CALGARY, Alberta–(BUSINESS WIRE)–STEP Energy Services Ltd. (the “Company” or “STEP”) is pleased to announce its financial and operating results for the three months and twelve months ended December 31, 2023. The following press release should be read in conjunction with the management’s discussion and analysis (“MD&A”) and audited consolidated financial statements and notes thereto as at December 31, 2023 (the “Financial Statements”). Readers should also refer to the “Forward-looking information & statements” legal advisory and the section regarding “Non-IFRS Measures and Ratios” at the end of this press release. All financial amounts and measures are expressed in Canadian dollars unless otherwise indicated. Additional information about STEP is available on the SEDAR+ website at www.sedarplus.ca, including the Company’s Annual Information Form for the year ended December 31, 2023 dated March 11, 2024 (the “AIF”).
CONSOLIDATED HIGHLIGHTS
FINANCIAL REVIEW
| ($000s except percentages and per share amounts) | Three months ended | Years ended | |||||||||||||
| December 31, | December 31, | December 31, | December 31, | December 31, | |||||||||||
| 2023 | 2022 | 2023 | 2022 | 2021 | |||||||||||
| Consolidated revenue | $ | 195,047 | $ | 251,394 | $ | 945,723 | $ | 989,018 | $ | 536,309 | |||||
| Net income (loss) | $ | (5,244) | $ | 16,692 | $ | 50,419 | $ | 94,781 | $ | (28,127) | |||||
| Per share-basic | $ | (0.07) | $ | 0.24 | $ | 0.70 | $ | 1.37 | $ | (0.41) | |||||
| Per share-diluted | $ | (0.07) | $ | 0.23 | $ | 0.67 | $ | 1.31 | $ | (0.41) | |||||
| Adjusted EBITDA (1) | $ | 18,436 | $ | 48,616 | $ | 163,578 | $ | 198,906 | $ | 62,963 | |||||
| Adjusted EBITDA % (1) | 9% | 19% | 17% | 20% | 12% | ||||||||||
| Free Cash Flow (1) | (4,458) | 22,373 | 82,811 | 111,788 | 27,775 | ||||||||||
| (1) Adjusted EBITDA and Free Cash Flow are non-IFRS financial measures, Adjusted EBITDA % is a non-IFRS financial ratio. These metrics are not defined and have no standardized meaning under IFRS. See Non-IFRS Measures and Ratios. | |||||||||||||||
OPERATIONAL REVIEW
| ($000s except days, proppant, pumped, horsepower and units) | Three months ended | Years ended | ||||||||
| December 31, | December 31, | December 31, | December 31, | December 31, | ||||||
| 2023 | 2022 | 2023 | 2022 | 2021 | ||||||
| Fracturing services | ||||||||||
| Fracturing operating days (2) | 362 | 476 | 1,635 | 2,042 | 1,681 | |||||
| Proppant pumped (tonnes) | 460,300 | 453,000 | 2,153,200 | 2,229,000 | 1,972,000 | |||||
| Fracturing crews | 8 | 8 | 8 | 8 | 7 | |||||
| Dual fuel horsepower (“HP”), ended | 301,500 | 182,750 | 301,500 | 182,750 | 182,500 | |||||
| Total HP, ended | 490,000 | 490,000 | 490,000 | 490,000 | 490,000 | |||||
| Coiled tubing services | ||||||||||
| Coiled tubing operating days (2) | 1,263 | 1,151 | 4,976 | 4,338 | 3,307 | |||||
| Active coiled tubing units, ended | 21 | 19 | 21 | 19 | 15 | |||||
| Total coiled tubing units, ended | 35 | 33 | 35 | 33 | 29 | |||||
| (2) An operating day is defined as any coiled tubing or fracturing work that is performed in a 24-hour period, exclusive of support equipment. | ||||||||||
| ($000s except shares) | ||||||
| As at December 31, | 2023 | 2022 | 2021 | |||
| Cash and cash equivalents | $ | 1,785 | $ | 2,785 | $ | 3,698 |
| Working capital (including cash and cash equivalents) (3) | $ | 42,104 | $ | 66,580 | $ | 3,912 |
| Total assets | $ | 606,519 | $ | 682,532 | $ | 483,848 |
| Total long-term financial liabilities (3) | $ | 118,970 | $ | 168,746 | $ | 175,689 |
| Net Debt (3) | $ | 87,844 | $ | 142,224 | $ | 186,885 |
| Shares outstanding | 72,233,064 | 71,589,626 | 68,156,981 | |||
| (3) Working Capital, Total long-term financial liabilities and Net debt are non-IFRS financial measures. They are not defined and have no standardized meaning under IFRS. See Non-IFRS Measures and Ratios. | ||||||
2023 ANNUAL HIGHLIGHTS
FOURTH QUARTER 2023 OVERVIEW
Commodity prices remained volatile in the fourth quarter. West Texas Intermediate (WTI), the benchmark U.S. oil price, declined from approximately $90 per barrel at the start of the quarter to approximately $70 per barrel at the close. The strengthening of supply from countries outside of the Organization of the Petroleum Exporting Countries plus other oil-producing countries (“OPEC+”), coinciding with slower than expected global demand growth, were significant factors in the price decrease. The benchmark Henry Hub natural gas price fluctuated through the quarter, but the quarter-end price remained relatively flat compared to the price at the end of the third quarter. The steady erosion in the U.S. rig count seen through much of 2023 slowed in the fourth quarter, with the Baker Hughes land rig count bottoming at 597 rigs before closing 2023 at 602 rigs, resulting in an average rig count of 601 in the fourth quarter. This is down from 630 rigs in Q3 2023 and 764 rigs at the close of 2022. Rig counts in Canada decreased by 7 rigs, declining from an average of 187 in Q3 2023 to 180 in Q4 2023. The rig count in Canada is less indicative of completions activity, as an estimated 35-40% of Canadian rigs are typically drilling wells that do not require hydraulic fracturing. The reduced activity was captured in analysis from Rystad Energy(1), an independent energy research and business intelligence company, which estimated that North American fracturing starts in Q4 2023 fell by 15% relative to Q3 2023.
STEP’s consolidated fourth quarter revenue of $195.0 million and Adjusted EBITDA of $18.4 million was lower sequentially and year over year. The fourth quarter typically sees a slowdown in activity as E&P companies wind down their capital budgets. At times companies will pull capital forward if there is a strong commodity price incentive but that did not materialize in Q4 2023 as commodity prices were on a weakening trend.
STEP’s Canadian geographic region generated quarterly revenue of $112.2 million and adjusted EBITDA of $15.0 million. Fracturing revenue in Canada fell quarter over quarter due to the typical slowdown outlined above as well as the decision by certain clients to defer approximately $16.0 – $18.0 million of work scheduled for Q4 2023 into Q1 2024. The Q4 fracturing job mix also shifted sequentially to include more lower-intensity well completions, which have a lower revenue profile. The lower activity and shift in job mix is reflected in the reduction in proppant pumped, which declined in Q4 2023 to 223,300 tonnes from 308,000 tonnes in Q3 2023, resulting in lower average revenue per day. Coiled tubing services typically follow fracturing services on a well, resulting in activity changes that lag the fracturing market. Coiled tubing activity levels stayed strong through the fourth quarter, benefitting from STEP’s presence in the Canadian market as a technical leader. Coiled tubing revenue per day also decreased in part due to the shift to lower intensity coil fracturing, which is lower revenue relative to the milling work that was more predominant in prior quarters.
STEP’s U.S. geographic region generated quarterly revenue of $82.8 million and adjusted EBITDA of $7.2 million. The fourth quarter slow down in drilling activity was further exacerbated by the wave of consolidation in the U.S. E&P market, which negatively affected STEP’s U.S. fracturing operations when a long-term client was acquired in mid Q4 2023. This acquisition resulted in the cancellation of the remaining fracturing work scope for 2023 for one fracturing crew and additional work scope was lost for a second fracturing crew when a client delayed a pad late in the quarter to the point where it would have crossed over into Q1 2024, disrupting the schedule for that quarter. The estimated revenue loss from this reduced utilization was approximately $17.0 – $19.0 million. With the reduction in utilization, proppant pumped decreased to 237,000 tonnes in Q4 from 281,000 tonnes in Q3. Coiled tubing activity remained strong in the northern basins as clients continued to operate until the holiday break while levels declined sequentially in the southern basins as clients reached the limits of their 2023 capital budgets.
The Company generated consolidated Adjusted EBITDA of $18.4 million, a margin of 9%. This was lower than the $52.3 million (21% margin) achieved in Q3 2023 and the $48.6 million (19% margin) posted in Q4 2022. The decline in activity was a factor in the lower Adjusted EBITDA but margins were also eroded by higher operating expenses associated with the preparation of equipment for the highly utilized upcoming quarter and certain one-time items that totalled between $3.0 – $4.0 million.
Net loss was $5.2 million in Q4 2023 ($0.07 diluted loss per share), sequentially lower than net income of $20.7 million in Q3 ($0.28 diluted earnings per share) and $16.7 million ($0.23 diluted earnings per share) realized in Q4 2022. Net loss for Q4 2023 included $2.6 million in finance costs (Q3 2023 ‐ $2.9 million, Q4 2022 ‐ $3.0 million) and $0.8 million in share-based compensation (Q3 2023 ‐ $4.0 million, Q4 2022 ‐ $4.4 million).
Free Cash Flow was $(4.5) million in Q4 2023, sequentially lower than the $37.1 million in Q3 2023 and the $22.4 million in Q4 2022. Significant collection of trade receivables late in Q4 2023 allowed the Company to accelerate certain capital expenditures to capitalize on benefits associated with early payment and possession. The accelerated capital expenditures resulted in a draw down of working capital, which STEP anticipates will return to more typical levels in the first quarter of 2024. Free Cash Flow on an annualized basis in 2023 was $82.8 million compared to $111.8 million in 2022. A considerable portion of Free Cash Flow was allocated to debt reduction, balanced with increased investment into equipment.
Net Debt was reduced to $87.8 million at the close of Q4 2023 from $89.8 million at close of Q3 2023 and is down nearly $60 million on a year-over-year basis. The debt reduction was accomplished while simultaneously investing $120.4 million into capital expenditures during the full year 2023. STEP has now reduced debt by nearly $230 million from peak levels in 2018.
______________________________
1 Rystad Energy, January 5, 2024
MARKET OUTLOOK
The outlook for the north American energy sector is anticipated to continue strengthening as major energy infrastructure projects are completed in Canada and the U.S. In Canada, completion of the Trans Mountain Expansion Project will increase the capacity of the original Trans Mountain Pipeline from 300,000 barrels of oil per day to 890,000 barrels of oil per day and completion of the LNG Canada facility will require 2.1 BCF per day of feed gas to produce liquified natural gas (“LNG”) for export. These projects are both anticipated to be complete in 2024, with additional LNG projects expected to add up to 4-5 BCF per day by 2030. In the U.S., numerous LNG projects are under construction with completion dates anticipated over the next 3-4 years, adding 11-12 BCF per day to current U.S. LNG export capacity of approximately 13-14 BCF per day today. Collectively these projects demonstrate that North America is becoming a cornerstone supplier of clean, reliable energy to the world, lifting millions of people out of energy poverty and delivering energy security to allies across the world, while providing constructive economic conditions for north American producers and service providers.
Near term commodity prices continue to remain volatile, with concerns over recession and overproduction weighing on prices. North American crude oil, as measured by the benchmark West Texas Intermediate (“WTI”), is showing greater resiliency due to the higher correlation with global oil markets. Those markets are heavily influenced by the supply management policies of the OPEC+ producers, which helps smooths out the volatility in crude prices. Natural gas prices are expected to remain weak through the shoulder season, with the benchmark Henry Hub price recently testing multi decade lows in Q1 2024 as a result of an extremely mild winter and record gas production. Major U.S. producers have announced reductions in their 2024 capital programs to return this market to balance, which will result in softer U.S. activity levels for at least the first half of the year relative to prior years. Canadian gas production is heavily affected by the price of natural gas liquids (“NGLs”), which have been more stable than natural gas due to their correlation to oil prices. Demand for condensate, a key NGL, remains strong and is supported by growing oil sands production. Nonetheless, major Canadian natural gas producers are also voicing more caution around expected 2024 activity levels, which may result in deferral of some work scope to later in the year.
The long-term outlook for oilfield services is very constructive. The structural under-investment in hydrocarbon production capacity through the last seven years has been exacerbated by geopolitical tensions, forcing governments and policy makers to confront the realty that oil and gas will be a key part of the energy mix for many years. STEP is proud to work in Canada and the U.S., countries that have the natural resources, regulatory frameworks, and technical expertise to deliver safe and affordable energy to the world.
Canada
Canadian activity levels have been strong for Q1 2024, particularly for the fracturing service line which is seeing high utilization across the six active crews. The work that was deferred from Q4 2023 into Q1 2024 began at the start of January, which allowed STEP to weather the extreme cold in mid January with minimal disruption to utilization. Five of STEP’s fracturing crews are focused on large multi-well pads in the gas-focused Montney and Duvernay plays, with the smaller sixth crew optimized for smaller scale fracturing work across different plays. This crew operates with a fully electrified combination unit that replaces individual blender, data van and chemical additive units, reducing the wellsite footprint and emissions.
The increase in fracturing intensity is driving horsepower demand higher, as well as requiring a large logistics fleet to support the larger sand volumes being placed per stage and per well. STEP operates one of the largest sand logistics fleets in the industry, hauling over 80% of STEP supplied sand in 2023. Having this fleet provides greater efficiency on fracturing operations by reducing third party nonproductive time and increasing flexibility between multiple fracturing operations.
Demand for STEP’s coiled tubing and ancillary services (nitrogen and fluid pumping) has been steady from early January, reflecting the Company’s position as one of the leading service providers in the WCSB. STEP coiled tubing crews are valued for their technical expertise and experience in the most technically challenging wells and STEP’s Intelligent Intervention systems bring the best technology, such as Canada’s deepest and largest e-coil fleet, to client locations.
All service lines are largely booked for the balance of the quarter, although timing of spring break-up may affect utilization levels in March. If break-up conditions come early, the remaining Q1 work scope will be pushed into Q2 2024. The second quarter calendar is filling up, although continued weakness in natural gas prices and concerns over drought conditions may result in the deferral of some work scope until conditions improve. Fresh water usage is continually decreasing as producers and service providers become more adept at handling recycled water. STEP also has fracturing systems that can utilize nitrogen or carbon dioxide to significantly reduce the amount of water required and has proprietary systems that use liquified petroleum gas (“LPG”) to displace water completely.
STEP expects its second Tier 4 dual fuel fleet to be complete by the end of the second quarter, with upgraded pumpers being delivered to the field as they are completed. These pumpers displace up to 85% of diesel with natural gas, delivering lower emissions and costs to STEP’s valued clients. On completion of this crew, 72% of STEP’s total U.S. and Canadian fleet will be natural gas capable.
Work scope for the second half of the year remains difficult to project at this juncture, but the anticipated completion of the Trans Mountain Expansion and LNG Canada is expected to support activity levels. The Company is participating in a number of client proposals that will determine how much fracturing capacity is needed in Canada. The coiled tubing market is at balance in Q1, which is typically the most completions intensive quarter. That market has the potential to slip into an oversupplied position if additional coil capacity is added by current market participants, likely leading pricing lower for all participants. STEP is sensitive to the competitive balance in the fracturing and coiled tubing market and has the optionality to balance equipment between Canada and the U.S. to capitalize on the best return.
United States
STEP currently has two fracturing fleets operating in the Permian Basin. Activity has been consistent throughout the first quarter, reflecting the benefit of securing longer term work scope with active producers. The U.S. fracturing market remains oversupplied, which could result in some near-term softness in pricing and utilization as fracturing fleets focused on the gassier plays migrate to the Permian Basin and bid margins lower.
Activity levels on STEP’s twelve coiled tubing fleets have stayed steady to start 2024, reflecting the Company’s position as one of the leading service providers in the basins it operates in. Pricing is down modestly across the fleet relative to 2023 but has not seen the same pressures exhibited in the fracturing market. Spring break-up conditions may impact activity at STEP’s northern coiled tubing bases in Colorado and North Dakota in late Q1 and early Q2, but utilization is expected to remain steady outside of these periods.
Visibility into the second half of the year will in large part be dictated by the slope of the natural gas futures curve. The current strip shows prices strengthening in the third and fourth quarters, which will bring more stability to the fracturing market. STEP will continue to evaluate opportunities to repatriate the fracturing capacity sent to Canada back to the U.S. The recent E&P consolidation is expected to benefit STEP’s ultra deep coiled tubing capacity, as the contiguous land holdings of the consolidated entities create more opportunities for the three-mile laterals to be drilled.
Consolidated
STEP’s focus for the balance of 2024 and into 2025 is on the generation of Free Cash Flow that supports the Company’s commitment to continue investing into next generation technology and expanding its shareholder return framework.
STEP has set a target to have 90% of its fracturing fleet capable of utilizing natural gas by the end of 2025. STEP’s current focus is on the upgrading of diesel engines to Tier 4 dual fuel capability, with the third fleet expected to be complete by the end of Q2 2024. STEP is evaluating other next generation technologies that could provide even higher natural gas substitution rates.
STEP’s shareholder return framework will continue to focus on reduction of overall leverage but was expanded in late 2023 to include an NCIB. STEP believes that its current share price does not reflect the value inherent in its business and it intends to acquire the full amount permitted, provided market conditions remain favourable.
CANADIAN FINANCIAL AND OPERATIONS REVIEW
STEP has a fleet of 16 coiled tubing units in the WCSB, all of which are designed to service the deepest wells in the basin. STEP’s fracturing business primarily focuses on the deeper, more technically challenging plays in Alberta and northeast British Columbia. STEP deploys or idles coiled tubing units and fracturing horsepower as dictated by the market’s ability to support targeted utilization and economic returns.
| ($000’s except per day, days, units, proppant | Three months ended | Years ended | ||||||
| pumped) | December 31, | December 31, | December 31, | December 31, | ||||
| 2023 | 2022 | 2023 | 2022 | |||||
| Revenue: | ||||||||
| Fracturing | $ | 81,719 | $ | 83,093 | $ | 460,503 | $ | 453,611 |
| Coiled tubing | 30,486 | 31,733 | 119,710 | 114,227 | ||||
| 112,205 | 114,826 | 580,213 | 567,838 | |||||
| Expenses | 107,495 | 102,673 | 483,007 | 477,209 | ||||
| Results from operating activities | $ | 4,710 | $ | 12,153 | $ | 97,206 | $ | 90,629 |
| Adjusted EBITDA (1) | $ | 15,017 | $ | 23,561 | $ | 134,418 | $ | 136,034 |
| Adjusted EBITDA % (1) | 13% | 21% | 23% | 24% | ||||
| Sales mix (% of segment revenue) | ||||||||
| Fracturing | 73% | 72% | 79% | 80% | ||||
| Coiled tubing | 27% | 28% | 21% | 20% | ||||
| Fracturing services | ||||||||
| Number of fracturing operating days (2) | 233 | 249 | 1,004 | 1,194 | ||||
| Proppant pumped (tonnes) | 223,300 | 145,000 | 1,137,600 | 1,059,000 | ||||
| Fracturing crews | 5 | 5 | 5 | 5 | ||||
| Coiled tubing services | ||||||||
| Number of coiled tubing operating days (2) | 510 | 496 | 1,878 | 1,964 | ||||
| Active coiled tubing units, end of period | 9 | 8 | 9 | 8 | ||||
| Total coiled tubing units, end of period | 16 | 16 | 16 | 16 | ||||
| (1) Adjusted EBITDA is a non-IFRS financial measure and Adjusted EBITDA % are non-IFRS financial ratios. They are not defined and have no standardized meaning under IFRS. See Non-IFRS Measures and Ratios. | ||||||||
| (2) An operating day is defined as any coiled tubing or fracturing work that is performed in a 24-hour period, exclusive of support equipment. | ||||||||
FOURTH QUARTER 2023 COMPARED TO FOURTH QUARTER 2022
Revenue for the three months ended December 31, 2023 was $112.2 million compared to $114.8 million for the three months ended December 31, 2022. While revenue remained relatively consistent in Q4 2023 compared to Q4 2022, Adjusted EBITDA fell from $23.6 million to $15.0 million.
Adjusted EBITDA for the fourth quarter of 2023 was 13% of revenue ($15.
Contacts
For more information please contact:
Steve Glanville
President and Chief Executive Officer
Telephone: 403-457-1772
Klaas Deemter
Chief Financial Officer
Telephone: 403-457-1772
Email: investor_relations@step-es.com
Web: www.stepenergyservices.com