Yahoo Finance Trican Reports First Quarter Results for 2022
Calgary, Alberta--(Newsfile Corp. - May 11, 2022) - Trican Well Service Ltd. (TSX: TCW) ("Trican" or the "Company") is pleased to announce its first quarter results for 2022. The following news release should be read in conjunction with Management's Discussion and Analysis ("MD&A"), the unaudited interim consolidated financial statements and related notes of Trican for the three months ended March 31, 2022, as well as the Annual Information Form ("AIF") for the year ended December 31, 2021. All of these documents are available on SEDAR at www.sedar.com.
HIGHLIGHTS
Revenue was $218.9 million for the three months ended March 31, 2022, a 48% increase compared to the three months ended March 31, 2021 resulting from higher industry activity and pricing leading to increased revenue per job.
Adjusted EBITDA and adjusted EBITDAS for the three months ended March 31, 2022, were $38.9 million and $42.0 million, compared to $27.3 million and $29.1 million, respectively for the three months ended March 31, 2021. The increase was the result of higher industry activity and pricing offset by significant inflationary pressures in all of our major cost categories including fuel, proppant, parts and labour as the industry seeks to ramp up activity.
Free cash flow was $30.4 million for the three months ended March 31, 2022 (March 31, 2021 - $22.0 million). Free cash flow was higher primarily as a result of strong activity levels which drove increased adjusted EBITDA and adjusted EBITDAS compared to the prior year comparative period offset by an anticipated increase in maintenance capital requirements for the quarter.
Profit from continuing operations for the three months ended March 31, 2022 was $13.3 million compared to $1.7 million for the three months ended March 31, 2021.
The Company's balance sheet remains in excellent shape with positive working capital, including cash, of $115.1 million at March 31, 2022 compared to $103.8 million at December 31, 2021 and no long-term debt.
The Company continues to differentiate its equipment fleet from what is available in the industry, successfully deploying Canada's first next generation fracturing spread with CAT Tier 4 Dynamic Gas Blending ("DGB") engine technology in Q1 2022. The Tier 4 DGB engine displaces up to 85% of the diesel used in a conventional pumper with cleaner burning natural gas. Combined with Trican's idle reduction technology, these upgrades result in lower overall fuel consumption, and in turn reduce carbon dioxide and particulate matter emissions. Progress continues on upgrading our second fleet with Tier 4 DGB technology which is anticipated to be field ready for the second half of 2022. Upgrades to Trican's third Tier 4 DGB fleet have been formally approved and are now underway. The third fleet is anticipated to be field ready by the end of 2022 and will bring Trican's total Tier 4 DGB fleet to 126,000 HHP. Tier 4 upgrades are a key component of Trican's ESG strategy and commitment to improving the sustainability of our operations and supporting our key customers to achieve their ESG goals.
The Company continues to be active in executing on its normal course issuer bid ("NCIB") program. Trican repurchased and cancelled 2,802,511 shares during the three months ended March 31, 2022, at a weighted average price of $3.22 per share.
CONTINUING OPERATIONS - FINANCIAL REVIEW
($ millions, except per share amounts. Weighted average shares is stated in thousands) | Three months ended | ||
(unaudited) | March 31, | March 31, | December 31, |
Revenue | $218.9 | $148.0 | $156.4 |
Gross profit | 29.4 | 11.2 | 12.5 |
Adjusted EBITDA1 | 38.9 | 27.3 | 28.0 |
Adjusted EBITDAS1 | 42.0 | 29.1 | 27.6 |
Free cash flow1 | 30.4 | 22.0 | 17.9 |
Weighted average shares outstanding - basic | 247,290 | 255,310 | 246,668 |
Weighted average shares outstanding - diluted | 252,729 | 258,373 | 254,552 |
Profit from continuing operations | 13.3 | 1.7 | 9.7 |
Per share - basic and diluted | $0.05 | $0.01 | $0.04 |
Profit for the period | 13.3 | 5.9 | 10.6 |
Per share - basic and diluted | $0.05 | $0.02 | $0.04 |
1 Refer to the Non-GAAP disclosure section of this news release for further details. | |||
($ millions, unaudited) | As at March 31, 2022 | As at December 31, 2021 |
Cash and cash equivalents | $4.0 | $29.5 |
Current assets - other | $225.6 | $151.8 |
Current portion of lease liabilities | $2.1 | $2.4 |
Current liabilities - other | $112.4 | $75.2 |
Lease liabilities - non-current portion | $7.5 | $7.9 |
Long-term loans and borrowings | $- | $- |
Total assets | $625.7 | $577.8 |
Three months ended | |||||
(Unaudited) | March 31, | December | September | June 30, | March 31, |
WTI - Average Price (US$/bbl) | $95.01 | $77.10 | $70.52 | $66.10 | $58.14 |
AECO-C - Spot Average Price (C$/mcf) | $4.53 | $4.50 | $3.39 | $2.94 | $2.94 |
WCS - Average Price (C$/bbl) | $103.91 | $76.57 | $72.56 | $65.42 | $58.54 |
Condensate - Average Price (C$/bbl) | $123.17 | $100.12 | $89.22 | $79.66 | $74.98 |
Average Exchange Rate (US$/C$) | $0.79 | $0.79 | $0.79 | $0.81 | $0.79 |
Canadian Average Drilling Rig Count | 203 | 176 | 160 | 84 | 146 |
Source: Bloomberg, Bank of Canada, Nickle's Energy Group, Rig Locator | |||||
First Quarter 2022 vs Fourth Quarter 2021 Sequential Overview
Revenue, gross profit, adjusted EBITDA and adjusted EBITDAS for Q1 2022 were $218.9 million, $29.4 million, $38.9 million and $42.0 million, respectively, with all significant financial measures being stronger in Q1 2022 than Q4 2021 due to sequentially higher industry activity levels.
Overall activity levels in Q1 2022 increased compared to Q4 2021 due to higher drilling and completions activity. The Company realized modest price increases in all three service lines. Unfortunately, improved pricing did not result in higher margins as better pricing only served to offset continued, significant inflationary pressures faced in all of our major cost categories.
The Company did not recognize any Canadian Government COVID-19 subsidy programs, Canadian Emergency Wage Subsidy ("CEWS"), Canadian Emergency Rent Subsidy ("CERS"), and together ("CES") in the quarter (Q4 2021 - $1.1 million).
Volumes of proppant pumped by the fracturing service line increased by 29% sequentially (Q1 2022 - 375,000 tonnes compared to Q4 2021 - 291,000 tonnes) as customers were more active with their completion programs in Q1 2022. The Company saw average tonnage pumped per job increase 14% in Q1 2022 relative to Q4 2021, reflective of the Company's strong position in the deep, technically challenging work found in the Montney and Deep Basin areas.
The Company maintained seven hydraulic fracturing crews throughout Q1 2022. Utilization of dual fuel pumpers continued to be prioritized through the quarter, supporting customer ESG and cost control objectives through a reduction in the amount of diesel used in favour of cleaner burning, less expensive natural gas.
The Cementing service line benefited from the increase in rig count in Q1 2022, which provided steady utilization through much of January and February, before slowing in mid-March due to seasonal spring breakup conditions. Coiled tubing operating days increased 17% sequentially, driven by first call work with our core customers and our efforts to expand market share.
OUTLOOK
Trican's overall outlook for our services for 2022 remains very positive. Global demand for energy remains strong as the world's major economies continue to recover. Macroeconomic factors including continued inflationary pressures, escalation of geopolitical tension and the lessening of COVID-19 restrictions point to continued strong commodity pricing through 2022.
At these commodity price levels we anticipate generally robust oilfield service activity levels as we move through the year. Canadian rig counts are expected to track 15-20% higher than 2021 which will drive an increase in demand across the oilfield services sector.
Activity levels for the second quarter of 2022 are expected to be much higher than prior years. Many customers were not able to complete their anticipated first quarter programs as cold weather delayed operations at the beginning of the year and activity levels in advance of spring breakup were very intense. As a result, a portion of work expected to be performed in the first quarter has carried forward and will be completed in the second quarter. This has led to a somewhat muted spring breakup with activity levels already beginning to increase.
Customer drilling and completions budgets are expected to increase as we move into the second half of 2022 given the attractive returns achieved by drilling and completing wells in the current commodity pricing environment. We expect that any budgetary expansion on behalf of our customers will lead to growing demand for Trican's services. Accordingly, we expect the market for Trican's services to move into an undersupplied position for the second half of 2022.
Attracting and retaining additional personnel continues to be a challenge across the industry making it much more difficult than in past upturns to supply additional crews. However, easing of COVID-19 travel restrictions combined with aggressive recruiting efforts across the country have resulted in positive progress for Trican in this area.
Significant inflationary pressures have affected virtually all inputs and are expected to continue as we progress through the year. Trican has been successful to date in passing along these cost increases to our customers to preserve operating margins. However, industry pricing is still below the levels necessary to provide sustainable returns with further price increases required to achieve meaningful net margin improvements.
Capital Expenditures and Hydraulic Fracturing Fleet Upgrades
Capital expenditures for the three months ended March 31, 2022 totaled $21.1 million ($6.9 million for the three months ended March 31, 2021) related to growth and upgrade capital, maintenance, and infrastructure capital. These capital expenditures were funded with available cash resources and free cash flow.
In Q1 2022, the Company successfully deployed Canada's first next generation fracturing spread with Tier 4 DGB engine technology. The Tier 4 DGB engine displaces up to 85% of the diesel used in a conventional pumper with cleaner burning natural gas. Combined with Trican's idle reduction technology, these upgrades result in lower overall fuel consumption and in turn reduce carbon dioxide and particulate matter emissions. Progress continues on upgrading our second fleet with Tier 4 DGB technology which is anticipated to be field ready for the second half of 2022. Upgrades to Trican's third Tier 4 DGB fleet have been formally approved and are now underway. The third fleet is anticipated to be field ready by the end of 2022 and will bring Trican's total Tier 4 DGB fleet to 126,000 HHP. Tier 4 upgrades are a key component of Trican's ESG strategy and commitment to improving the sustainability of our operations and supporting our key customers to achieve their ESG goals. Customer response has been positive and the Company is prepared to commit additional capital to the conversion of existing diesel-powered fleets to Tier 4 DGB engines if internal capital return metrics can be achieved.
Trican's 2022 capital spending program remains as previously announced at $65 million representing maintenance capital of approximately $30 million and growth and upgrade capital of approximately $35 million, inclusive of our third Tier 4 DGB fleet upgrade. In addition to the 2022 capital spending program, $17 million related to the second Tier 4 fleet upgrade has been carried forward into 2022, bringing total capital spending for the year to approximately $82 million.
Hydraulic Fracturing Fleet
Trican's hydraulic fracturing equipment is specifically designed to meet the demands of the higher intensity regions of the WCSB, including the Montney, Duvernay and Deep Basin formations. These regions account for approximately 80% of the required hydraulic horsepower demand in Canada. Additionally, Trican's fleet also includes an industry leading 170,000 HHP of conventional dual fuel engine fracturing pumps, which displace higher particulate diesel fuel with cleaner burning natural gas. The existing dual fuel fleet will be complemented by Trican's Tier 4 DGB fleet of 126,000 HHP when the third fleet has been deployed by the end of 2022. These investments reflect Trican's commitment to becoming an industry leader in ESG practices by reducing the environmental footprint of our operations.
Financial Position
We will continue to focus on maintaining a strong balance sheet with significant positive working capital and a building cash position. Our ability to generate strong free cash flow and our financial flexibility will provide required capital to allow us to execute our strategic plans that meet our return hurdle rate, maintain low financial leverage and continue participation in our NCIB program as a form of returning capital to our shareholders.
Sustainability Report
Trican issued its first sustainability report in 2021 and expects to publish the next report in mid-2022. The report outlines our commitment to sustainability, including a strong focus on safety, minimizing the environmental impacts of our operations and creating positive relationships with stakeholders in the communities where we live and work. Trican will remain focused on the evolving standards with respect to sustainability reporting and required disclosures.
Primary Objectives
Our goal remains to achieve top quartile return on invested capital in our sector. Our primary objectives are:
Strengthen Existing Businesses: Maintain our market leading position in the fracturing and cementing divisions and grow our market share in the coiled tubing division.
Environmental, Social, and Governance: Deepen the integration of ESG into our business to improve value for our stakeholders. We will differentiate with new technologies that reduce our environmental impact. We will build strong community relationships in the areas we live and work in.
Shareholder Return: Continue our disciplined investment philosophy ensuring full-cycle return hurdles can be met before investing in new equipment or upgrades to existing equipment, sell surplus or obsolete capital equipment whenever possible, continue to focus on a strong balance sheet and return capital to shareholders.
Cost Control and Efficiency Gains: Control and reduce costs for ourselves and our clients through efficiency improvements and scale.
COMPARATIVE QUARTERLY INCOME STATEMENTS
Continuing Operations
($ thousands, except total job count and revenue per job; unaudited) | ||||||
Three months ended | March 31, | Percentage | March 31, | Percentage | December 31, | Percentage |
Revenue | $218,911 | 100 % | $147,987 | 100 % | $156,366 | 100 % |
Cost of sales | ||||||
Cost of sales | 170,046 | 78 % | 113,720 | 77 % | 123,449 | 79 % |
Cost of sales - depreciation and amortization | 19,514 | 9 % | 23,090 | 16 % | 20,375 | 13 % |
Gross profit | 29,351 | 13 % | 11,177 | 8 % | 12,542 | 8 % |
Administrative expenses | 10,338 | 5 % | 7,752 | 5 % | 5,364 | 3 % |
Administrative expenses - depreciation | 880 | - % | 1,063 | 1 % | 602 | - % |
Other (income) / loss | (181) | - % | 104 | - % | (3,786) | (2) % |
Results from operating activities | 18,314 | 8 % | 2,258 | 2 % | 10,362 | 7 % |
Finance costs | 337 | - % | 537 | - % | 520 | - % |
Foreign exchange (gain) / loss | (131) | - % | (25) | - % | 287 | - % |
Profit before income tax | 18,108 | 8 % | 1,746 | 1 % | 9,555 | 6 % |
Income tax expense / (recovery) | 4,771 | 2 % | 74 | - % | (157) | - % |
Profit from continuing operations | $13,337 | 6 % | $1,672 | 1 % | $9,712 | 6 % |
Adjusted EBITDA1 | $38,949 | 18 % | $27,267 | 18 % | $28,007 | 18 % |
Total job count | 2,257 | 1,992 | 1,996 | |||
Revenue per job | 96,992 | 74,291 | 78,340 | |||
Total proppant pumped (tonnes) | 375,000 | 334,000 | 291,000 | |||
Hydraulic pumping capacity (HHP) | 576,000 | 570,000 | 573,000 | |||
Hydraulic fracturing - active crews | 7.0 | 6.0 | 6.0 | |||
Hydraulic fracturing - parked crews | 5.0 | 6.0 | 6.0 | |||
1 Refer to the Non-GAAP disclosure section of this news release for further details. | ||||||
Sales Mix - % of Total Revenue
Three months ended (unaudited) | March 31, 2022 | March 31, 2021 | December 31, 2021 |
Fracturing | 77 % | 76 % | 73 % |
Cementing | 15 % | 16 % | 17 % |
Coiled Tubing | 8 % | 8 % | 9 % |
Other | - % | - % | 1 % |
Total | 100 % | 100 % | 100 % |
NON-GAAP MEASURES
Certain terms in this News Release, including adjusted EBITDA, adjusted EBITDAS, adjusted EBITDA percentage and free cash flow, do not have any standardized meaning as prescribed by IFRS and therefore, are considered non-GAAP measures and may not be comparable to similar measures presented by other issuers.
Adjusted EBITDA and Adjusted EBITDAS
Adjusted EBITDA is a non-GAAP term and has been reconciled to profit / (loss) for the applicable financial periods, being the most directly comparable measure calculated in accordance with IFRS. Management relies on adjusted EBITDA to better translate historical variability in our principal business activities into future forecasts. By isolating incremental items from net income, including income / expense items related to how the Company chooses to manage financing elements of the business, management can better predict future financial results from our principal business activities.
Adjusted EBITDAS is a non-GAAP term and has been reconciled to profit / (loss) for the applicable financial periods, being the most directly comparable measure calculated in accordance with IFRS. Management relies on adjusted EBITDAS as a useful measure of operating performance, cash flow to complement profit / (loss) and to provide meaning comparisons of operating results.
The items included in this calculation of adjusted EBITDA have been specifically identified as they are either non-cash in nature, subject to significant volatility between periods, and / or not relevant to our principal business activities. Items adjusted in the non-GAAP calculation of adjusted EBITDA, are as follows:
Non-cash expenditures, including depreciation, amortization, impairment of non-financial assets, and equity-settled share-based compensation;
Consideration as to how we chose to generate financial income and incur financial expenses, including foreign exchange expenses and finance costs;
Taxation in various jurisdictions; and
Other income / expense which generally result from the disposition of equipment, as these transactions generally do not reflect quarterly operational field activity.
The item adjusted in the non-GAAP calculation of adjusted EBITDAS from adjusted EBITDA, is as follows:
Cash-settled share-based compensation.
($ thousands; unaudited) | Three months ended | ||
March 31, | March 31, | December 31, | |
Profit from continuing operations (IFRS financial measure) | $13,337 | $1,672 | $9,712 |
Adjustments: | |||
Cost of sales - depreciation and amortization | 19,514 | 23,090 | 20,375 |
Administrative expenses - depreciation | 880 | 1,063 | 602 |
Income tax expense / (recovery) | 4,771 | 74 | (157) |
Finance costs and amortization of debt issuance costs | 337 | 537 | 520 |
Foreign exchange (gain) / loss | (131) | (25) | 287 |
Other (income) / loss | (181) | 104 | (3,786) |
Administrative expenses - Other: equity-settled share-based compensation | 422 | 752 | 454 |
Adjusted EBITDA | $38,949 | $27,267 | $28,007 |
Administrative expenses - Other: cash-settled share-based compensation | 3,041 | 1,854 | (451) |
Adjusted EBITDAS | $41,990 | $29,121 | $27,556 |
Certain financial measures in this news release - namely adjusted EBITDA, adjusted EBITDAS, adjusted EBITDA percentage and free cash flow are not prescribed by IFRS and are considered non-GAAP measures. These measures may not be comparable to similar measures presented by other issuers and should not be viewed as a substitute for measures reported under IFRS. These financial measures are reconciled to IFRS measures in the Non-GAAP disclosure section of this news release. Other non-standard measures are described in the Non-Standard Measures section of this news release. Stainless steel fluid ends were historically expensed as depreciation prior to December 2017. Not all hydraulic fracturing companies apply the accounting policy for stainless steel fluid ends consistently. | |||
Adjusted EBITDA %
Adjusted EBITDA % is determined by dividing adjusted EBITDA by revenue from continuing operations. The components of the calculation are presented below:
($ thousands; unaudited) | Three months ended | ||
March 31, | March 31, | December 31, | |
Adjusted EBITDA | $38,949 | $27,267 | $28,007 |
Revenue | $218,911 | $147,987 | $156,366 |
Adjusted EBITDA % | 18% | 18% | 18% |
Free cash flow
Free cash flow is a non-GAAP term and has been reconciled to cash flow from continuing operations for the applicable financial periods, being the most directly comparable measure calculated in accordance with IFRS. Management relies on free cash flow to be a key measure of capital management as it demonstrates the Company's ability to generate monies available to fund future growth through capital investments and return capital to our shareholders.
Management believes that such a measure provides an insightful assessment of the Company's operations on a continuing basis by adjusting for other (income) / loss, realized (gain) / loss, maintenance capital expenditures included within purchase of property and equipment from the statement of cash flows and change in non-cash operating working capital.
Management alternatively reconciles free cash flow from adjusted EBITDA for the applicable financial periods as it believes that such a measure provides an insightful assessment of the Company's operating performance by adjusting for interest paid, income tax received, and maintenance capital expenditures included within purchase of property and equipment from the statement of cash flows.
Free cash flow is not a standardized measure and therefore may not be comparable with the calculation of similar measures by other entities.
($ thousands, unaudited) | Three months ended | ||
March 31, | March 31, | December 31, | |
Cash flow from continuing operations | $1,328 | $1,719 | $20,560 |
Interest paid | (142) | 24 | 443 |
Income tax received | (211) | 136 | 405 |
Maintenance capital expenditures | (9,176) | (4,877) | (11,525) |
Change in non-cash operating working capital | 38,634 | 24,948 | 8,045 |
Free cash flow | $30,433 | $21,950 | $17,928 |
($ thousands, unaudited) | Three months ended | ||
March 31, | March 31, | December 31, | |
Adjusted EBITDA | $38,949 | $27,267 | $28,007 |
Interest paid | (313) | (440) | (313) |
Income tax received | 973 | - | 1,759 |
Maintenance capital expenditures | (9,176) | (4,877) | (11,525) |
Free cash flow | $30,433 | $21,950 | $17,928 |
($ thousands, unaudited) | Three months ended | ||
March 31, | March 31, | December 31, | |
Purchase of property and equipment | $21,093 | $6,859 | $26,319 |
Growth capital expenditures | (11,917) | (1,982) | (14,794) |
Maintenance capital expenditures | $9,176 | $4,877 | $11,525 |
OTHER NON-STANDARD FINANCIAL TERMS
In addition to the above non-GAAP financial measures, this News Release makes reference to the following non-standard financial terms. These terms may differ and may not be comparable to similar terms used by other companies.
Revenue Per Job
Calculation is determined based on total revenue from continuing operations divided by total job count. This calculation is significantly impacted by factors such as the relative revenue contribution by service line, changes in pricing and the magnitude of customer supplied consumables and inputs.
Maintenance and Growth Capital
Term that refers to capital additions as maintenance or growth capital. Maintenance capital are capital expenditures in respect of capital additions, replacements or improvements required to maintain ongoing business operations. Growth capital refers to capital expenditures primarily for items that will expand our revenue and / or reduce our expenditures through operating efficiencies. The determination of what constitutes maintenance capital expenditures versus growth capital involves judgement by management.
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking information and statements (collectively "forward-looking statements"). These statements relate to future events or our future performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "achieve", "estimate", "expect", "intend", "plan", "planned", and other similar terms and phrases. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. We believe the expectations reflected in these forward-looking statements are reasonable, but no assurance can be given that these expectations will prove to be correct and such forward-looking statements included in this document should not be unduly relied upon. These statements speak only as of the date of this document.
In particular, this document contains forward-looking statements pertaining to, but not limited to, the following:
we will advance our business;
we have sufficient liquidity to invest in new opportunities, improve our competitive position and drive profitable growth;
that Trican will continue to adapt to the current economic environment;
the impact of escalated geopolitical tensions and the associated effect on worldwide demand for oil and gas;
the impact of COVID-19 and the associated effect on world-wide demand for oil and gas;
anticipated industry activity levels and outlook as well as expectations regarding our customers' work and capital programs and the associated impact on the Company's equipment utilization levels and demand for our services in Q2 and throughout 2022;
the impact of inflation and inflationary pressures;
expectation as to the type of pressure pumping equipment required and which operating regions the equipment is appropriate to operate in;
expectations regarding supply and demand fundamentals and strong commodity pricing levels;
expectations regarding credit risk and that we have an adequate provision for trade receivables;
expectation that we are adequately staffed for current industry activity levels, that we will be able to retain and attract staff and that we will maintain the Company's lean cost structure;
expectations regarding the Company's ability to work with customers to achieve long-term pricing objectives;
expectations regarding the Company's financial results, working capital levels, liquidity and profits;
expectations regarding Trican's capital spending plans, sources of capital, and specifically the timing and cost of the roll out of Trican's Tier 4 DGB pumpers;
expectations regarding Trican's utilization of its NCIB program;
expectations that adjusted EBITDA will help predict future earnings;
expectations regarding customer performance and financial flexibility;
expectations that rig count will continue to increase;
expectations regarding the impact of inflation;
anticipated compliance with debt and other covenants under our revolving credit facilities;
expectations that the Company can maintain its market leading position in the fracturing and cementing services lines and strengthen auxiliary services;
expectations that the Company will deepen the integration of ESG into its business and be supported by its customers in doing so;
expectations regarding provincial income tax rates and ongoing tax evaluations; and
expectations surrounding weather and seasonal slowdowns.
Our actual results could differ materially from those anticipated in these forward-looking statements as a result of the risk factors set forth herein and in the "Risk Factors" section of our AIF for the year ended December 31, 2021, available on SEDAR (www.sedar.com).
Readers are cautioned that the foregoing lists of factors are not exhaustive. Forward-looking statements are based on a number of factors and assumptions, which have been used to develop such statements and information, but which may prove to be incorrect. Although management of Trican believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because Trican can give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified in this document, assumptions have been made regarding, among other things: crude oil and natural gas prices; the impact of increasing competition; the general stability of the economic and political environment; the timely receipt of any required regulatory approvals; industry activity levels; Trican's policies with respect to acquisitions; the ability of Trican to obtain qualified staff, equipment and services in a timely and cost efficient manner; the ability to operate our business in a safe, efficient and effective manner; the ability of Trican to obtain capital resources and adequate sources of liquidity; the performance and characteristics of various business segments; the regulatory framework; the timing and effect of pipeline, storage and facility construction and expansion; and future commodity, currency, exchange and interest rates.
The forward-looking statements contained in this document are expressly qualified by this cautionary statement. We do not undertake any obligation to publicly update or revise any forward-looking statements except as required by applicable law.
Additional information regarding Trican including Trican's most recent AIF, is available under Trican's profile on SEDAR (www.sedar.com).
CONFERENCE CALL AND WEBCAST DETAILS
The Company will host a conference call on Thursday, May 12, 2022 at 10:00 a.m. MT (12:00 p.m. ET) to discuss its results for the First Quarter 2022.
To listen to the webcast of the conference call, please enter the following URL in your web browser: http://www.gowebcasting.com/11747.
You can also visit the Investors section of our website at www.tricanwellservice.com/investors and click on "Reports".
To participate in the Q&A session, please call the conference call operator at 1-800-319-4610 (North America) or 1-403-351-0324 (outside North America) 10 minutes prior to the call's start time and ask for the "Trican Well Service Ltd. First Quarter 2022 Earnings Results Conference Call."
The conference call will be archived on Trican's website at www.tricanwellservice.com/investors.
ABOUT TRICAN
Headquartered in Calgary, Alberta, Trican supplies oil and natural gas well servicing equipment and solutions to our customers through the drilling, completion and production cycles. Our team of technical experts provide state of the art equipment, engineering support, reservoir expertise and laboratory services through the delivery of hydraulic fracturing, cementing, coiled tubing, nitrogen services and chemical sales for the oil and gas industry in Western Canada. Trican is the largest pressure pumping service company in Canada.
Requests for further information should be directed to:
Bradley P.D. Fedora
President and Chief Executive Officer
Scott Matson
Chief Financial Officer
Phone: (403) 266-0202
2900, 645 - 7th Avenue S.W.
Calgary, Alberta T2P 4G8
Please visit our website at www.tricanwellservice.com.
To view the source version of this press release, please visit https://www.newsfilecorp.com/release/123724
