OIL STATES INTERNATIONAL, INC 10-Q

ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations The following discussion and analysis should be read together with our condensed consolidated financial statements and notes to those statements included elsewhere in this Quarterly Report on Form 10-Q and our consolidated financial statements and notes to those statements included in our 2023 Annual Report on Form 10-K in order to understand factors, such as charges and credits, financing transactions and changes in tax regulations, which may impact comparability from period to period. We provide a broad range of manufactured products and services to customers in the energy, industrial and military sectors through our Offshore Manufactured Products, Well Site Services and Downhole Technologies segments. In first quarter 2024, certain short-cycle, consumable product operations historically reported within the Offshore Manufactured Products segment (legacy frac plugs and elastomer products) were integrated into the Downhole Technologies segment to better align with the underlying activity demand drivers and current segment management structure, as well as provide for additional operational synergies. Historical financial data, supplemental disaggregated revenue and backlog information as of and for the three months ended March 31, 2023 (presented herein) was conformed with the current-period segment presentation. Demand for our products and services is cyclical and substantially dependent upon activity levels in the oil and gas industry, particularly our customers’ willingness to invest capital in the exploration for and development of crude oil and natural gas reserves. Our customers’ capital spending programs are generally based on their cash flows and their outlook for near-term and long-term commodity prices, making demand for our products and services sensitive to expectations regarding future crude oil and natural gas prices, as well as economic growth, commodity demand and estimates of resource production and regulatory pressures related to Environmental, Social and Governance (“ESG”) considerations. 18 Table of Contents Recent Developments Brent and WTI crude oil and natural gas pricing trends were as follows: Average Price (1) for quarter ended Average Price (1) for year ended December 31 Year March 31 June 30 September 30 December 31 Brent Crude (per bbl) 2024 $ 82.92 $ — $ — $ — $ — 2023 81.01 77.99 86.65 $ 84.01 $ 82.47 WTI Crude (per bbl) 2024 $ 77.50 $ — $ — $ — $ — 2023 75.91 73.54 82.25 $ 78.53 $ 77.56 Henry Hub Natural Gas (per MMBtu) 2024 $ 2.15 $ — $ — $ — $ — 2023 2.64 2.16 2.59 $ 2.74 $ 2.53 ________________ (1) Source: U.S. Energy Information Administration (spot prices). On February 16, 2024, we amended our ABL Facility to extend its maturity date from February 10, 2025 to February 16, 2028. In the first quarter of 2024, certain short-cycle, consumable product operations historically reported within the Offshore Manufactured Products segment (legacy frac plugs and elastomer products) were integrated into our Downhole Technologies segment to better align with the underlying activity demand drivers and current segment management structure, as well as provide for additional operational synergies. Historical segment financial data, backlog and other information were conformed with the first quarter 2024 revised segment presentation. On April 19, 2024, Brent crude oil, WTI crude oil and natural gas spot prices closed at $87.96 per barrel, $83.79 per barrel and $1.43 per MMBtu, respectively. Additionally, the U.S. drilling rig count reported on April 19, 2024 was 619 rigs – comparable to the first quarter 2024 average. Overview Current and expected future pricing for WTI crude oil and natural gas and inflationary cost increases, along with expectations regarding the regulatory environment in the regions in which we operate, are factors that will continue to influence our customers’ willingness to invest capital in their businesses. Expectations for the longer-term price for Brent crude oil will continue to influence our customers’ spending related to global offshore drilling and development and, thus, a significant portion of the activity of our Offshore Manufactured Products segment. Crude oil and natural gas prices and levels of demand for crude oil and natural gas are likely to remain highly volatile due to numerous factors, including: geopolitical conflicts in Europe and the Middle East, along with associated international tensions; the perceived risk of a global economic recession; domestic or international crude oil and natural gas production; changes in governmental rules and regulations; sanctions; the willingness of operators to invest capital in the exploration for and development of resources; use of alternative fuels; improved vehicle fuel efficiency; timing of capital investments in alternative energy sources; a more sustained movement to electric vehicles; and the potential for ongoing supply/demand imbalances. U.S. drilling, completion and production activity and, in turn, our financial results, are sensitive to near-term fluctuations in commodity prices, particularly WTI crude oil prices, given the short-term, call-out nature of our U.S. operations. Customer spending in the natural gas shale plays has moderated over the last ten years due to technological advancements that have led to significant amounts of natural gas being produced from prolific basins in the Northeastern United States and from associated gas produced from the drilling and completion of unconventional oil wells in the United States. Our Offshore Manufactured Products segment provides technology-driven, highly-engineered products and services for offshore oil and natural gas production systems and facilities globally, as well as certain products and services to the offshore drilling and completion markets. This segment also produces a variety of products for use in industrial, military and other applications outside the traditional energy industry. Additionally, we are investing in research and product development (and have been awarded select contracts and are bidding on additional projects) to facilitate the development of alternative energy 19 Table of Contents sources, including offshore wind and deepsea mineral gathering opportunities. This segment is particularly influenced by global spending on deepwater drilling and production, which is primarily driven by our customers’ longer-term commodity demand forecasts and outlook for crude oil and natural gas prices. Approximately 90% of Offshore Manufactured Products segment sales in the first three months of 2024 were driven by our customers’ capital spending for products and services used in exploratory and developmental drilling, greenfield offshore production infrastructure, and subsea pipeline tie-in and repair system applications, along with upgraded equipment for existing offshore drilling rigs and other vessels (referred to herein as “project-driven products and services”). Deepwater oil and gas development projects typically involve significant capital investments and multi-year development plans. Such projects are generally undertaken by larger exploration, field development and production companies (primarily international oil companies and state-run national oil companies) using relatively conservative crude oil and natural gas pricing assumptions. Given the long lead times associated with field development, we believe some of these deepwater projects, once approved for development, are generally less susceptible to change based on short-term fluctuations in the price of crude oil and natural gas. Backlog reported by our Offshore Manufactured Products segment decreased to $305 million as of March 31, 2024 from $327 million as of December 31, 2023. Bookings totaled $66 million in the first quarter of 2024, yielding a quarterly book-to-bill ratio of 0.8x. The following table sets forth backlog as of the dates indicated (in millions). Backlog as of Year March 31 June 30 September 30 December 31 2024 $ 305 2023 316 $ 328 $ 341 $ 327 2022 255 232 248 300 Our Well Site Services segment provides completion services and, to a much lesser extent, land drilling services, in the United States (including the Gulf of Mexico) and internationally. U.S. drilling and completion activity and, in turn, our Well Site Services results, are sensitive to near-term fluctuations in commodity prices, particularly WTI crude oil prices, given the short-term, call-out nature of its operations. We primarily supply equipment and service personnel utilized in the completion of, and initial production from, new and recompleted wells in our U.S. operations, which are dependent primarily upon the level and complexity of drilling, completion and workover activity in our areas of operations. Well intensity and complexity have increased with the continuing transition to multi-well pads, the drilling of longer lateral wells and increased downhole pressures, along with the increased number of frac stages completed in horizontal wells. Our Downhole Technologies segment provides oil and gas perforation systems, downhole tools and services in support of completion, intervention, wireline and well abandonment operations. This segment designs, manufactures and markets its consumable engineered products to oilfield service as well as exploration and production companies. Product and service offerings for this segment include innovations in perforation technology through patented and proprietary systems combined with advanced modeling and analysis tools. This expertise has led to the optimization of perforation hole size, depth, and quality of tunnels, which are key factors for maximizing the effectiveness of hydraulic fracturing. Additional offerings include frac plug, toe valve and other elastomer products, which are focused on zonal isolation for hydraulic fracturing of horizontal wells, and a broad range of consumable products, such as setting tools and bridge plugs, that are used in completion, intervention and decommissioning applications. Demand drivers for the Downhole Technologies segment include continued trends toward longer lateral lengths, increased frac stages and more perforation clusters to target increased unconventional well productivity. Demand for our completion-related products and services within each of our segments is highly correlated to changes in the total number of wells drilled in the United States, total footage drilled, the number of drilled wells that are completed and changes in the drilling rig count. The following table sets forth a summary of the U.S. drilling rig count, as measured by Baker Hughes Company, as of and for the periods indicated. As of April 19, 2024 Average for the Three Months Ended March 31, 2024 2023 United States Rig Count: Land – Oil 492 483 579 Land – Natural gas and other 107 119 155 Offshore 20 21 19 619 623 753 20 Table of Contents The U.S. energy industry is primarily focused on crude oil and liquids-rich exploration and development activities in U.S. shale plays utilizing horizontal drilling and completion techniques. As of March 31, 2024, oil-directed drilling accounted for 81% of the total U.S. rig count – with the balance largely natural gas related. We use a variety of domestically produced and imported raw materials and component products, including steel, in the manufacture of our products. The United States has imposed tariffs on a variety of imported products, including steel and aluminum. In response to the U.S. tariffs on steel and aluminum, the European Union and several other countries, including Canada and China, have threatened and/or imposed retaliatory tariffs. In addition, in response to Russia’s invasion of Ukraine, governments in the European Union, the United States, the United Kingdom, Switzerland and other countries have enacted sanctions against Russia and Russian interests. The effect of these sanctions and tariffs and the application and interpretation of existing trade agreements and customs, anti-dumping and countervailing duty regulations continue to evolve, and we continue to monitor these matters. If we encounter difficulty in procuring these raw materials and component products, or if the prices we have to pay for these products increase and we are unable to pass corresponding cost increases on to our customers, our financial position, cash flows and results of operations could be adversely affected. Furthermore, uncertainty with respect to potential costs in the drilling and completion of oil and gas wells could cause our customers to delay or cancel planned projects which, if this occurred, would adversely affect our financial position, cash flows and results of operations. Other factors that can affect our business and financial results include but are not limited to: the general global economic environment; competitive pricing pressures; customer consolidations; public health crises; natural disasters; labor market constraints; supply chain disruptions; inflation in wages, materials, parts, equipment and other costs; climate-related and other regulatory changes; geopolitical conflicts and tensions; and changes in tax laws in the United States and international markets. We continue to monitor the global economy, the prices of and demand for crude oil and natural gas, and the resultant impact on the capital spending plans and operations of our customers in order to plan and manage our business. Human Capital For more information on our health and safety, diversity and other workforce policies, please see “Part I, Item 1. Business – Human Capital” in our Annual Report on Form 10-K for the year ended December 31, 2023. 21 Table of Contents Selected Financial Data This selected financial data should be read in conjunction with our Unaudited Condensed Consolidated Financial Statements and related notes included in “Part I, Item 1. Financial Statements” of this Quarterly Report on Form 10-Q and “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our Consolidated Financial Statements and related notes included in “Part II, Item 8. Financial Statements and Supplementary Data” of our Annual Report on Form 10-K for the year ended December 31, 2023 in order to understand factors, such as charges, credits and financing transactions, which may impact comparability of the selected financial data. In the first quarter of 2024, certain short-cycle manufacturing operations historically reported within the Offshore Manufactured Products segment (legacy frac plug and elastomer products) were integrated into the Downhole Technologies segment to better align with the underlying activity demand drivers and the current segment management structure, as well as provide for additional operational synergies. Historical financial data and supplemental disaggregated revenue information as of the three months ended March 31, 2023 (presented herein) were conformed with the current-period segment presentation. Unaudited Consolidated Results of Operations The following summarizes our consolidated results of operations for the three months ended March 31, 2024 and 2023 (in thousands, except per share amounts): Three Months Ended March 31, 2024 2023 Variance Revenues: Products $ 94,329 $ 99,840 $ (5,511) Services 72,933 96,359 (23,426) 167,262 196,199 (28,937) Costs and expenses: Product costs 75,137 78,677 (3,540) Service costs 56,814 72,058 (15,244) Cost of revenues (exclusive of depreciation and amortization expense presented below) 131,951 150,735 (18,784) Selling, general and administrative expenses (1) 22,496 24,016 (1,520) Depreciation and amortization expense 14,195 15,256 (1,061) Impairment of goodwill (2) 10,000 — 10,000 Other operating (income) expense, net (3) (203) 317 (520) 178,439 190,324 (11,885) Operating income (loss) (11,177) 5,875 (17,052) Interest expense, net (2,101) (2,391) 290 Other income (expense), net (72) 276 (348) Income (loss) before income taxes (13,350) 3,760 (17,110) Income tax provision (24) (1,602) 1,578 Net income (loss) $ (13,374) $ 2,158 $ (15,532) Net income (loss) per share: Basic $ (0.21) $ 0.03 Diluted (0.21) 0.03 Weighted average number of common shares outstanding: Basic 62,503 62,825 Diluted 62,503 63,072 _______________ (1) During the three months ended March 31, 2024, we recognized $0.4 million in costs associated with the defense of certain Well Site Services segment patents related to proprietary technologies. (2) During the three months ended March 31, 2024, the Downhole Technologies segment recognized a $10.0 million non-cash impairment charge related to goodwill reassigned to the business in connection with the segment realignment discussed above. (3) During the three months ended March 31, 2024, we recognized facility consolidation and other charges of $2.1 million associated with the Offshore Manufactured Products and the Well Site Services segments’ ongoing consolidation and relocation of certain manufacturing and service locations. 22 Table of Contents Unaudited Segment Results of Operations We manage and measure our business performance in three distinct operating segments: Offshore Manufactured Products, Well Site Services and Downhole Technologies. Supplemental financial information by operating segment for the three months ended March 31, 2024 and 2023 is summarized below (in thousands): Three Months Ended March 31, 2024 2023 Variance Revenues: Offshore Manufactured Products Project-driven: Products $ 53,137 $ 48,617 $ 4,520 Services 25,233 24,630 603 78,370 73,247 5,123 Military and other products 8,487 7,258 1,229 86,857 80,505 6,352 Well Site Services 47,292 67,058 (19,766) Downhole Technologies 33,113 48,636 (15,523) $ 167,262 $ 196,199 $ (28,937) Operating income (loss): Offshore Manufactured Products (1) $ 10,603 $ 7,698 $ 2,905 Well Site Services (2) (419) 6,966 (7,385) Downhole Technologies (3) (12,079) 1,873 (13,952) Corporate (9,282) (10,662) 1,380 $ (11,177) $ 5,875 $ (17,052) _______________ (1) During the three months ended March 31, 2024, we recognized facility consolidation charges of $1.5 million associated with the Offshore Manufactured Products segment’s ongoing consolidation and relocation of a manufacturing and service location. (2) During the three months ended March 31, 2024, the Well Site Services segment recognized charges of $1.0 million associated primarily with the consolidation and exit of certain service locations. (3) During the three months ended March 31, 2024, the Downhole Technologies segment recognized a $10.0 million non-cash impairment charge related to goodwill reassigned to the business in connection with the segment realignment discussed above. 23 Table of Contents Three Months Ended March 31, 2024 Compared to Three Months Ended March 31, 2023 We reported a net loss for the three months ended March 31, 2024 of $13.4 million, or $0.21 per share, which included a non-cash goodwill impairment charge of $10.0 million ($9.5 million after-tax, or $0.15 per share) and facility consolidation and other charges of $2.5 million ($2.0 million after-tax, or $0.03 per share). These results compare to net income for the three months ended March 31, 2023 of $2.2 million, or $0.03 per share. Our first quarter 2024 results, reflect the impact of an industry-wide decline in U.S. well completions, driven particularly by weak natural gas prices (the average spot price for Henry Hub natural gas was $2.15 per MMBtu in the first quarter of 2024, down 19% from the prior-year period). The impact of the decline in investments by our U.S. customers was partially offset by growth in offshore and international project activity and associated backlog conversion. Management continues to implement measures in areas experiencing lower activity levels to reduce future costs. Revenues. Consolidated total revenues in the first three months of 2024 decreased $28.9 million, or 15%, from the first three months of 2023. Consolidated product revenues in the first three months of 2024 decreased $5.5 million, or 6%, from the first three months of 2023, with the impact of lower customer demand for consumable completion products in the United States, partially offset by higher customer demand for project-driven production facility and connector products. Consolidated service revenues in the first three months of 2024 decreased $23.4 million, or 24%, from the first three months of 2023 due primarily to lower U.S. land-based customer investments. The following table provides supplemental disaggregated revenue from contracts with customers by operating segment for the three months ended March 31, 2024 and 2023 (in thousands): Offshore Manufactured Products Well Site Services Downhole Technologies Total Three Months Ended March 31 2024 2023 2024 2023 2024 2023 2024 2023 Project-driven: Products $ 53,137 $ 48,617 $ — $ — $ — $ — $ 53,137 $ 48,617 Services 25,233 24,630 — — — — 25,233 24,630 Total project-driven 78,370 73,247 — — — — 78,370 73,247 Military and other products 8,487 7,258 — — — — 8,487 7,258 Short-cycle products and services — — 47,292 67,058 33,113 48,636 80,405 115,694 $ 86,857 $ 80,505 $ 47,292 $ 67,058 $ 33,113 $ 48,636 $ 167,262 $ 196,199 By destination: U.S. land $ 7,055 $ 8,442 $ 35,857 $ 53,274 $ 24,170 $ 38,821 $ 67,082 $ 100,537 Offshore and international 79,802 72,063 11,435 13,784 8,943 9,815 100,180 95,662 $ 86,857 $ 80,505 $ 47,292 $ 67,058 $ 33,113 $ 48,636 $ 167,262 $ 196,199 Cost of Revenues (exclusive of Depreciation and Amortization Expense). Our consolidated total cost of revenues (exclusive of depreciation and amortization expense) decreased $18.8 million, or 12%, in the first three months of 2024 compared to the first three months of 2023. Consolidated product costs in the first three months of 2024 decreased $3.5 million, or 4%, compared to the first three months of 2023 due primarily to the reported revenue decline. Consolidated service costs in the first three months of 2024 decreased $15.2 million, or 21%, compared to the first three months of 2023, due primarily to the impact of lower U.S. activity levels. Selling, General and Administrative Expense. Selling, general and administrative expense was $22.5 million in the first three months of 2024, which included $0.4 million of costs associated with enforcing certain of our patents. Excluding these patent defense costs, selling, general and administrative costs decreased $1.2 million, or 5%, from the first three months of 2023, due primarily to reductions in short- and long-term incentive expenses. Depreciation and Amortization Expense. Depreciation and amortization expense decreased $1.1 million, or 7%, in the first three months of 2024 compared to the prior-year period. Note 10, “Segments and Related Information,” to our Unaudited Condensed Consolidated Financial Statements presents depreciation and amortization expense by segment. 24 Table of Contents Impairment of Goodwill. During the first three months of 2024, our Downhole Technologies operations recognized a non-cash impairment charge of $10.0 million related to goodwill transferred to the business in connection with segment realignment discussed above. See Note 2, “Goodwill Impairment and Other Charges,” to the Unaudited Condensed Consolidated Financial Statements included in this Quarterly Report on Form 10-Q for additional discussion. Other Operating (Income) Expense, Net. In the first three months of 2024, other operating income, net included, among other items, gains on disposals of equipment totaling $1.2 million and charges of $2.1 million recognized in connection with our ongoing consolidation and exit of certain manufacturing and service locations within our Offshore Manufactured Products and Well Site Services segments. Operating Income (Loss). Our consolidated operating loss was $11.2 million in the first three months of 2024, which included a $10.0 million non-cash goodwill impairment charge and $2.5 million in facility consolidation and other charges. This compares to consolidated operating income of $5.9 million in the first three months of 2023. Excluding the 2024 charges, operating income decreased $4.5 million year-over-year. Interest Expense, Net. Net interest expense totaled $2.1 million in the first three months of 2024, which compares to $2.4 million in the first three months of 2023. Interest expense as a percentage of total debt outstanding was approximately 7% in the first three months of 2024, compared to 7% in the first three months of 2023. Income Tax. Income tax expense for the first three months of 2024 and 2023 was calculated using a discrete approach. This methodology was used because changes in our results of operations and non-deductible expenses can materially impact the estimated annual effective tax rate. For the first three months of 2024, our income tax provision was $24 thousand on a pre-tax loss of $13.4 million, which included a $10.0 million goodwill impairment charge and other non-deductible expenses. This compares to an income tax provision of $1.6 million on pre-tax income of $3.8 million for the first three months of 2023, which included certain non-deductible expenses and discrete tax items. Other Comprehensive Income (Loss). Reported comprehensive income (loss) is the sum of reported net income (loss) and other comprehensive income (loss). Other comprehensive loss was $3.0 million in the first three months of 2024 compared to comprehensive income of $4.1 million in the first three months of 2023 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our operating segments. For the first three months of 2024 and 2023, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. During the first three months of 2024, the exchange rates for the British pound and the Brazilian real weakened compared to the U.S. dollar. In the first three months of 2023, the exchange rate for the British pound and the Brazilian real strengthened compared to the U.S. dollar. Segment Operating Results Offshore Manufactured Products Revenues. Our Offshore Manufactured Products segment revenues increased $6.4 million, or 8%, in the first three months of 2024 compared to the first three months of 2023 due primarily to increased demand for international and offshore-project driven products and services. Operating Income. Our Offshore Manufactured Products segment reported operating income of $10.6 million in the first three months of 2024, which included the $1.5 million in facility consolidation charges discussed above. This compares to operating income of $7.7 million in the first three months of 2023. Excluding the facility consolidation charges, operating income increased $4.4 million year-over-year. Backlog. Backlog in our Offshore Manufactured Products segment totaled $305 million as of March 31, 2024 compared to $327 million as of December 31, 2023. Bookings during the first three months of 2024 totaled $66 million, yielding a quarterly book-to-bill ratio of 0.8x. Well Site Services Revenues. Our Well Site Services segment revenues decreased $19.8 million, or 29%, in the first three months of 2024 compared to the first three months of 2023, driven primarily by lower U.S. customer activity levels (particularly in natural gas basins) and competitive market conditions. 25 Table of Contents Operating Income. Our Well Site Services segment reported an operating loss of $0.4 million in the first three months of 2024, which included costs totaling $1.0 million associated with the exit of three facilities and the defense of patents. This compares to operating income of $7.0 million in the first three months of 2023. Excluding the costs discussed above, the Well Site Services segment’s operating results declined $6.3 million from the prior-year period, due to the reported decrease in revenue. Downhole Technologies Revenues. Our Downhole Technologies segment revenues decreased $15.5 million, or 32%, in the first three months of 2024 from the first three months of 2023 due primarily to lower U.S. customer demand for perforating and completion products. Operating Loss. Our Downhole Technologies segment reported an operating loss of $12.1 million in the first three months of 2024, which included the $10.0 million non-cash goodwill impairment charge related to the first quarter of 2024 segment realignment. This compares to operating income of $1.9 million reported in the first three months of 2023. Excluding the goodwill impairment charge, the Downhole Technologies operating results declined $4.0 million from the prior-year period, due primarily to the reported decrease in revenue and lower manufacturing volumes. Corporate Operating Loss. Corporate expenses in the first three months of 2024 decreased $1.4 million, or 13%, from the first three months of 2023, due primarily to lower short- and long-term incentive expenses. 26 Table of Contents Liquidity, Capital Resources and Other Matters Our primary liquidity needs are to fund operating and capital expenditures, new product development and general working capital needs. In addition, capital has been used to fund strategic business acquisitions, repay debt and fund share repurchases. Our primary sources of funds are cash flow from operations, proceeds from borrowings under our credit facilities and, less frequently, capital markets transactions. Operating Activities Cash flows used in operations totaled $11.4 million during the first three months of 2024, compared to $5.9 million used in operations during the first three months of 2023. During the first three months of 2024, $21.8 million was used to fund net working capital increases, primarily due to the payment of accrued 2023 short- and long-term cash incentives and a decrease in accounts payable. During 2023, $25.6 million was used to fund net working capital increases, primarily due to the payment of accrued 2022 short- and long-term cash incentives and an activity-driven increase in inventories. Investing Activities Net cash used in investing activities during the first three months of 2024 totaled $7.8 million, compared to $6.4 million used in investing activities during the first three months of 2023. Capital expenditures totaled $10.1 million and $6.6 million during the first three months of 2024 and 2023, respectively. These investments were partially offset by proceeds from the sale of equipment of $2.3 million and $0.2 million during the first three months of 2024 and 2023, respectively. Within our Offshore Manufactured Products segment, we completed the consolidation of certain facilities in Houston, Texas during 2023 and are in the process of strategically relocating our Asian manufacturing and service operations from Singapore to Batam, Indonesia. With these consolidations, two facilities are classified as held-for-sale assets within prepaid expenses and other current assets as of March 31, 2024. Including the planned construction of a new facility in Batam, we expect to invest approximately $40 million in capital expenditures during 2024. In 2024, we also expect to sell the two held-for-sale facilities (in Singapore and Houston), with proceeds totaling approximately $35 million. We plan to fund our capital expenditures with available cash, internally generated funds and, if necessary, borrowings under our ABL Facility discussed below. Financing Activities During the first three months of 2024, net cash of $3.7 million was used in financing activities. This compares to $14.4 million of cash used in financing activities during the first three months of 2023, which included the repayment of $17.3 million principal amount of our outstanding 2023 Notes. As of March 31, 2024, we had cash and cash equivalents totaling $24.1 million, which compared to $47.1 million as of December 31, 2023. As of March 31, 2024, we had no borrowings outstanding under our ABL Facility, $135.0 million principal amount of our 2026 Notes (as defined below) outstanding and other debt of $2.9 million. Our reported interest expense included amortization of deferred financing costs of $0.5 million during the first three months of 2024. For the first three months of 2024, our contractual cash interest expense was $1.9 million, or approximately 6% of the average principal balance of debt outstanding. We believe that cash on-hand, cash flow from operations and borrowing capacity available under our ABL Facility will be sufficient to meet our liquidity needs in the coming twelve months. If our plans or assumptions change, or are inaccurate, we may need to raise additional capital. Our ability to obtain capital for additional projects to implement our growth strategy over the longer term will depend upon our future operating performance, financial condition and, more broadly, on the availability of equity and debt financing. Capital availability will be affected by prevailing conditions in our industry, the global economy, the global banking and financial markets, stakeholder scrutiny of ESG matters and other factors, many of which are beyond our control. In this regard, the effect of multiple U.S. bank failures in 2023 resulted in significant disruptions to global banking and financial markets. For companies like ours that support the energy industry, these disruptions negatively impacted the value of our common stock and may reduce our ability to access capital in the bank and capital markets or result in such capital being available on less favorable terms, which could in the future negatively affect our liquidity. 27 Table of Contents On March 6, 2024, the SEC finalized rules relating to the disclosure of a range of climate-related information (the “Rules”). The Rules were temporarily stayed by the SEC on April 4, 2024 pending judicial review. While subject to ongoing litigation, these new disclosure requirements are currently effective for us beginning with the year ending December 31, 2026, phased in over a five-year period. The ultimate impact on our business is uncertain but we and our customers may incur increased compliance costs related to the assessment and disclosure of climate-related risks. We may also face increased litigation risks related to disclosures made pursuant to the rule if finalized as proposed. In addition, enhanced climate disclosure requirements could accelerate the trend of certain stakeholders and lenders in restricting access to capital or seeking more stringent conditions with respect to their investments in us, our customers and other companies like ours that support the energy industry. For more information on our risks related to climate change, see the risk factors in “Part I, Item 1A. Risk Factors” included in our 2023 Annual Report on Form 10-K titled, “Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide,” “The Inflation Reduction Act of 2022 could accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations” and “Increasing attention to ESG matters may impact our business.” Stock Repurchase Program. On February 16, 2023, the Board authorized $25.0 million for the repurchases of our common stock, par value $0.01 per share, through February 2025. Subject to applicable securities laws, such purchases will be at such times and in such amounts as we deem appropriate. During the three months ended March 31, 2024, there were no repurchases of common stock under the program. The amount remaining under our share repurchase authorization as of March 31, 2024 was $18.1 million. Revolving Credit Facility. Our senior secured credit facility provides for a $125.0 million asset-based revolving credit facility (as amended, the “ABL Facility”) under which credit availability is subject to a borrowing base calculation. On February 16, 2024, we amended the ABL Facility to extend the maturity date to February 16, 2028. The ABL Facility is governed by a credit agreement, as amended, with Wells Fargo Bank, National Association, as administrative agent and the lenders and other financial institutions from time to time party thereto (as amended, the “ABL Agreement”). The ABL Agreement, as amended, matures on February 16, 2028 with a springing maturity 91 days prior to the maturity of any outstanding indebtedness with a principal amount in excess of $17.5 million. See Note 4, “Long-term Debt,” to the Unaudited Condensed Consolidated Financial Statements included in this Quarterly Report on Form 10-Q for further information regarding the ABL Agreement. As of March 31, 2024, we had $15.9 million of outstanding letters of credit, but no borrowings outstanding under the ABL Agreement. The total amount available to be drawn as of March 31, 2024 was $86.3 million, calculated based on the then-current borrowing base less outstanding letters of credit. 2026 Notes. We issued $135.0 million aggregate principal amount of 4.75% convertible senior notes due 2026 (the “2026 Notes”) pursuant to an indenture, dated as of March 19, 2021 (the “2026 Indenture”), between us and Computershare Trust Company, National Association, as successor trustee. The 2026 Notes will mature on April 1, 2026, unless earlier repurchased, redeemed or converted. The 2026 Indenture contains certain events of default, including certain defaults by us with respect to other indebtedness of at least $40.0 million. See Note 4, “Long-term Debt,” to the Unaudited Condensed Consolidated Financial Statements included in this Quarterly Report on Form 10-Q for further information regarding the 2026 Notes. As of March 31, 2024, none of the conditions allowing holders of the 2026 Notes to convert, or requiring us to repurchase the 2026 Notes, had been met. 2023 Notes. On February 15, 2023, our 2023 Notes matured and the outstanding $17.3 million in principal amount was repaid in full. Our total debt represented 16% of our combined total debt and stockholders’ equity as of March 31, 2024 and December 31, 2023. Contingencies and Other Obligations. We are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our commercial operations, products, employees and other matters. See Note 11, “Commitments and Contingencies,” to the Unaudited Condensed Consolidated Financial Statements included in this Quarterly Report on Form 10-Q for additional discussion. Off-Balance Sheet Arrangements. As of March 31, 2024, we had no off-balance sheet arrangements. 28 Table of Contents Critical Accounting Policies For a discussion of the critical accounting policies and estimates that we use in the preparation of our condensed consolidated financial statements, see “Part II Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K for the year ended December 31, 2023. These estimates require significant judgments, assumptions and estimates. We have discussed the development, selection, and disclosure of these critical accounting policies and estimates with the audit committee of our Board of Directors. There have been no material changes to the judgments, assumptions and estimates upon which our critical accounting estimates are based. Recent Accounting Pronouncements From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board, which are adopted by us as of the specified effective date. Management believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on our consolidated financial statements upon adoption.