STEP Energy Services issued the following announcement on Mar. 12
STEP Energy Services Ltd. (the “Company” or “STEP”) is pleased to announce its financial and operating results for the three and twelve months ended December 31, 2019. The following press release should be read in conjunction with the management’s discussion and analysis (“MD&A”) and audited consolidated financial statements as at and for the year ended December 31, 2019. The above documents are available on STEP’s website at www.stepenergyservices.com or on SEDAR at www.sedar.com.
MESSAGE FROM THE PRESIDENT
“Our 2019 strategy recognized that continued pricing pressure for our services necessitated a reduction in our operating costs, a diligent focus on finding efficiencies in our business and alignment with clients, with larger scope projects, to drive stronger utilization of our assets,” commented Regan Davis, President and CEO. “I am very pleased with the results STEP delivered as we managed capital spending, maximized cash flow and reduced our outstanding debt. I extend a genuine thanks to all our professionals who worked diligently to increase the quality and predictability of our field execution while maintaining a resolute focus on safe operations. We have undoubtedly demonstrated that we are a best-in-class service provider.” Davis adds, “Despite the geopolitical and economic uncertainties that continue to impact our sector, we enter 2020 with an ongoing commitment to find further cost efficiencies, maintain our emphasis on safe operations, and execute flawlessly in every facet of our business.”
FINANCIAL
| ($000s except percentages and | Three months ended | Years ended | ||||||||||||||||||||
| per share amounts) | December 31, | December 31, | September 30, | December 31, | ||||||||||||||||||
| 2019 | 2018 | 2019 | 2019 | 2018 | 2017 | |||||||||||||||||
| Consolidated revenue | $ | 126,507 | $ | 169,028 | $ | 178,745 | $ | 668,297 | $ | 781,763 | $ | 553,220 | ||||||||||
| Net (loss) income | $ | (24,411) | $ | (58,549) | $ | (112,843) | $ | (143,883) | $ | (39,304) | $ | 57,718 | ||||||||||
| Per share-basic | $ | (0.37) | $ | (0.88) | $ | (1.69) | $ | (2.16) | $ | (0.60) | $ | 1.02 | ||||||||||
| Per share-diluted | $ | (0.37) | $ | (0.88) | $ | (1.69) | $ | (2.16) | $ | (0.60) | $ | 1.00 | ||||||||||
| Weighted average shares – basic | 66,850,775 | 66,621,937 | 66,767,919 | 66,763,210 | 65,033,085 | 56,528,016 | ||||||||||||||||
| Weighted average shares – diluted | 66,850,775 | 66,621,937 | 66,767,919 | 66,763,210 | 65,033,085 | 57,752,867 | ||||||||||||||||
| Adjusted EBITDA (1) | $ | 9,165 | $ | 12,302 | $ | 22,690 | $ | 78,809 | $ | 117,637 | $ | 123,584 | ||||||||||
| Adjusted EBITDA % (1) | 7% | 7% | 13% | 12% | 15% | 22% | ||||||||||||||||
| ($000s except shares and per share amounts) | ||||||||||||
| As at December 31, | 2019 | 2018 | 2017 | |||||||||
| Cash and cash equivalents | $ | 7,267 | $ | 364 | $ | 36,859 | ||||||
| Working capital (including cash and cash equivalents) (2) | $ | 72,156 | $ | 67,158 | $ | 121,032 | ||||||
| Total assets | $ | 686,039 | $ | 887,908 | $ | 533,845 | ||||||
| Total long-term financial liabilities (2) | $ | 247,481 | $ | 260,451 | $ | 8,049 | ||||||
| Net debt (2) | $ | 232,552 | $ | 254,210 | $ | n/a | ||||||
| Shares outstanding | 66,942,830 | 66,682,319 | 60,309,738 | |||||||||
2019 RESULTS
Through the efforts of STEP’s professionals, the Company maintained high levels of operating execution and efficiency, having finished the year with strong margins despite ongoing industry headwinds. Exploration and production clients continued to demonstrate capital budget discipline, using surplus cash flows to return capital to shareholders through dividends or share-buy backs rather than increasing capital budgets. 2019 activity, as evidenced by the Baker Hughes North American land rig count, was down 13% when compared to 2018. In the fourth quarter, many operators experienced budget exhaustion reducing demand for services, however the Company was able to align with active clients to maintain utilization. This resulted in an oversupplied market which put service pricing under pressure and resulted in weaker financial performance for the Company. Due to the decreased demand, the industry has parked equipment in efforts to help balance the market.
Management took actions throughout 2019 to adjust to the market environment and position the Company for success. In the year, the Company focused on executing work programs for large clients with active and stable work programs. This allowed the Company to drive utilization and increase efficiencies in operations. There was also success in deploying assets to areas of greater activity, including opening a new coiled tubing operation in North Dakota towards the end of the year. The Company’s emphasis on cost control, focus on improving pumping efficiencies and relocating assets to create new opportunities allowed the Company to maintain positive margins and generate improved year to date margins from Canadian operations relative to 2018. Throughout 2019, STEP concentrated on optimizing costs by implementing changes to salary and benefits and reducing overhead and selling, general and administrative spending. Employee headcount decreased by 13% as the Company rightsized the deployed equipment fleet to meet demand. STEP made select capital investments including expanding our dual fuel fleet, developing and trialing our auto start/stop technology as well as operational changes related to maintenance activities, fluid chemistries and engineering processes that will enable us to reduce greenhouse gas emissions and lessen the environmental impact from operations.
Net debt decreased by $21.7 million to $232.6 million at December 31, 2019 as all cash flow remaining after capital, interest, lease obligation payments and working capital changes was directed to repayment of debt. As of January 22, 2020, the Company entered into an agreement with its syndicate of lenders to make an amendment to its credit facilities in order to provide increased financial flexibility. The amendment was a change to the required Funded Debt to EBITDA Ratio (as defined in the capital management section of the MD&A). Available financial resources as at December 31, 2019 were $116.7 million, consisting of cash and cash equivalents and the remaining capacity on the credit facilities.
Effective January 1, 2019, the Company implemented the following accounting changes:
- IFRS 16 replaces existing lease guidance including IAS 17, Leases. IFRS 16 requires the recognition of most leases previously recognized as operating leases onto the statement of financial position. These are recognized as right-of-use assets and additional lease liabilities. See the "New Accounting Pronouncements" section of the MD&A for more details.
- The Company reorganized the composition of its operating segment disclosure to reflect how management makes strategic decisions and assesses the performance of the Company’s operations. Corporate activities are now separated from Canadian and U.S. Operations. The Company has reclassified prior period information to align with the new composition of operating segments.
- Consolidated revenue for the year ended December 31, 2019 of $668.3 million decreased by 15% from $781.8 million in the prior year primarily due to lower industry activity, and its impact on pricing, partially offset by a full twelve-month contribution of the U.S. fracturing operations compared to nine months in 2018. As evidenced by the reduction in year over year average Canadian land rig activity of 30% and U.S. land rig activity decline of 9%, market demand fell through the year, negatively impacting utilization and putting pressure on revenue per day. Revenue per day was also impacted by the ongoing trend of client supplied proppant. In 2019, clients supplied 41% of the consolidated proppant pumped, up from 13% in 2018.
- For the year ended December 31, 2019, Adjusted EBITDA decreased by 33% compared to the prior year primarily due to decreased revenue and the resulting margin compression. Operating and selling, general and administrative expenses declined due to the cost control initiatives implemented. Adjusted EBITDA % (see chart on page 1 and Non-IFRS measures) for the year was 12% compared to 15% for 2018, again reflecting the Company’s ability to preserve margin in a difficult operating environment.
- During the third quarter of 2019, the Company recorded a non-cash impairment charge with respect to goodwill and intangible assets in the U.S. fracturing segment of $113.5 million.
- During the fourth quarter of 2019, the Company committed to sell a group of assets. The Company classified these assets as held for sale at December 31, 2019. As such, these assets must be reflected at the lower of their carrying amount and estimated fair value less costs to sell. An impairment charge of $13.7 million was recorded as a result.
- Net loss for the year ended December 31, 2019 was $143.9 million, compared to net loss of $39.3 million in 2018. Net loss in 2019 was primarily the result of the impairment to goodwill and intangible assets as well as slowing market activity contributing to margin compression combined with increased depreciation in 2019.
- Quarterly consolidated revenue for the three months ended December 31, 2019 was $126.5 million compared to $169.0 million in the same quarter of 2018. The 25% decrease in quarterly revenue was primarily attributable to lower revenue per day as a result of pricing pressure from increasing competition and the impact of client supplied proppant. Consolidated fracturing and coiled tubing operating days increased by 19% and 8% respectively when comparing the fourth quarter of 2019 to 2018. Activity in the fourth quarter of 2018 was negatively impacted by a sharp decrease in commodity price realized by Canadian producers that wasn’t repeated in 2019. Although quarterly consolidated revenue fell versus the prior year, operating days were strong relative to an overall reduction in rig activity of 23% in Canada and 24% in the U.S. in the fourth quarter of 2019 compared to the previous year fourth quarter.
- Quarterly Adjusted EBITDA was $9.2 million (or 7% of revenue) in the fourth quarter of 2019 compared to $12.3 million (or 7%) in the same quarter of 2018. Quarterly Adjusted EBITDA % was maintained despite lower revenue per day. The Company successfully managed operating expense and equipment utilization to offset the pricing compression and preserve margins. Consolidated selling, general and administrative expenses decreased due to cost saving initiatives implemented in the year.
- As a result, net loss for the three months ended December 31, 2019 was $24.4 million compared to net loss of $58.5 million the fourth quarter of 2018. The decreased net loss was primarily a result of the impairment booked in the fourth quarter of 2018 offset by lower operating results in 2019.
- Quarterly consolidated revenue for the three months ended December 31, 2019 of $126.5 million decreased from $178.7 million in the third quarter of 2019. The 28% decrease in quarterly revenue was primarily attributable to the lower revenue per day combined with budget exhaustion resulting in fewer operating days worked. Revenue per day was lower in the quarter because the job mix observed in Canada had less pumping intensity than the previous quarter and the proportion of client supplied proppant increased in the U.S.
- Lower revenue impacted Adjusted EBITDA %, resulting in a decrease of 6 percentage points from the third quarter 2019. Operating and selling, general and administrative costs reduced in the quarter from the initiatives outline above, however this was not enough to offset revenue declines.
- Net loss for the three months ended December 31, 2019 decreased compared to the third quarter due to the impairment booked in the third quarter offset by lower operating results in the fourth quarter.
During the fourth quarter of 2019, commodity prices remained volatile with West Texas Intermediate (“WTI”) crude prices starting the quarter at approximately US$54 per barrel. WTI rose to almost US$62 per barrel by the end of the year. However, STEP’s clients remained focused on maintaining capital discipline and market activity fell as clients experienced budget exhaustion as they completed their 2019 capital programs. This resulted in decreased drilling and completion spending and lower demand for completion services. Throughout 2019, service providers have made significant reductions in manned equipment in both Canada and the U.S. in response to lower activity.
In early 2020 in Canada, STEP was able to renew its strategic fracturing work programs from 2019 with similar-to-larger work scopes. In addition, the Company added another large fracturing work program with a large client while retaining other key clients. STEP’s suite of technologies continues to be a differentiator as the Company retained and added key coiled tubing clients. In the U.S., STEP was able to retain major work programs for fracturing operations and executed on the goal of obtaining more consistent work programs. For coiled tubing, STEP was awarded first call options with large clients across the Permian, Eagle Ford and the newly opened operations in the Bakken.
Recently, global trade, geopolitical and economic uncertainty have begun to impact global oil supply and demand outlook. Commodity prices were volatile in the first two months of 2020 with WTI oil prices falling 27% to approximately US$45 per barrel at the end of February 2020. The decline in oil price was primarily due to uncertainty around the impact that the COVID-19 outbreak will have on global oil demand. Most recently, an impasse within OPEC+ regarding future cooperation on production cuts has enhanced market uncertainty and negatively impacted commodity prices, resulting in WTI at approximately US$33 per barrel. These developments have amplified the earlier uncertainty bringing further ambiguity to the outlook for 2020. Extreme volatility in commodity prices has reinforced caution amongst STEP’s clients’ spending plans and could potentially lead to a deferral or cancelation of completion programs.
The Company believes these emerging issues will have a negative impact on demand for services, client capital spending and activity levels. The full extent of these events on the oil field services market and STEP is currently unfolding and is uncertain. STEP is reacting quickly to the emerging market challenges and will continue to monitor the markets, diligently manage costs and engage with clients. Additionally, STEP will adjust the amount of manned equipment deployed to optimize utilization in changing market conditions.
CAPITAL UPDATE
The amended 2019 capital program was $44 million and consisted primarily of maintenance, optimization and reliability spending. Spending on the 2019 capital program was on budget as the company incurred $38 million in the year and will carry-forward approximately $6 million to 2020.
In February 2020, STEP’s board of directors approved a 2020 capital program of $47 million based on expected work activity. The approved capital program was evenly split between Canada and the U.S. and was comprised of $42 million for maintenance capital to sustain operating equipment deployed and $5 million to support several equipment optimization programs.
With the current market uncertainty, management will evaluate and balance the Company’s manned equipment fleet and capital program with market conditions and demand for STEP’s services and will suspend or cancel expenditures as warranted.
OPERATIONS
During the fourth quarter, Canadian operations contributed stronger Adjusted EBITDA and Adjusted EBITDA % compared to last year through higher utilization and effective cost management, despite tougher market conditions. Both fracturing and coiled tubing services increased operating days and utilization over last year’s fourth quarter, as budget exhaustion, holiday impacts and activity level declines were not as pronounced in December as witnessed in the prior year.
Similar to the Canadian operations, U.S. fracturing increased operating days and utilization over last year’s fourth quarter as coiled tubing activity remained largely the same. STEP’s ability to pivot assets to areas of higher activity allowed STEP to broaden its client base and support stronger utilization. Utilization and activity levels were offset by market pricing pressure, which impacted the fourth quarter’s results.
CANADIAN OPERATIONS REVIEW
STEP maintains a fleet of 16 coiled tubing units in the WCSB, of which nine were operating at December 31, 2019. The Company’s coiled tubing units are designed to service the deepest wells in the region. STEP’s fracturing business is primarily focused on the deeper, more technically challenging plays in Alberta and northeast British Columbia, with growing exposure to oilier plays in eastern Alberta and southern Saskatchewan. Canadian operations currently include six fracturing spreads representing 225,000 HP (including approximately 132,500 HP with dual fuel capabilities). STEP has an additional 57,500 HP available for deployment, 15,000 HP of which will require capital for maintenance and refurbishment. The Company will deploy or idle coiled tubing or fracturing units as dictated by the market’s ability to support targeted utilization and pricing.
| ($000’s except per day, days, units, proppant pumped and HP) | Three months ended | Years ended | |||||||||||||||
| December 31, | December 31, | September 30, | December 31, | ||||||||||||||
| 2019 | 2018(4) | 2019 | 2019 | 2018(4) | |||||||||||||
| Revenue: | |||||||||||||||||
| Fracturing | $ | 50,215 | $ | 73,814 | $ | 65,754 | $ | 251,544 | $ | 350,628 | |||||||
| Coiled tubing | 22,285 | 23,942 | 32,080 | 103,120 | 128,260 | ||||||||||||
| 72,500 | 97,756 | 97,834 | 354,664 | 478,888 | |||||||||||||
| Expenses: | |||||||||||||||||
| Operating expenses | 75,546 | 96,719 | 84,149 | 333,127 | 430,423 | ||||||||||||
| Selling, general and administrative | 1,718 | 4,186 | 2,453 | 8,955 | 15,845 | ||||||||||||
| Results from operating activities | $ | (4,764) | $ | (3,149) | $ | 11,232 | $ | 12,582 | $ | 32,620 | |||||||
| Add non-cash items: | |||||||||||||||||
| Depreciation | 13,659 | 11,824 | 11,319 | 50,716 | 44,129 | ||||||||||||
| Share-based compensation | 506 | 321 | 534 | 1,915 | 2,232 | ||||||||||||
| Adjusted EBITDA (1) | $ | 9,401 | $ | 8,996 | $ | 23,085 | $ | 65,213 | $ | 78,981 | |||||||
| Adjusted EBITDA % (1) | 13% | 9% | 24% | 18% | 16% | ||||||||||||
| Sales mix (% of segment revenue) | |||||||||||||||||
| Fracturing | 69% | 76% | 67% | 71% | 73% | ||||||||||||
| Coiled tubing | 31% | 24% | 33% | 29% | 27% | ||||||||||||
| Fracturing services | |||||||||||||||||
| Fracturing revenue per operating day(1) | $ | 145,551 | $ | 245,230 | $ | 186,272 | $ | 185,368 | $ | 245,195 | |||||||
| Number of fracturing operating days (2) | 345 | 301 | 353 | 1,357 | 1,430 | ||||||||||||
| Proppant pumped (tonnes) | 183,000 | 192,000 | 255,000 | 858,000 | 701,000 | ||||||||||||
| Stages completed | 4,064 | 3,148 | 3,768 | 13,424 | 14,551 | ||||||||||||
| Horsepower (“HP”) | |||||||||||||||||
| Active pumping HP, end of period | 225,000 | 225,000 | 225,000 | 225,000 | 225,000 | ||||||||||||
| Idle pumping HP, end of period | 57,500 | 72,500 | 72,500 | 57,500 | 72,500 | ||||||||||||
| Total pumping HP, end of period (3) | 282,500 | 297,500 | 297,500 | 282,500 | 297,500 | ||||||||||||
| Coiled tubing services | |||||||||||||||||
| Coiled tubing revenue per operating day(1) | $ | 39,583 | $ | 49,775 | $ | 53,916 | $ | 48,187 | $ | 46,420 | |||||||
| Number of coiled tubing operating days (2) | 563 | 481 | 595 | 2,140 | 2,763 | ||||||||||||
| Active coiled tubing units, end of period | 9 | 9 | 9 | 9 | 9 | ||||||||||||
| Idle coiled tubing units, end of period | 7 | 5 | 7 | 7 | 5 | ||||||||||||
| Total coiled tubing units, end of period | 16 | 14 | 16 | 16 | 14 | ||||||||||||
(2) An operating day is defined as any coiled tubing and fracturing work that is performed in a 24-hour period, exclusive of support equipment.
(3) Represents total owned HP in Canada, of which 225,000 HP is currently deployed and some of the remainder requires certain maintenance and refurbishment.
(4) 2018 amounts were reclassified asthe Company reorganized the composition of its operating segments. See “Corporate review” section.
FINANCIAL HIGHLIGHTS – FULL YEAR
Revenue for the year ended December 31, 2019 was $354.7 million compared to $478.9 million for the same period in 2018. The decrease in annual revenue was primarily due to an ongoing industry slowdown in the WCSB with the average Canadian land rig count decreasing approximately 30% over 2018. Fracturing operations worked 5% fewer days in 2019 compared to 2018 as increased fracturing intensity partially offset the decline in activity. Revenue per day decreased by 24% year over year, as clients provided approximately 58% of the proppant pumped in the year compared to 20% in the prior year. Client supplied proppant reduces revenue but yields higher margins. Coiled tubing operating days decreased by 23% in 2019 compared to 2018, consistent with the decline in land rig count. However, coiled tubing revenue per day was higher as revenue from ancillary product lines did not show similar declines. Adjusted EBITDA decreased from $79.0 million (or 16% of revenue) in 2018 to $65.2 million (or 18%) in 2019. Despite the reduction in activity and increased pricing pressure, Adjusted EBITDA % improved year over year as operating and selling, general and administrative costs decreased due to field efficiencies, management of manned equipment and cost controls. Throughout 2019, STEP controlled costs by implementing changes to staffing costs and reduced overhead and selling, general and administrative spending.
FINANCIAL HIGHLIGHTS – FOURTH QUARTER
Revenue for the three months ended December 31, 2019 was $72.5 million compared to $97.8 million for the fourth quarter of 2018. In fracturing, the Company experienced reduced revenue per day as clients self-supplied 60% of the proppant pumped in the quarter, which reduces revenue for the job. A shift in job mix to less intense work in the quarter also impacted revenue per day. Fracturing and coiled tubing operating days increased by 15% and 17%, respectively, when compared to 2018 as the activity in the fourth quarter of 2018 was negatively impacted by a decrease in commodity price realized by Canadian producers that wasn’t experienced in 2019. Coiled tubing also faced pricing pressure as competition increased for limited work with revenue per day decreasing by 20%. Adjusted EBITDA for the three months ended December 31, 2019 was $9.4 million (or 13% of revenue) compared to $9.0 million (or 9%) in 2018. Despite pricing pressure, Adjusted EBITDA % percentage increased on a quarterly basis due to the focus on cost control and efficiencies outlined above.
FINANCIAL HIGHLIGHTS – SEQUENTIAL QUARTER
Revenue for the three months ended December 31, 2019 decreased 26% from the quarter ended September 30, 2019 as the industry was again faced with budget exhaustion as clients depleted budgets prior to year end. In fracturing, the fourth quarter was impacted by a shift of work to a less intense job type and an increased proportion of client supplied proppant, leading to lower realized revenue per day. Additionally, coiled tubing revenue per day was impacted by reduced activity and lower pricing. The lower revenue impacted Adjusted EBITDA %, decreasing 11 percentage points from the third quarter 2019. Operating and selling, general and administrative costs decreased in the quarter from the initiatives outlined above, however this was not enough to offset revenue declines.
OPERATING HIGHLIGHTS
- The Company staffed six fracturing spreads with active horsepower of 225,000 in the fourth quarter.
- STEP capitalizes fluid ends when their estimated useful life exceeds 12 months. Fluid ends are capitalized in Canada based on a review of usage history. However, had the Company expensed fluid ends, the operating expenses for the three months and year ended December 31, 2019 would have been increased by approximately $0.9 million and $6.6 million, respectively.
- The Company staffed an average of nine coiled tubing units throughout the fourth quarter of 2019.
STEP’s U.S. business commenced operations in 2015 with coiled tubing services. At December 31, 2019, STEP maintained a fleet of 13 coiled tubing units, of which eight units were operating in the Permian and Eagle Ford basins in Texas and the Bakken shale in North Dakota. On April 2, 2018, STEP closed the Tucker Acquisition, which established its U.S. fracturing operations. The U.S. fracturing operations consist of 207,500 HP, 157,500 HP of which is deployed as three spreads operating in the Permian and Eagle Ford basins in Texas. Management continues to adjust capacity and regional deployment to optimize utilization, efficiency and returns.
| ($000’s except per day, days, units, proppant pumped and HP) | Three months ended | Year ended | |||||||||||||||
| December 31, | December 31, | September 30, | December 31, | ||||||||||||||
| 2019 | 2018(4) | 2019 | 2019 | 2018(4) | |||||||||||||
| Revenue: | |||||||||||||||||
| Fracturing | $ | 35,316 | $ | 49,270 | $ | 56,835 | $ | 217,543 | $ | 202,873 | |||||||
| Coiled tubing | 18,691 | 22,002 | 24,076 | 96,090 | 100,002 | ||||||||||||
| 54,007 | 71,272 | 80,911 | 313,633 | 302,875 | |||||||||||||
| Expenses: | |||||||||||||||||
| Operating expenses | 63,976 | 74,253 | 86,576 | 326,078 | 284,455 | ||||||||||||
| Selling, general and administrative | 1,995 | 1,695 | 2,946 | 10,444 | 7,068 | ||||||||||||
| Results from operating activities | $ | (11,964) | $ | (4,676) | $ | (8,611) | $ | (22,889) | $ | 11,352 | |||||||
| Add non-cash items: | |||||||||||||||||
| Depreciation | 13,774 | 13,144 | 11,859 | 49,374 | 39,464 | ||||||||||||
| Share-based compensation | 365 | 349 | 521 | 2,094 | 2,116 | ||||||||||||
| Adjusted EBITDA (1) | $ | 2,175 | $ | 8,817 | $ | 3,769 | $ | 28,579 | $ | 52,932 | |||||||
| Adjusted EBITDA % (1) | 4% | 12% | 5% | 9% | 18% | ||||||||||||
| Sales mix (% of segment revenue) | |||||||||||||||||
| Fracturing | 65% | 69% | 70% | 69% | 67% | ||||||||||||
| Coiled tubing | 35% | 31% | 30% | 31% | 33% | ||||||||||||
| Fracturing services | |||||||||||||||||
| Fracturing revenue per operating day(1) | $ | 223,519 | $ | 400,568 | $ | 336,302 | $ | 338,325 | $ | 403,325 | |||||||
| Number of fracturing operating days (2) | 158 | 123 | 169 | 643 | 503 | ||||||||||||
| Proppant pumped (tonnes) | 177,000 | 96,000 | 171,000 | 667,000 | 369,000 | ||||||||||||
| Stages completed | 934 | 675 | 994 | 3,539 | 2,515 | ||||||||||||
| Horsepower | |||||||||||||||||
| Active pumping HP, end of period | 157,500 | 142,500 | 142,500 | 157,500 | 142,500 | ||||||||||||
| Idle pumping HP, end of period | 50,000 | 50,000 | 50,000 | 50,000 | 50,000 | ||||||||||||
| Total pumping HP, end of period (3) | 207,500 | 192,500 | 192,500 | 207,500 | 192,500 | ||||||||||||
| Coiled tubing services | |||||||||||||||||
| Coiled tubing revenue per operating day(1) | $ | 44,083 | $ | 51,168 | $ | 44,585 | $ | 47,288 | $ | 52,550 | |||||||
| Number of coiled tubing operating days (2) | 424 | 430 | 540 | 2,032 | 1,903 | ||||||||||||
| Active coiled tubing units, end of period | 8 | 8 | 8 | 8 | 8 | ||||||||||||
| Idle coiled tubing units, end of period | 5 | 4 | 5 | 5 | 4 | ||||||||||||
| Total coiled tubing units, end of period | 13 | 12 | 13 | 13 | 12 | ||||||||||||
(2) An operating day is defined as any coiled tubing and fracturing work that is performed in a 24-hour period, exclusive of support equipment.
(3) Represents total owned HP in the U.S.,some of which will require capital for maintenance and refurbishment.
(4) 2018 amounts were reclassified asthe Company reorganized the composition of its operating segments. See “Corporate review” section.
FINANCIAL HIGHLIGHTS – FULL YEAR
For the year ended December 31, 2019 revenue was $313.6 million, a 4% increase from $302.9 million in 2018. The year to date increase in revenue of $10.8 million was primarily due to the operation of the U.S. fracturing assets for twelve months in 2019 versus only nine months in the prior year. A slow down in activity in the U.S. fracturing market and the increased proportion of client supplied proppant impacted revenue per day which fell by 16% compared to 2018. Coiled tubing worked 129 additional days in 2019 compared to 2018 due to more equipment deployed on average over the period while revenue per day decreased due to pressure on price from new entrants to the market. Adjusted EBITDA decreased by $24.4 million or 46% over the period primarily due to pricing pressure. Operating expenses and selling, general and administrative expenses increased modestly as a result of the full year of fracturing administration, partially offset by cost saving initiatives.
FINANCIAL HIGHLIGHTS – FOURTH QUARTER
Revenue of $54.0 million in the three months ended December 31, 2019 decreased by $17.3 million from the same quarter in 2018. The fourth quarter of 2019 saw an increase in the proportion of client supplied proppant with 54% of sand pumped being supplied by the client. Client supplied proppant decreases revenue and operating expenses and contributed to a 44% decrease in revenue per day in the fourth quarter. Fracturing services worked 29% more operating days in the fourth quarter of 2019 compared to 2018 due to the redistribution of spreads earlier in the year to more active basins. Coiled tubing worked approximately the same number of days in the fourth quarter of 2019 compared to 2018, however, market pressure continues to weigh on pricing with day rates declining 14% compared to fourth quarter 2018. New entrants to the coiled tubing market increased competition in the fourth quarter, and management responded by leveraging client relationships and relocating assets to new areas to maintain utilization. Adjusted EBITDA for the fourth quarter 2019 was $2.2 million (or 4% of revenue) compared to $8.8 million (or 12%) for the same quarter in the prior year. Operating expenses declined through management’s cost saving initiatives. The Adjusted EBITDA percentage decline was primarily due to the pricing pressure across all service lines.
FINANCIAL HIGHLIGHTS – SEQUENTIAL QUARTER
In the U.S., seasonality is generally not a factor and the prior quarter is often utilized when comparing financial results. Revenue and Adjusted EBITDA decreased by 33% and 42%, respectively compared to the prior quarter. Clients faced pronounced budget exhaustion in the fourth quarter, resulting in a 7% and 22% decline in operating days for fracturing and coiled tubing, respectively, when compared to the third quarter of 2019. Day rates for fracturing services were impacted by the proportion of client supplied proppant in the quarter. Despite the decrease in revenue, Adjusted EBITDA % only decreased by one percentage point as operating costs decreased as a result of cost saving initiatives undertaken during the year.
OPERATING HIGHLIGHTS
- Three fracturing spreads were staffed and deployed during the fourth quarter utilizing 157,500 HP.
- In the fourth quarter, STEP pumped 177,000 tonnes (391 million pounds) of proppant over 934 stages (190 tonnes/stage) compared to the fourth quarter of 2018 where the Company pumped 96,000 tonnes (211 million pounds) of proppant over 675 stages (142 tonnes/stage).
- During the year ended December 31, 2019, U.S. fracturing pumped an average of 188 tonnes/stage compared to 147 tonnes/stage for 2018, demonstrating increasing intensity of fracturing work.
- STEP capitalizes fluid ends when it is determined that they have an estimated useful life that exceeds 12 months. Based on a review of usage history in the U.S., fluid ends are expensed. U.S. fracturing expensed fluid ends for the three months and year ended December 31, 2019 of $1.1 million (U.S. $0.9 million) and $9.3 million (U.S. $7.0 million), respectively.
- U.S. coiled tubing staffed an average of eight units in the fourth quarter of 2019. Additional capacity came to the market and resulted in increased competition and decreased utilization and pricing.
Effective January 1, 2019, the Company reorganized the composition of its operating segments to reflect how management makes strategic decisions and assesses the performance of the Company’s operations. Corporate activities are separated from Canadian and U.S. Operations. Corporate operating expenses include expenses related to asset reliability, maintenance and optimization teams. Corporate selling, general and administrative costs include costs associated with the executive team, Board of Directors, and other activities that benefit Canadian and U.S. operating segments collectively. The Company has reclassified prior period information to align with the new composition of operating segments and has identified such reclassification where applicable.
| ($000’s) | Three months ended | Year ended | |||||||||||||||
| December 31, | December 31, | September 30, | December 31, | ||||||||||||||
| 2019 | 2018(3) | 2019 | 2019 | 2018(3) | |||||||||||||
| Expenses: | |||||||||||||||||
| Operating expenses | $ | 529 | $ | 651 | $ | 666 | $ | 2,395 | $ | 2,337 | |||||||
| Selling, general and administrative | 2,951 | 4,915 | 4,478 | 17,024 | 15,441 | ||||||||||||
| Results from operating activities | $ | (3,480) | $ | (5,566) | $ | (5,144) | $ | (19,419) | $ | (17,778) | |||||||
| Add non-cash items: | |||||||||||||||||
| Depreciation | 551 | 145 | 270 | 1,447 | 450 | ||||||||||||
| Share-based compensation | 518 | (90) | 710 | 2,989 | 3,052 | ||||||||||||
| Adjusted EBITDA (1) | $ | (2,411) | $ | (5,511) | $ | (4,164) | $ | (14,983) | $ | (14,276) | |||||||
| Adjusted EBITDA % (1,2) | (2%) | (3%) | (2%) | (2%) | (2%) | ||||||||||||
(2) Adjusted EBITDA percentage calculated using the Consolidated revenue for the period.
(3) 2018 amounts were reclassified asthe Company reorganized the composition of its operating segments.
FINANCIAL HIGHLIGHTS – FULL YEAR
Adjusted EBITDA loss for the year ended December 31, 2019 totalled $15.0 million compared to a $14.3 million loss in 2018. The increased loss was due to a full year of administration of the U.S. fracturing operations. Specifically, increased costs included the transfer of professionals from operating segments to work on corporate initiatives, increased professional fees, integration of information technology data centers and increased system security.
FINANCIAL HIGHLIGHTS – FOURTH QUARTER
Adjusted EBITDA loss for the fourth quarter of 2019 was $2.4 million compared to a $5.5 million loss in the fourth quarter of 2018. Throughout the year, the Company initiated several cost saving programs that have reduced overhead and selling, general and administrative expenses including review of ancillary expenses, adjustment of annual incentive accruals, reduction in consulting expenses, review and curtailment of payroll and benefits as well as right sizing corporate functions earlier in the year.
FINANCIAL HIGHLIGHTS – SEQUENTIAL QUARTER
Corporate Adjusted EBITDA for the fourth quarter of 2019 decreased by $1.8 million or 42% compared to the third quarter of 2019 as corporate cost saving initiatives had begun to show results, primarily due to salary and benefit adjustments and the restriction of consulting expenses.
NON‐IFRS MEASURES
Please see the discussion in the Non‐IFRS Measures section of the MD&A for the reconciliation of non‐IFRS items to IFRS measures.
FORWARD‐LOOKING INFORMATION & STATEMENTS
Certain statements contained in this release constitute “forward-looking statements” or “forward-looking information” within the meaning of applicable securities laws (collectively, “forward-looking statements”). These statements relate to the expectations of management about future events, results of operations and STEP’s future performance (both operational and financial) and business prospects. All statements other than statements of historical fact are forward-looking statements. The use of any of the words “anticipate”, “plan”, “contemplate”, “continue”, “estimate”, “expect”, “intend”, “propose”, “might”, “may”, “will”, “shall”, “project”, “should”, “could”, “would”, “believe”, “predict”, “forecast”, “pursue”, “potential”, “objective” and “capable” and similar expressions are intended to identify forward-looking statements. 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. While STEP believes the expectations reflected in the forward-looking statements included in this release are reasonable, such statements are not guarantees of future performance or outcomes and may prove to be incorrect and should not be unduly relied upon.
In particular, but without limitation, this release contains forward-looking statements pertaining to: 2020 operation outlook; including potential deferral or cancellation of completion programs; supply and demand for oilfield services and industry activity levels, including the Company’s integrated service offerings; OPEC production, related market uncertainty, and its effect on commodity prices; the Company’s anticipated business strategies and expected success; effect of weather conditions on the Company’s operations; expected completions activity, utilization levels and operating margins in 2020; pricing received for the Company’s services; the Company’s capital program in 2020; expected profitability; adequacy of resources to find operations, financial obligation and planned capital expenditures in 2020; ability of the Company to maintain its track record of returns and margin performance; the Company’s expected performance in 2020; future development activities; planned deployment and staffing levels for the Company’s equipment; the Company’s ability to retain existing clients and attract new business; monitoring of industry demand, client capital budgets and market conditions; and on the effect of the COVID-19 outbreak and OPEC related market uncertainty on client work programs and activity in 2020.
The forward-looking information and statements contained in this release reflect several material factors and expectations and assumptions of the Company including, without limitation: the Company will continue to conduct its operations in a manner consistent with past operations; the general continuance of current or, where applicable, assumed industry conditions; pricing of the Company’s services; the Company’s ability to market successfully to current and new clients; the Company’s ability to utilize its equipment; the Company’s ability to collect on trade and other receivables; the Company’s ability to obtain qualified staff and equipment in a timely and cost effective manner; levels of deployable equipment; future capital expenditures to be made by the Company; future funding sources for the Company’s capital program; the Company’s future debt levels; the impact of competition on the Company; the Company’s ability to obtain financing on acceptable terms; the amount of available equipment in the marketplace; and client activity levels. The Company believes the material factors, expectations and assumptions reflected in the forward-looking information and statements are reasonable but no assurance can be given that these factors, expectations and assumptions will prove correct.
Actual results could differ materially from those anticipated in these forward-looking statements due to the risk factors set forth below and elsewhere in this release: volatility of the oil and natural gas industry; excess equipment levels; competition in the oilfield services industry; restrictions on access to capital; reliance on suppliers of raw materials, diesel fuel and component parts; reliance on equipment suppliers and fabricators; direct and indirect exposure to volatile credit markets; fluctuations in currency exchange rates; merger and acquisition activity among the Company’s clients; federal and provincial legislative and regulatory initiatives could result in increased costs and additional operating restrictions or delays; health, safety and environment laws and regulations may require the Company to make substantial expenditures or cause it to incur substantial liabilities; loss of a significant client could cause the Company’s revenue to decline substantially; negative cash flows from operating activities; third party credit risk; hazards inherent in the oilfield services industry which may not be covered to the full extent by the Company’s insurance policies; difficulty in retaining, replacing or adding personnel; seasonal volatility due to adverse weather conditions; reliance on a few key employees; legal proceedings involving the Company; failure to maintain the Company’s safety standards and record; inability to manage growth; failure to continuously improve operating equipment and proprietary fluid chemistries; actual results may differ materially from management estimates and assumptions; and the risk factors set forth under the heading “Risk Factors” in the AIF.
Any financial outlook or future orientated financial information contained in this release regarding prospective financial performance, financial position or cash flows is based on the assumptions about future events, including economic conditions and proposed courses of action based on management’s assessment of the relevant information that is currently available. Projected operational information, including the Company’s capital program, contains forward looking information and is based on a number of material assumptions and factors, as are set out above. These projections may also be considered to contain future oriented financial information or a financial outlook. The actual results of the Company’s operations will likely vary from the amounts set forth in these projections and such variations may be material. Readers are cautioned that any such financial outlook and future oriented financial information contains herein should not be used for purposes other than those for which it is disclosed herein.
The forward‐looking information and statements contained in this release speak only as of the date of the document, and none of the Company or its subsidiaries assumes any obligation to publicly update or revise them to reflect new events or circumstances, except as may be required pursuant to applicable laws. The reader is cautioned not to place undue reliance on forward‐looking information.
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