportation costs combined with lower pricing led to the decrease in operating margins. These factors were partially offset by an increase in operating leverage on our fixed cost structure caused by higher revenue. General and administrative costs increased by $3.2 million due largely to increased share-based and insurance expenses.

INTERNATIONAL OPERATIONS

($ thousands, except revenue per job, unaudited) June 30, % of June 30, % of Period-Over-Period
Six months ended, 2014 Revenue 2013 Revenue Change
Revenue 173,934 149,118 17 %
Expenses
Materials and operating 147,365 84.7 % 139,107 93.3 % 6 %
General and administrative 10,725 6.2 % 8,485 5.7 % 26 %
Total expenses 158,090 90.9 % 147,592 99.0 % 7 %
Operating income* 15,844 9.1 % 1,526 1.0 % 938 %
Number of jobs 2,191 1.876 17 %
Revenue per job 77,178 76,235 1 %

* see first page of this report

International revenue increased by 17% during the first half of 2014 compared to the same period in 2013. An increase in Russian activity contributed to the majority of the increase. Russian activity benefitted from a rise in horizontal drilling and completions activity, which has led to an increase in pressure pumping demand in the region. Increased activity in Norway, Colombia, Saudi Arabia and Australia also contributed to the rise in international revenue. Revenue per job remained relatively flat on a year-over-year basis.

Materials and operating expenses decreased to 84.7% of revenue compared to 93.3% of revenue in the same period of 2013. An increase in Russian revenue led to improved operational leverage, which contributed to the majority of the margin improvement. Strong margins for the completion tools business in Norway also led to margin improvement. Continued weakness in Algeria and start-up costs in Saudi Arabia and Colombia offset a portion of the Russian and Norwegian gains. General and administrative costs increased by $2.2 million due largely to an increase in share-based employee expenses.

CORPORATE

($ thousands, unaudited) June 30, % of June 30, % of Period-Over-Period
Six months ended, 2014 Revenue 2013 Revenue Change
Expenses
Materials and operating 12,174 1.0 % 12,076 1.2 % 1 %
General and administrative 25,380 2.2 % 22,013 2.2 % 15 %
Total expenses 37,555 3.2 % 34,089 3.4 % 10 %
Operating loss* (37,555 ) (34,089 ) 10 %

* see first page of this report

Corporate costs are up $3.4 million for the first six months of 2014 compared to the same period in 2013 due largely to increased share-based expenses.

OTHER EXPENSES AND INCOME

For the six months ended June 30, 2014, finance costs increased by $3.2 million compared to the same period in 2013 due to increased debt balances. Depreciation and amortization increased by $4.2 million compared to the same period last year due to capital additions related to our capital expansion program.

Foreign exchange losses of $2.7 million have been recorded for the six months ended June 30, 2014, compared to gains of $3.2 million for the same period in 2013. This change is due to the net impact of fluctuations in the U.S. dollar and the Russian ruble relative to the Canadian dollar. Other income for the first half of 2014 was $4.0 million compared to $3.5 million for the same period of 2013. Other income is largely comprised of gains on asset sales and interest income on cash balances.

LIQUIDITY AND CAPITAL RESOURCES

Operating Activities

Funds used in operations decreased to $11.5 million for the second quarter of 2014 compared to $29.1 million for the same period in 2013. The decrease was due largely to a smaller consolidated net loss.

At June 30, 2014, Trican had working capital of $511.4 million compared to $413.2 million at the end of 2013. The increase is due to additional cash combined with higher U.S. activity, which has led to more U.S. inventory and trade accounts receivable. These were offset partially by repayment of US$75 million in current debt at the end of June.

Investing Activities

Capital expenditures for the second quarter of 2014 totaled $24.3 million, compared with $30.0 million for the same period in 2013. Capital expenditures for the six months ended June 30, 2014, were $41.0 million compared to $61.0 million in the same period of 2013. Capital expenditures continue to decrease on a year-over-year basis due to declines in our 2013 and 2014 capital programs relative to 2012.

During the second quarter of 2014, no significant changes were made to our 2014 capital budget. Remaining expenditures on approved capital budgets are expected to be approximately $60 million to $70 million.

Financing Activities

As at July 29, 2014, Trican had 149,612,995 common shares and 9,746,173 employee stock options outstanding.

During the first six months of 2014, Trican withdrew net $133.1 million on its $500.0 million revolving credit facility. The balance of the facility at June 30, 2014, was $345.0 million leaving $155 million of available debt under the facility. In addition, during the second quarter of 2014, Trican repaid $75 million of private placement notes.

On July 17, 2014, Trican exercised the Accordion feature of its Revolving Credit Facility and increased it from $500.0 million to $575.0 million. All other terms and conditions of the Revolving Credit Facility remained unchanged, including its current maturity date of October 17, 2017. At July 29, 2014, $230 million was available under the Facility.

Subsequent to the end of the second quarter of 2014, Trican obtained a commitment from an institutional investor to issue $20 million of senior unsecured notes. The notes will have a 10 year maturity, a coupon of 5.75% and will rank equally with all other senior indebtedness. The transaction is expected to close and fund during the third quarter of 2014.

During the first quarter of 2014, Trican received approval from the Toronto Stock Exchange to purchase its own common shares, for cancellation, in accordance with a Normal Course Issuer Bid ("NCIB") that expires on March 12, 2015. There were no common shares purchased through the NCIB during the first half of 2014.

Trican currently pays a semi-annual dividend of $0.15 per share. During the first quarter of 2014, $22.3 million in dividend payments were made. During the second quarter of 2014, Trican accrued $22.4 million in dividends that will be paid during the third quarter of 2014.

OUTLOOK

Canadian Operations

Demand for pressure pumping services is expected to be strong in Canada during the second half of 2014. Strong demand is expected to be driven by cash flow increases for Canadian customers and a continued increase in fracturing intensity per well. We expect the strongest demand to be generated from the Montney, Cardium and Deep Basin plays. Drilling and completions activity is also expected to increase in the Duvernay play during the second half of 2014 compared to the second half of 2013.

We expect to complete a large Horn River project with a 60,000 horsepower crew over the first five to six weeks of the third quarter. Approximately 33% of the horsepower used on this project will run on engines fuelled by a combination of natural gas sourced on site and diesel. Using natural gas in a conventional diesel engine has quickly evolved and we are optimistic that the most recent technology has led to a product design that is well suited for our service conditions. This is an exciting development for our industry and we will continue to actively participate in this development with our engine manufacturers. We are also using our proprietary recycled water fracturing fluid in the Horn River this year, which will significantly reduce the fresh water used on this project. Third quarter operating margins are expected to benefit from the Horn River work given the strong utilization anticipated over the duration of this project.

We expect to complete two small projects in the Liard basin during the third quarter. These will be the first fracturing projects completed by Trican in the Liard basin and reflects potential long-term customer interest in this region in light of Canadian LNG export opportunities.

Significant increases to our cost structure have negatively impacted operating margins over the last several quarters and pricing increases are required to achieve acceptable operating margins in Canada. As a result, pricing improvements will continue to be a key area of focus for our Canadian management team for the remainder of 2014. Given the strong demand expected in Canada during the second half of 2014, we anticipate that pricing improvement initiatives will be successful and expect second half margins to benefit from sequential pricing increases.

We expect to deploy a new fracturing crew into the Canadian market during the fourth quarter of 2014. The crew size is expected to be 20,000 to 25,000 horsepower and the equipment will be drawn from our existing inactive fleet.

U.S. Operations

Activity in the third quarter of 2014 is expected to remain strong in the Marcellus play, which is our most profitable U.S. region. Pricing improvements obtained at the end of the second quarter combined with a full quarter of activity from the fourth Marcellus crew are expected to result in sequential increases in revenue and operating income for this region.

We also expect financial results to continue to improve in the Permian region. Strong and growing demand in the Permian region, improvements in service quality and strategic sales initiatives have led to recent price increases, which are expected to positively impact third quarter results. In addition, we will continue to focus on increasing utilization and reducing costs, both of which are required to achieve acceptable return on capital in this region.

Due to strong operational performance, demand for our services in the Bakken region is increasing. As a result, we will be adding a second crew to this region during the third quarter of 2014, which is expected to result in stronger regional operating margins for our Bakken operations. The equipment for this crew will be drawn from our existing idle U.S. operating fleet.

To meaningfully advance our financial performance in the U.S., underperforming regions such as Barnett, Haynesville and Oklahoma must improve. New contracts have recently been obtained for fracturing crews in the Oklahoma and Barnett regions, and if operational execution is strong, sequential financial improvements are expected in these regions. In addition, we will continue to focus on increasing the utilization of the Haynesville crew through discussions with customers operating in Eastern Texas.

With recent improvements in operational execution, pricing increases, new contracts, and equipment deployed to high profitability areas, we were pleased with the progress made by our U.S. pressure pumping business during the second quarter. We still have significant improvements to make in the U.S. and must continue to execute on our strategic initiatives to achieve acceptable financial and operational results in this region in the future.

International Operations

With a strong second quarter making up for weak first quarter results, our annual 2014 outlook for Russia has not changed. We continue to expect revenue to increase by approximately 5% relative to 2013 with modest improvements in operating margins. When combined with year-over-year revenue growth in the North Sea, Australia, Colombia, and Saudi, overall international revenue for 2014 is expected to increase by approximately 10%.

We expect to grow our Saudi Arabia and Colombia operations during the second half of 2014 as we continue to establish our operations in these regions. In addition, we will continue to focus on expanding our cementing customer base in Australia and expect to achieve modest growth in this market over the second half of 2014.

Our Algerian operations continue to incur operating losses at current utilization levels. If utilization does not improve over the second half of 2014, we will consider exiting this region upon completion of our current customer commitments, which are expected to be fulfilled by the end of 2014.

We expect our North Sea completions tools business to continue to achieve good financial results over the second half of 2014. We will also focus on growing our manufacturing and supply-chain capabilities and expanding our customer base over the second half of 2014 in order to position this business for future growth.

NON-IFRS DISCLOSURE

Adjusted net income/(loss), operating income and funds provided by/(used in) operations do not have any standardized meaning as prescribed by IFRS and, therefore, are considered non-IFRS measures.

Adjusted net income/(loss) and funds provided by operations have been reconciled to profit and operating income has been reconciled to gross profit, being the most directly comparable measures calculated in accordance with IFRS. The reconciling items have been presented net of tax.

(thousands; unaudited) Three months ended Six months ended
June 30, 2014 June 30, 2013 March 31, 2013 June 30, 2014 June 30, 2013
Adjusted net income/(loss) ($41,175 ) ($50,407 ) ($6,330 ) ($47,505 ) ($23,027 )
Deduct:
Goodwill impairment - 4,123 - - 4,123
Non-cash share-based compensation expense 1,929 1,859 2,151 4,080 4,047
Profit/(loss) for the period (IFRS financial measure) ($43,104 ) ($56,389 ) ($8,481 ) ($51,585 ) ($31,197 )
(thousands; unaudited) Three months ended Six months ended
June 30, 2014 June 30, 2013 March 31, 2013 June 30, 2014 June 30, 2013
Funds provided by/(used in) operations ($11,532 ) ($29,073 ) $37, 999 $26,465 $28,883
Charges to income not involving cash
Depreciation and amortization (49,137 ) (50,613 ) (52,751 ) (101,887 ) (97,672 )
Amortization of debt issuance costs (216 ) (216 ) (216 ) (432 ) (432 )
Stock-based compensation (1,929 ) (1,859 ) (2,151 ) (4,080 ) (4,047 )
Gain/(loss) on disposal of property and equipment 480 (183 ) 90 570 277
Net finance costs (8,830 ) (7,984 ) (9,816 ) (18,646 ) (15,516 )
Unrealized foreign exchange gain / (loss) (6,609 ) 5,282 2,773 (3,836 ) 8,578
Goodwill impairment, net - (4,123 ) - - (4,123 )
Income tax recovery/(expense) 17,470 18,752 6,568 24,038 9,025
Interest paid 14,103 12,865 5,659 19,762 15,656
Income tax paid 3,096 763 3,365 6,461 28,174
Profit/(loss) for the period (IFRS financial measure) ($43,104 ) ($56,389 ) ($8,481 ) ($51,585 ) ($31,197 )
(thousands; unaudited) Three months ended Six months ended
June 30, 2014 June 30, 2013 March 31, 2013 June 30, 2014 June 30, 2013
Operating income $1,283 ($14,814 ) $42,404 $43,687 $71,349
Add:
Administrative expenses 37,597 29,252 33,989 71,586 60,041
Deduct:
Depreciation expense (49,136 ) (50,613 ) (52,751 ) (101,887 ) (97,672 )
Gross profit/(loss) (IFRS financial measure) ($10,256 ) ($36,175 ) $23,642 $13,386 $33,718

FORWARD-LOOKING STATEMENTS

This document contains certain forward-looking information and financial outlook based on Trican's current expectations, estimates, projections and assumptions that were made by the Company in light of information available at the time the statement was made. Forward-looking information and financial outlook that address expectations or projections about the future, and other statements and information about the Company's strategy for growth, expected and future expenditures, costs, operating and financial results, future financing and capital activities are forward-looking statements. Some forward-looking information and financial outlook are identified by the use of terms and phrases such as "anticipate," "achieve", "achievable," "believe," "estimate," "expect," "intend", "plan", "planned", and other similar terms and phrases. This forward-looking information and financial outlook speak only as of the date of this document and we do not undertake to publicly update this forward-looking information and financial outlook except in accordance with applicable securities laws. This forward-looking information and financial outlook include, among others:

  • The expectation that a 7% price book increase released in Canada during the second quarter will be phased-in over the second half of 2014;
  • The expectation that pricing improvement initiatives in Canada will be successful and that second half margins will benefit from sequential pricing increases;
  • The expectation that contracts with customers in the Barnett and Oklahoma regions will improve utilization and profitability in these regions during the third quarter of 2014;
  • The expectation that financial results for Saudi Arabia and Colombia will improve during the second half of 2014;
  • The expectation that improved cash flows for our Canadian customers will result in higher Canadian pressure pumping demand in the second half of 2014;
  • The expectation that the Canadian completions tools business will continue to grow in the second half of 2014 with a continued focus on improving and increasing our tool manufacturing capabilities and leveraging off of our Canadian pressure pumping customer base;
  • The expectation that pricing improvements obtained in both the Permian and Marcellus regions late in the second quarter will benefit third quarter 2014 financial results;
  • The expectation that a growing customer base for the U.S. completion tools division will have a favorable impact on operating margins for this business going forward;
  • The expectation that remaining expenditures on approved capital budgets will be approximately $40 million to $50 million;
  • The expectation that the issuance from an institutional investor of $20 million of senior unsecured notes will close and fund during the third quarter of 2014;
  • The expectation that demand for pressure pumping services will be strong in Canada during the second half of 2014 and will be driven by cash flow increases for Canadian customers and a continued increase in fracturing intensity per well;
  • The expectation that the strongest demand in Canada over the second half of 2014 will be generated from the Montney, Cardium and Deep Basin plays;
  • The expectation that drilling and completions activity will increase in the Duvernay play during the second half of 2014 compared to the second half of 2013;
  • The expectation to complete a large Horn River project with a 60,000 horsepower crew over the first five to six weeks of the third quarter of 2014;
  • The belief that using natural gas in a conventional diesel engine has quickly evolved and that the most recent technology has led to a product design that is well suited for our service conditions;
  • The expectation that the use of our proprietary recycled water fracturing fluid in the Horn River will significantly reduce the fresh water used on the Horn River project in 2014;
  • The belief that third quarter operating margins will benefit from the Horn River work given the strong utilization anticipated over the duration of this project;
  • The expectation to complete two small projects in the Liard basin during the third quarter;
  • The expectation that pricing improvements will continue to be a key area of focus for our Canadian management team for the remainder of 2014;
  • The expectation to deploy a new fracturing crew into the Canadian market during the fourth quarter of 2014;
  • The expectation that activity in the third quarter of 2014 will remain strong in the Marcellus region;
  • The expectation that pricing improvements obtained at the end of the second quarter combined with a full quarter of activity from the fourth Marcellus crew are will result in sequential increases in revenue and operating income for the Marcellus region;
  • The expectation that financial results will continue to improve in the Permian region;
  • The expectation that strong and growing demand in the Permian region, improvements in service quality and strategic sales initiatives will positively impact third quarter results;
  • The expectation that the second Bakken fracturing crew will result in stronger regional operating margins for our Bakken operations;
  • The expectation that Russian revenue will increase by approximately 5% relative to 2013 with modest improvements in operating margins;
  • The expectation that international revenue for 2014 will increase by approximately 10% relative to 2013;
  • The expectation that our Saudi Arabia and Colombia operations will grow during the second half of 2014 as we continue to establish our operations in these regions;
  • The expectation to achieve modest growth in Australia over the second half of 2014;
  • The expectation that if utilization does not improve over the second half of 2014, we will consider exiting Algeria upon completion of our current customer commitments, which are expected to be fulfilled by the end of 2014;
  • The expectation that our North Sea completions tools business will achieve good financial results over the second half of 2014.

Forward-looking information and financial outlook is based on current expectations, estimates, projections and assumptions, which we believe are reasonable but which may prove to be incorrect. Trican's actual results may differ materially from those expressed or implied and therefore such forward-looking information and financial outlook should not be unduly relied upon. In addition to other factors and assumptions which may be identified in this document, assumptions have been made regarding, among other things: industry activity; the general stability of the economic and political environment; effect of market conditions on demand for the Company's products and services; the ability to obtain qualified staff, equipment and services in a timely and cost efficient manner; the ability to operate its business in a safe, efficient and effective manner; the performance and characteristics of various business segments; the effect of current plans; the timing and costs of capital expenditures; future oil and natural gas prices; currency, exchange and interest rates; the regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which the Company operates; and the ability of the Company to successfully market its products and services.

Forward-looking information and financial outlook is subject to a number of risks and uncertainties, which could cause actual results to differ materially from those anticipated. These risks and uncertainties include: fluctuating prices for crude oil and natural gas; changes in drilling activity; general global economic, political and business conditions; weather conditions; regulatory changes; the successful exploitation and integration of technology; customer acceptance of technology; success in obtaining issued patents; the potential development of competing technologies by market competitors; and availability of products, qualified personnel, manufacturing capacity and raw materials. The foregoing important factors are not exhaustive. In addition, actual results could differ materially from those anticipated in forward-looking information and financial outlook provided herein as a result of the risk factors set forth under the section entitled "Risk Factors" in our Annual Information Form dated March 21, 2014. Readers are also referred to the risk factors and assumptions described in other documents filed by the Company from time to time with securities regulatory authorities.

Additional information regarding Trican including Trican's most recent annual information form is available under Trican's profile on SEDAR (www.sedar.com).

CONDENSED CONSOLIDATED STATEMENT OF FINANCIAL POSITION
(Stated in thousands; unaudited) June 30, 2014 December 31, 2013
ASSETS
Current assets
Cash and cash equivalents $108,135 $63,869
Trade and other receivables 467,516 459,210
Current tax assets 12,934 5,186
Inventory 246,980 232,898
Prepaid expenses 33,308 34,407
868,873 795,570
Property and equipment 1,308,409 1,374,212
Intangible assets 40,242 44,285
Deferred tax assets 141,968 122,745
Other assets 13,563 17,360
Goodwill 59,475 59,475
2,432,530 $2,413,647
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Bank loans $15,255 $-
Trade and other payables 342,175 301,920
Deferred consideration - 650
Current tax liabilities - 14
Current portion of loans and borrowings - 79,770
357,430 382,354
Loans and borrowings 707,398 593,786
Deferred tax liabilities 83,696 87,005
Shareholders' equity
Share capital 571,956 559,723
Contributed surplus 64,193 63,074
Accumulated other comprehensive loss (5,775 ) (1,020 )
Retained earnings 651,150 725,172
Total equity attributable to equity holders of the Company 1,281,524 1,346,949
Non-controlling interest 2,482 3,553
2,432,530 $2,413,647
CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

Three Months
Ended June 30,
Six Months
Ended June 30,
(Stated in thousands, except per share amounts; unaudited) 2014 2013 2014 2013
Three months ended June 30,
Revenue 534,599 $396,607 1,177,816 $1,014,983
Cost of sales 544,855 432,782 1,164,430 981,265
Gross (loss)/profit (10,256 ) (36,175 ) 13,386 33,718
Administrative expenses 37,597 29,252 71,586 60,041
Other income (653 ) (1,391 ) (2,846 ) (2,505 )
Results from operating activities (47,200 ) (64,036 ) (55,354 ) (23,818 )
Finance income (706 ) (63 ) (1,117 ) (1,019 )
Finance costs 9,536 8,554 19,763 16,535
Foreign exchange loss / (gain) 4,992 (1,510 ) 2,700 (3,236 )
Goodwill impairment, net - 4,123 - 4,123
Loss before income tax (61,022 ) (75,140 ) (76,700 ) (40,221 )
Income tax recovery (17,470 ) (18,751 ) (24,038 ) (9,024 )
Loss for the period (43,552 ) ($56,389 ) (52,662 ) ($31,197 )
Other comprehensive (loss) / income
Unrealized gain / (loss) on hedging instruments (49 ) (57 ) (1,583 ) 43
Foreign currency translation differences (8,023 ) 7,616 (3,166 ) 14,645
Total comprehensive loss for the period (51,624 ) ($48,830 ) (57,411 ) ($16,509 )
Loss attributable to:
Owners of the Company (43,104 ) (56,264 ) (51,585 ) (30,901 )
Non-controlling interest (448 ) (125 ) (1,077 ) (296 )
Loss for the period (43,552 ) ($56,389 ) (52,662 ) ($31,197 )
Total comprehensive loss attributable to:
Owners of the Company (51,176 ) (48,840 ) (56,334 ) (16,509 )
Non-controlling interest (448 ) 10 (1,077 ) -
Total comprehensive loss for the period (51,624 ) ($48,830 ) (57,411 ) ($16,509 )
Loss per share
Basic ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )
Diluted ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )
Weighted average shares outstanding - basic 149,129 148,845 149,029 148,720
Weighted average shares outstanding - diluted 149,129 148,845 149,029 148,720
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
Three Months
Ended June 30,
Six Months
Ended June,
(Stated in thousands; unaudited) 2014 2013 2014 2013
Cash Provided By / (Used In):
Operations
Loss for the period ($43,552 ) ($56,389 ) (52,662 ) ($31,197 )
Charges to income not involving cash:
Depreciation and amortization 49,136 50,613 101,887 97,672
Amortization of debt issuance costs 216 216 432 432
Stock-based compensation 1,929 1,859 4,080 4,047
Loss on disposal of property and equipment (480 ) 184 (570 ) (277 )
Net finance costs 8,830 7,984 18,646 15,516
Unrealized foreign exchange loss / (gain) 6,609 (5,282 ) 3,836 (8,578 )
Goodwill impairment, net - 4,123 - 4,123
Income tax recovery (17,470 ) (18,751 ) (24,038 ) (9,025 )
5,218 (15,443 ) 51,611 72,713
Change in inventories (11,509 ) (2,805 ) (17,572 ) (16,008 )
Change in trade and other receivables 119,281 187,997 (26,259 ) 87,159
Change in prepayments (4,072 ) (1,091 ) 1,014 1,748
Change in trade and other payables (29,364 ) (44,857 ) 45,286 28,163
Cash provided by operating activities 79,554 123,801 54,080 173,775
Interest paid (14,103 ) (12,865 ) (19,762 ) (15,656 )
Income taxes paid (3,096 ) (763 ) (6,461 ) (28,174 )
62,355 110,173 27,857 129,945
Investing
Payments received on a loan to unrelated third party 1,235 155 2,850 155
Purchase of property and equipment (24,316 ) (30,045 ) (41,032 ) (61,031 )
Proceeds from the sale of property and equipment 506 1,761 1,096 2,690
Purchase of other assets - - - (4,600 )
Payment of deferred consideration - - (650 ) -
Business acquisitions - - - (31,009 )
(22,575 ) (28,129 ) (37,736 ) (93,795 )
Financing
Net proceeds from issuance of share capital 9,024 906 9,272 906
Funds received from bank loans 4,151 - 15,255 -
Funds drawn on revolving credit facility 40,658 - 133,107 26,354
Repayment of long-term debt (80,483 ) (103,000 ) (80,483 ) (103,000 )
Dividend paid - - (22,338 ) (21,968 )
(26,650 ) (102,094 ) 54,813 (97,708 )
Effect of exchange rate changes on cash (401 ) 856 (668 ) 438
Increase / (decrease) in cash and cash equivalents 12,729 (19,194 ) 44,266 (61,120 )
Cash and cash equivalents, beginning of period 95,406 71,580 63,869 113,506
Cash and cash equivalents, end of period 108,135 $52,386 108,135 $52,386

SELECTED NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

LOANS AND BORROWINGS

Long term debt

June 30, 2014
December 31, 2013
Notes payable $378,617 $456,935
Finance lease obligations 19,230 25,904
Revolving credit facilities 344,984 212,625
Hedge receivable (9,427 ) (9,970 )
Total 733,404 685,494
Current portion of finance lease obligations (1) 10,751 11,938
Russian demand revolving credit facility 15,255 -
Current portion of loans and borrowings - 79,770
Non-current 707,398 $593,786
(1) Current portion of finance lease obligations is included in trade and other payables.

On June 30, 2014 Trican has a $500.0 million four-year extendible revolving credit facility ("Revolving Credit Facility") with a syndicate of banks. The Revolving Credit Facility is unsecured and bears interest at the applicable Canadian prime rate, U.S. prime rate, Banker's Acceptance rate, or at LIBOR, plus 50 to 325 basis points, dependent on certain financial ratios of the Company. On July 17, 2014, Trican added two additional banks to its banking syndicate and increased its Revolving Credit Facility from $500.0 million to $575.0 million. On October 17, 2013 the Revolving facility was extended by one additional year to until 2017. The Revolving Credit Facility requires Trican to comply with certain financial and non-financial covenants that are typical for this type of arrangement. Trican was in compliance with these covenants at June 30, 2014 (2013 - in compliance).

Notes payable

On June 22, 2014, Trican repaid US$ 75 million retiring its 2007 Series B Senior Notes.

The Notes payable require the Company to comply with certain financial and non-financial covenants that are typical for this type of arrangement. At June 30, 2014, the Company was in compliance with these covenants (2013 - in compliance).

LOSS PER SHARE

For the three months ended,
June 30,
For the six months ended
June 30,
Basic earnings per share 2014 2013 2014 2013
Loss available to common shareholders ($43,104 ) ($56,264 ) ($51,585 ) ($30,901 )
Weighted average number of common shares 149,129,488 148,845,211 149,028,946 148,720,011
Basic loss per share ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )
For the three months ended June 30, For the six months ended June 30,
Diluted earnings per share 2014 2013 2014 2013
Loss available to common shareholders ($43,104 ) ($56,264 ) ($51,585 ) ($30,901 )
Weighted average number of common shares 149,129,488 148,845,211 149,028,946 148,720,011
Diluted effect of stock options - - - -
Diluted weighted average number of common shares 149,129,488 148,845,211 149,028,946 148,720,011
Diluted loss per share ($0.29 ) ($0.38 ) ($0.35 ) ($0.21 )

INCOME TAXES

(Stated in thousands)

Three months ended June 30, 2014 2013
Current income tax expense ($4,596 ) ($10,982 )
Deferred income tax recovery (12,874 ) (7,769 )
($17,470 ) ($18,751 )

Stated in thousands)

Six months ended June 30, 2014 2013
Current income tax expense ($1,408) $1,440
Deferred income tax recovery (22,630) (10,464)
($24,038) ($9,024)

OPERATING SEGMENTS

The Company operates in Canada and the U.S. along with a number of international regions, which include Russia, Kazakhstan, Algeria, Australia, Saudi Arabia, Colombia and Norway. Each geographic region has a General Manager who is responsible for the operation and strategy of his region's business. Personnel working within the particular geographic region report to the General Manager; the General Manager reports to the Corporate Executive.

The Company provides a comprehensive array of specialized products, equipment, services and technology to customers through three operating divisions:

  • Canadian operations provide cementing, fracturing, coiled tubing, nitrogen, geological, acidizing, reservoir management, industrial cleaning and pipeline, and completion systems and downhole tool services. These services are performed on new and existing oil and gas wells and industrial facilities.
  • U.S. operations provide cementing, fracturing, coiled tubing, nitrogen, acidizing, industrial cleaning, completion systems and downhole tool services. These services are performed on new and existing oil and gas wells and industrial facilities.
  • International operations provide cementing, fracturing, coiled tubing, acidizing, nitrogen, industrial cleaning, completion systems and downhole tool services. These services are performed on new and existing oil and gas wells and industrial facilities.

Information regarding the results of each geographic region is included below. Performance is measured based on revenue and gross profit as included in the internal management reports, which are reviewed by the Company's executive management team. Each region's gross profit is used to measure performance as management believes that such information is most relevant in evaluating regional results relative to other entities that operate within the industry. Transactions between the segments are recorded at cost and have been eliminated upon consolidation.


Canadian Operations

United States
Operations

International
Operations

Corporate

Total
Three months ended June 30, 2014
Revenue $171,937 $267,564 $95,098 $- $534,599
Gross profit/(loss) (15,620 ) (2,058 ) 14,025 (6,603 ) (10,256 )
Finance income - - - (706 ) (706 )
Finance costs - - - 9,536 9,536
Tax expense/
(recovery)
(12,939 ) (6,331 ) 1,800 - (17,470 )
Depreciation and amortization 17,465 23,617 7,137 917 49,136
Assets 857,379 1,144,328 380,742 50,081 2,432,530
Goodwill 45,248 - 14,227 - 59,475
Property and equipment 469,466 698,737 123,457 16,749 1,308,409
Capital expenditures 4,475 6,797 12,710 334 24,316
Three months ended June 30, 2013
Revenue $116,062 $201,538 $79,007 - $396,607
Gross profit/(loss) (24,068 ) (7,272 ) 1,324 (6,159 ) (36,175 )
Finance income - - - ($63 ) (63 )
Finance costs - - - 8,554 8,554
Tax expense/
(recovery)
(10,928 ) (7,261 ) (562 ) - (18,751 )
Depreciation and amortization 18,141 24,724 7,001 747 50,613
Assets 850,519 1,117,887 334,074 50,103 2,352,583
Goodwill 62,492 - 14,226 - 76,718
Property and equipment 565,050 758,916 105,917 14,563 1,444,446
Capital expenditures 10,838 13,793 5,414 - 30,045

Canadian Operations
United States
Operations
International
Operations
Corporate Total
Six months ended June 30, 2014
Revenue $525,279 $478,604 $173,933 $- $1,177,816
Gross profit/(loss) 36,702 (21,812 ) 12,585 (14,089 ) 13,386
Finance income - - - (1,117 ) (1,117 )
Finance costs - - - 19,763 19,763
Tax expense/
(recovery)
(5,495 ) (19,425 ) 882 - (24,038 )
Depreciation and amortization 36,426 49,497 14,051 1,913 101,887
Capital expenditures 9,025 9,033 20,719 2,255 41,032
Six months ended June 30, 2013
Revenue $453,642 $412,223 $149,118 $ - $1,014,983
Gross profit/(loss) 56,257 (5,325 ) (3,915 ) (13,299 ) 33,718
Finance income - - - (1,019 ) (1,019 )
Finance costs - - - 16,535 16,535
Tax expense/
(recovery)
3,066 (10,508 ) (1,582 ) - (9,024 )
Depreciation and amortization 34,824 47,631 13,994 1,223 97,672
Capital expenditures 24,151 29,356 7,524 - 61,031

The Corporate division does not represent an operating segment and is included for informational purposes only. Corporate division expenses consist of salary expenses, stock-based compensation and office costs related to corporate employees, as well as public company costs.

Contact Information

  • Trican Well Service Ltd.
    Dale Dusterhoft
    Chief Executive Officer
    (403) 266-0202
    (403) 237-7716 (FAX)
    ddusterhoft@trican.ca

    Trican Well Service Ltd.
    Michael Baldwin
    Sr. Vice President, Finance & CFO
    (403) 266-0202
    (403) 237-7716 (FAX)
    mbaldwin@trican.ca

    Trican Well Service Ltd.
    Gary Summach
    Director of Reporting and Investor Relations
    (403) 266-0202
    (403) 237-7716 (FAX)
    gsummach@trican.ca

    Trican Well Service Ltd.
    2900, 645 - 7th Avenue S.W.
    Calgary, Alberta T2P 4G8
    www.trican.ca