Total Energy Services Inc. press release
Total Energy Services Inc. Announces Q3 2025 Results
TSX - Toronto Stock Exchange · Oil · Natural Gas · Canada
CALGARY, Alberta, Nov. 12, 2025 (GLOBE NEWSWIRE) -- Total Energy Services Inc. (“Total Energy” or the “Company”) (TSX:TOT) announces its consolidated financial results for the three months ended September 30, 2025.
Financial Highlights ($000’s except per share data, unaudited)
| | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | | 2025 | | 2024 | Change | | | 2025 | | 2024 | Change | | | | Revenue | $ | 260,702 | $ | 241,940 | 8 | % | | $ | 763,027 | $ | 659,960 | 16 | % | | Operating income | | 19,352 | | 27,308 | (29 | %) | | | 67,729 | | 63,950 | 6 | % | | EBITDA (1) | | 42,907 | | 50,543 | (15 | %) | | | 138,791 | | 131,280 | 6 | % | | Cashflow | | 41,362 | | 48,091 | (14 | %) | | | 124,706 | | 119,022 | 5 | % | | Net income (loss) | | 14,584 | | 19,706 | (26 | %) | | | 50,622 | | 50,623 | - | | | Attributable to shareholders | | 14,504 | | 19,731 | (26 | %) | | | 50,581 | | 50,685 | - | | | | | | | | | | | | | | | | | | Per Share Data (Diluted) | | | | | | | | | | | | | | | EBITDA (1) | $ | 1.13 | $ | 1.28 | (12 | %) | | $ | 3.64 | $ | 3.27 | 11 | % | | Cashflow | $ | 1.09 | $ | 1.22 | (11 | %) | | $ | 3.27 | $ | 2.97 | 10 | % | | | | | | | | | | | | | | | | | Attributable to shareholders: | | | | | | | | | | | | | | | Net income (loss) | $ | 0.38 | $ | 0.50 | (24 | %) | | $ | 1.33 | $ | 1.26 | 6 | % | | | | | | | | | | | | | | | | | Common shares (000’s) (4) | | | | | | | | | | | | | | | Basic | | 37,159 | | 38,802 | (4 | %) | | | 37,535 | | 39,385 | (5 | %) | | Diluted | | 37,890 | | 39,489 | (4 | %) | | | 38,088 | | 40,086 | (5 | %) | | | | | | | | | | | | | | | | | | | | | | | | | September 30 | | December 31 | | | | | Financial Position at | | | | | | | | 2025 | | 2024 | Change | | | | Total Assets | | | | | | | $ | 1,015,387 | $ | 937,708 | 8 | % | | | Long-Term Debt and Lease Liabilities (excluding current portion) | 98,197 | | 79,171 | 24 | % | | | | | | | | | | Working Capital (2) | | | | | | | | 113,535 | | 78,737 | 44 | % | | | Net Debt (3) | | | | | | | | - | | 434 | nm | | | | Shareholders’ Equity | | | | | | | | 594,111 | | 571,043 | 4 | % | | | | | | | | | | | | | | | | |
Notes 1 through 4 please refer to the Notes to the Financial Highlights set forth at the end of this release.
nm – calculation not meaningful
Total Energy’s financial results for the third quarter of 2025 reflect improved Australian financial results following the upgrade and reactivation of several drilling and service rigs, continued strong North American demand for compression and process equipment and competitive North American drilling and completion market conditions. Negatively impacting 2025 third quarter results was a $1.8 million year over year change in foreign currency exchange impact on Compression and Process Services segment financial results and a $1.5 million year over year increase in share based compensation expense due to share price appreciation.
Contract Drilling Services (“CDS”)
| | | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | | | | 2025 | | | 2024 | | Change | | 2025 | | | 2024 | | Change | | | | Revenue | $ | 82,374 | | $ | 86,634 | | (5 | %) | $ | 244,683 | | $ | 235,734 | | 4 | % | | EBITDA (1) | $ | 19,921 | | $ | 20,563 | | (3 | %) | $ | 61,180 | | $ | 57,414 | | 7 | % | | EBITDA (1) as a % of revenue | | 24 | % | | 24 | % | - | | | 25 | % | | 24 | % | 4 | % | | Operating days (2) | | 2,326 | | | 2,836 | | (18 | %) | | 7,044 | | | 7,687 | | (8 | %) | | Canada | | 1,407 | | | 1,861 | | (24 | %) | | 4,252 | | | 4,954 | | (14 | %) | | United States | | 62 | | | 328 | | (81 | %) | | 353 | | | 1,033 | | (66 | %) | | Australia | | 857 | | | 647 | | 32 | % | | 2,439 | | | 1,700 | | 43 | % | | Revenue per operating day (2) , dollars | $ | 35,414 | | $ | 30,548 | | 16 | % | $ | 34,736 | | $ | 30,667 | | 13 | % | | Canada | | 24,606 | | | 25,026 | | (2 | %) | | 26,278 | | | 26,137 | | 1 | % | | United States | | 30,016 | | | 27,829 | | 8 | % | | 29,666 | | | 28,566 | | 4 | % | | Australia | | 53,551 | | | 47,808 | | 12 | % | | 50,216 | | | 45,144 | | 11 | % | | Utilization | | 25 | % | | 29 | % | (14 | %) | | 25 | % | | 27 | % | (7 | %) | | Canada | | 21 | % | | 27 | % | (22 | %) | | 21 | % | | 24 | % | (13 | %) | | United States | | 6 | % | | 30 | % | (80 | %) | | 11 | % | | 31 | % | (65 | %) | | Australia | | 55 | % | | 41 | % | 34 | % | | 55 | % | | 46 | % | 15 | % | | Rigs, average for period | | 102 | | | 105 | | (3 | %) | | 102 | | | 103 | | (1 | %) | | Canada | | 73 | | | 76 | | (4 | %) | | 73 | | | 77 | | (5 | %) | | United States | | 12 | | | 12 | | - | | | 12 | | | 12 | | 0 | % | | Australia | | 17 | | | 17 | | - | | | 17 | | | 14 | | 21 | % |
(1 ) See Note 1 of the Notes to the Financial Highlights set forth at the end of this release. ( 2 ) Operating days includes drilling and paid standby days .
Third quarter CDS segment activity was lower in 2025 compared to 2024 due to a year over year decline in North American onshore drilling activity. Canadian activity was also negatively impacted by customer consolidation and a loss of market share in more competitive areas of the market. Partially offsetting the North American decline was increased Australian activity following the reactivation of several upgraded drilling rigs over the past year. The year over year increase in third quarter Australian revenue per operating day reflects higher day rates received for upgraded drilling rigs.
Rentals and Transportation Services (“RTS”)
| | | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | | | | 2025 | | | 2024 | | Change | | 2025 | | | 2024 | | Change | | | | Revenue | $ | 21,041 | | $ | 19,437 | | 8 | % | $ | 60,251 | | $ | 59,614 | | 1 | % | | EBITDA (1) | $ | 7,623 | | $ | 8,179 | | (7 | %) | $ | 21,657 | | $ | 23,958 | | (10 | %) | | EBITDA (1) as a % of revenue | | 36 | % | | 42 | % | (14 | %) | | 36 | % | | 40 | % | (10 | %) | | Revenue per utilized piece of equipment, dollars | $ | 13,754 | | $ | 12,868 | | 7 | % | $ | 43,072 | | $ | 42,297 | | 2 | % | | Pieces of rental equipment | | 8,050 | | | 7,960 | | 1 | % | | 8,050 | | | 7,960 | | 1 | % | | Canada | | 6,867 | | | 7,040 | | (2 | %) | | 6,867 | | | 7,040 | | (2 | %) | | United States | | 1,183 | | | 920 | | 29 | % | | 1,183 | | | 920 | | 29 | % | | Rental equipment utilization | | 19 | % | | 19 | % | - | | | 18 | % | | 18 | % | - | | | Canada | | 17 | % | | 18 | % | (6 | %) | | 15 | % | | 16 | % | (6 | %) | | United States | | 30 | % | | 29 | % | 3 | % | | 32 | % | | 33 | % | (3 | %) | | Heavy trucks | | 62 | | | 67 | | (7 | %) | | 62 | | | 67 | | (7 | %) | | Canada | | 40 | | | 46 | | (13 | %) | | 40 | | | 46 | | (13 | %) | | United States | | 22 | | | 21 | | 5 | % | | 22 | | | 21 | | 5 | % |
(1) See Note 1 of the Notes to the Financial Highlights set forth at the end of this release.
RTS segment revenue increased for the third quarter of 2025 compared to 2024 due to stable activity in Canada and the acquisition of 280 major rental pieces located in Oklahoma on June 10, 2025. Despite a year over year increase in revenue per utilized piece of rental equipment arising from a change in the mix of operating equipment, third quarter segment EBITDA decreased compared to 2024 as competitive market conditions did not allow for price increases necessary to offset cost inflation.
Compression and Process Services (“CPS”)
| | | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | | | | 2025 | | | 2024 | | Change | | 2025 | | | 2024 | | Change | | | | Revenue | $ | 125,801 | | $ | 110,567 | | 14 | % | $ | 365,250 | | $ | 297,547 | | 23 | % | | EBITDA (1) | $ | 15,097 | | $ | 19,336 | | (22 | %) | $ | 52,994 | | $ | 47,795 | | 11 | % | | EBITDA (1) as a % of revenue | | 12 | % | | 17 | % | (29 | %) | | 15 | % | | 16 | % | (6 | %) | | | | | | | | | | | | | | | | | | | | Horsepower of equipment on rent at period end | | 51,313 | | | 52,881 | | (3 | %) | | 51,313 | | | 52,881 | | (3 | %) | | | | | | | | | | | | | | | | | | | | Canada | | 23,763 | | | 16,661 | | 43 | % | | 23,763 | | | 16,661 | | 43 | % | | United States | | 27,550 | | | 36,220 | | (24 | %) | | 27,550 | | | 36,220 | | (24 | %) | | Rental equipment utilization during the period (HP) (2) | | 75 | % | | 77 | % | (3 | %) | | 69 | % | | 77 | % | (10 | %) | | Canada | | 78 | % | | 72 | % | 8 | % | | 66 | % | | 70 | % | (6 | %) | | United States | | 73 | % | | 79 | % | (8 | %) | | 71 | % | | 80 | % | (11 | %) | | | | | | | | | | | | | | | | | | | | Sales backlog at period end, $ million | $ | 380.8 | | $ | 189.0 | | 101 | % | $ | 380.8 | | $ | 189.0 | | 101 | % |
(1) See Note 1 of the Notes to the Financial Highlights set forth at the end of this release. (2) Rental equipment utilization is measured on a horsepower basis .
2025 third quarter CPS segment revenue was higher compared to 2024 due to increased North American fabrication sales and parts and service activity that was partially offset by lower compression rental fleet utilization. The year over year decline in third quarter segment EBITDA was a result of a negative $1.8 million foreign currency exchange impact resulting from a declining Canadian dollar relative to the U.S. dollar, the timing of execution of certain low margin fabrication projects and cost inflation arising from tariff related supply chain challenges. Sequentially, the quarter end fabrication sales backlog increased by $76.9 million, or 25%, from the $303.9 million backlog at June 30, 2025.
Well Servicing (“WS”)
| | | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | | | | 2025 | | | 2024 | | Change | | 2025 | | | 2024 | | Change | | | | Revenue | $ | 31,486 | | $ | 25,302 | | 24 | % | $ | 92,843 | | $ | 67,065 | | 38 | % | | EBITDA (1) | $ | 4,727 | | $ | 4,943 | | (4 | %) | $ | 13,490 | | $ | 11,344 | | 19 | % | | EBITDA (1) as a % of revenue | | 15 | % | | 20 | % | (25 | %) | | 15 | % | | 17 | % | (12 | %) | | Service hours (2) | | 29,298 | | | 24,680 | | 19 | % | | 85,806 | | | 67,307 | | 27 | % | | Canada | | 13,702 | | | 13,412 | | 2 | % | | 40,396 | | | 37,229 | | 9 | % | | United States | | 1,405 | | | 2,613 | | (46 | %) | | 5,697 | | | 9,243 | | (38 | %) | | Australia | | 14,191 | | | 8,655 | | 64 | % | | 39,713 | | | 20,835 | | 91 | % | | Revenue per service hour (2) , dollars | $ | 1,075 | | $ | 1,025 | | 5 | % | $ | 1,082 | | $ | 996 | | 9 | % | | Canada | | 893 | | | 958 | | (7 | %) | | 919 | | | 962 | | (4 | %) | | United States | | 934 | | | 861 | | 8 | % | | 921 | | | 883 | | 4 | % | | Australia | | 1,264 | | | 1,179 | | 7 | % | | 1,271 | | | 1,109 | | 15 | % | | Utilization (3) | | 29 | % | | 27 | % | 7 | % | | 29 | % | | 25 | % | 16 | % | | Canada | | 27 | % | | 27 | % | - | | | 27 | % | | 24 | % | 13 | % | | United States | | 13 | % | | 24 | % | (46 | %) | | 17 | % | | 31 | % | (45 | %) | | Australia | | 54 | % | | 33 | % | 64 | % | | 51 | % | | 26 | % | 96 | % | | Rigs, average for period | | 79 | | | 79 | | - | | | 79 | | | 79 | | - | | | Canada | | 55 | | | 55 | | - | | | 55 | | | 56 | | (2 | %) | | United States | | 12 | | | 12 | | - | | | 12 | | | 11 | | 9 | % | | Australia | | 12 | | | 12 | | - | | | 12 | | | 12 | | - | |
(1) See Note 1 of the Notes to the Financial Highlights set forth at the end of this release. (2) Service hours is defined as well servicing hours of service provided to customers and includes paid rig move and standby. (3) T he Company reports its service rig utilization for its operational service rigs in North America based on service hours of 3,650 per rig per year to reflect standard 10 hour operations per day. Utilization for the Company’s service rigs in Australia is calculated based on service hours of 8,760 per rig per year to reflect standard 24 hour operations.
Third quarter WS segment revenue increased in 2025 as compared to 2024 due to increased activity in Australia following the upgrade and reactivation of several service rigs over the past year. Increased revenue from Australian operations was partially offset by lower North American WS segment revenue, particularly in the United States. Segment EBITDA for the third quarter of 2025 was slightly lower compared to 2024 due to lower pricing in Canada and substantially lower utilization in the United States that was partially offset by increased utilization and pricing realized in Australia for reactivated rigs.
Corporate
During the third quarter of 2025, Total Energy continued to execute on its 2025 capital expenditure program with $17.2 million of capital expenditures that was primarily directed towards the upgrade of drilling and service rigs in Australia and Canada. To September 30, 2025, $77.9 million of capital expenditures were funded, including approximately $16.6 million of capital commitments carried forward from 2024 and the acquisition of 280 pieces of rental equipment located in Oklahoma on June 10, 2025 for $9.0 million.
Total Energy exited the third quarter of 2025 with $113.5 million of positive working capital, including $57.1 million of cash, and $85.0 million of available credit under its $175 million of revolving bank credit facilities. At September 30, 2025, bank debt less cash was $32.9 million and the interest rate on the Company’s outstanding bank debt was 4.50%.
During the first nine months of 2025, $24.7 million was returned to shareholders by way of dividends and share repurchases under the Company’s normal course issuer bid. Bank debt was also reduced by $20.9 million during this period.
Outlook
Oil prices remained under pressure during the third quarter of 2025 due to global economic uncertainty and concerns over excess supply. Oil price weakness continues to weigh on North American drilling and completion activity levels, particularly in the United States. Offsetting such weakness are stable Australian industry conditions, improving North American natural gas prices and continued strong North American demand for compression and process equipment. The CPS segment’s record $380.8 million fabrication sales backlog at September 30, 2025 provides visibility well into the second half of 2026.
Certain low margin fabrication projects that were awarded in the second half of 2024 when industry conditions were less favorable negatively impacted third quarter CPS segment profitability when construction on such projects began. These projects are scheduled to be substantially completed by the end of 2025. The CPS segment has also taken steps to mitigate supply chain and other issues arising from the trade dispute between Canada and the United States that have contributed to cost inflation. Those steps include commencement of the previously announced expansion of the CPS segment’s fabrication capacity in Weirton, West Virginia. Plant construction is currently expected to be completed by the first quarter of 2027.
In Canada, the upgrade of an idle mechanical double drilling rig to a state of the art AC electric triple pad rig was completed in early November and such rig has commenced drilling operations for a major Canadian producer in the Alberta Montney formation. Should the rig’s operational and financial performance meet expectations, the Company will consider additional upgrade opportunities for similar idle rigs subject to market conditions.
In Australia, the upgrade of an idle drilling rig acquired as part of the Saxon acquisition in 2024 is near completion and such rig is expected to commence drilling operations under a long term contract by the end of November, 2025. This will bring the Company’s active Australian drilling rig count to 13 rigs, the highest ever. In addition, an idle Australian service rig is currently being upgraded and is expected to commence operations by the second quarter of 2026.
Total Energy’s current capital expenditure commitments total $119.0 million and includes the Company’s 2025 capital budget of $102.4 million and $16.6 million of capital commitments carried forward from 2024. To September 30, 2025 $77.9 million of such commitments have been funded, with the remaining $41.1 million to be funded with cash on hand and cashflow.
Conference Call
At 9:00 a.m. (Mountain Time) on November 13, 2025 Total Energy will conduct a conference call and webcast to discuss its third quarter financial results. Daniel Halyk, President & Chief Executive Officer, will host the conference call. A live webcast of the conference call will be accessible on Total Energy’s website at www.totalenergy.ca by selecting “Webcasts”. Persons wishing to participate in the conference call may do so by calling (800) 715-9871 or (647) 932-3411. Those who are unable to listen to the call live may listen to a recording of it on Total Energy’s website. A recording of the conference call will also be available until December 13, 2025 by dialing (800) 770-2030 (passcode 1002576).
Selected Financial Information
Selected financial information relating to the three and nine months ended September 30, 2025 and 2024 is included in this news release. This information should be read in conjunction with the condensed interim consolidated financial statements of Total Energy and the notes thereto as well as management’s discussion and analysis to be issued in due course and in the Company’s 2024 Annual Report.
Consolidated Statements of Financial Position (in thousands of Canadian dollars)
| | | | September 30 | | December 31 | | | | | | | 2025 | | 2024 | | | | | | | (unaudited) | | (audited) | | | | Assets | | | | | | | | | Current assets: | | | | | | | | | Cash and cash equivalents | | $ | 57,087 | | $ | 38,419 | | | Accounts receivable | | | 161,605 | | | 149,048 | | | Inventory | | | 136,965 | | | 104,091 | | | Prepaid expenses and deposits | | | 21,010 | | | 17,640 | | | | | | 376,667 | | | 309,198 | | | | | | | | | | | | Property, plant and equipment | | | 633,410 | | | 622,499 | | | Deferred income tax asset | | | 1,257 | | | 1,958 | | | Goodwill | | | 4,053 | | | 4,053 | | | | | $ | 1,015,387 | | $ | 937,708 | | | | | | | | | | | | Liabilities & Shareholders' Equity | | | | | | | | | Current liabilities: | | | | | | | | | Accounts payable and accrued liabilities | | $ | 167,093 | | $ | 125,106 | | | Deferred revenue | | | 80,417 | | | 47,225 | | | Contingent consideration on business acquisition | | | 1,752 | | | 2,878 | | | Income taxes payable | | | 3,693 | | | 4,508 | | | Dividends payable | | | 3,705 | | | 3,429 | | | Current portion of lease liabilities | | | 6,472 | | | 6,368 | | | Current portion of long-term debt | | | - | | | 40,947 | | | | | | 263,132 | | | 230,461 | | | | | | | | | | | | Long-term debt | | | 90,000 | | | 70,000 | | | | | | | | | | | | Lease liabilities | | | 8,197 | | | 9,171 | | | | | | | | | | | | Deferred income tax liability | | | 59,947 | | | 57,033 | | | | | | | | | | | | Shareholders' equity: | | | | | | | | | Share capital | | | 232,264 | | | 239,269 | | | Contributed surplus | | | 5,790 | | | 5,279 | | | Accumulated other comprehensive loss | | | (14,304 | ) | | (11,219 | ) | | Non-controlling interest | | | 286 | | | 245 | | | Retained earnings | | | 370,075 | | | 337,469 | | | | | | 594,111 | | | 571,043 | | | | | | | | | | | | | | $ | 1,015,387 | | $ | 937,708 | | | | | | | | | | |
Consolidated Statements of Income (in thousands of Canadian dollars except per share amounts) (unaudited)
| | | | Three months ended September 30 | | Nine months ended September 30 | | | | | | | | | | | | | 2025 | | 2024 | | 2025 | | 2024 | | | | | | | | | | | | | | | | | | | | | Revenue | | $ | 260,702 | | $ | 241,940 | | $ | 763,027 | | $ | 659,960 | | | | | | | | | | | | | | | | | | Cost of services | | | 203,044 | | | 178,530 | | | 583,858 | | | 491,092 | | | Selling, general and administration | | | 13,571 | | | 13,337 | | | 40,877 | | | 37,512 | | | Other income | | | (543 | ) | | (844 | ) | | (1,232 | ) | | (720 | ) | | Share-based compensation | | | 1,983 | | | 518 | | | 2,795 | | | 1,940 | | | Depreciation | | | 23,295 | | | 23,091 | | | 69,000 | | | 66,186 | | | Operating income | | | 19,352 | | | 27,308 | | | 67,729 | | | 63,950 | | | | | | | | | | | | | | | | | | Gain on sale of property, plant and equipment | | | 260 | | | 144 | | | 2,062 | | | 1,144 | | | Finance costs, net | | | (1,195 | ) | | (2,330 | ) | | (3,921 | ) | | (6,318 | ) | | Net income before income taxes | | | 18,417 | | | 25,122 | | | 65,870 | | | 58,776 | | | | | | | | | | | | | | | | | | Current income tax expense | | | 3,248 | | | 2,072 | | | 10,916 | | | 7,090 | | | Deferred income tax expense | | | 585 | | | 3,344 | | | 4,332 | | | 1,063 | | | Total income tax expense | | | 3,833 | | | 5,416 | | | 15,248 | | | 8,153 | | | | | | | | | | | | | | | | | | Net income | | $ | 14,584 | | $ | 19,706 | | $ | 50,622 | | $ | 50,623 | | | | | | | | | | | | | | | | | | Net income (loss) attributable to: | | | | | | | | | | | | | | | Shareholders of the Company | | $ | 14,504 | | $ | 19,731 | | $ | 50,581 | | $ | 50,685 | | | Non-controlling interest | | | 80 | | | (25 | ) | | 41 | | | (62 | ) | | | | | | | | | | | | | | | | | Income per share | | | | | | | | | | | | | | | Basic | | $ | 0.39 | | $ | 0.51 | | $ | 1.35 | | $ | 1.29 | | | Diluted | | $ | 0.38 | | $ | 0.50 | | $ | 1.33 | | $ | 1.26 | | | | | | | | | | | | | | | | |