# Ranger Energy Services, Inc. (RNGR) Informational only - not investment advice. CIK: 0001699039 SIC: 1389 Oil & Gas Field Services, NEC SIC breadcrumb: [Mining](/division/B/) > [SIC Major Group 13](/major-group/13/) > [SIC 1389 Oil & Gas Field Services, NEC](/industry/1389/) Latest 10-K filed: 2026-03-05 SEC page: https://www.sec.gov/edgar/browse/?CIK=1699039 Filing source: https://www.sec.gov/Archives/edgar/data/1699039/000162828026015248/rngr-20251231.htm ## At a glance FY2025 · period end 2025-12-31 · filed 2026-03-05 · accession 0001628280-26-015248 · source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001699039.json | Metric | Value | FY | Provenance | | --- | ---: | ---: | --- | | Revenue | 546,900,000 USD | 2025 | verified | | Net income | 12,300,000 USD | 2025 | verified | | Assets | 419,300,000 USD | 2025 | verified | | Free cash flow | 42,900,000 USD | 2025 | computed | | Net margin | 2.25% | 2025 | computed | | Operating margin | 2.82% | 2025 | computed | | Revenue YoY | -4.24% | 2025 | computed | | ROE | 4.10% | 2025 | computed | Computed values are grepcent-computed from the verified facts above and may differ from ratios the company itself reports. Free cash flow = operating cash flow − capital expenditures. Net margin = net income ÷ revenue. Operating margin = operating income ÷ revenue. Revenue YoY = FY2025 revenue ÷ FY2024 revenue − 1 (consecutive fiscal years only). ROE = net income ÷ period-end stockholders' equity. No market price, no rating, no forecast on this site. Not investment advice. ### Peer percentile fingerprint | Ratio | RNGR | Peer median | Percentile | N | | --- | ---: | ---: | ---: | ---: | | Net margin | 2.2% | 3.7% | 29 | 15 | | Operating margin | 2.8% | 3.9% | 46 | 14 | | Revenue growth | -4.2% | -3.1% | 36 | 15 | | FCF margin | 7.8% | 4.9% | 79 | 15 | | ROE | 4.1% | 4.1% | 50 | 15 | | ROA | 2.9% | 2.8% | 57 | 15 | | Liabilities / equity | 0.40 | 0.83 | 14 | 15 | | Current ratio | 1.75 | 1.99 | 43 | 15 | Percentile = share of the N covered peers reporting that ratio whose value is lower (ties counted half); computed among grepcent-covered companies in SIC industry 1389 Oil & Gas Field Services, NEC, not the whole market. A higher percentile means a higher value of the ratio, not a better company. Ratios with fewer than 8 reporting peers are omitted. Latest reported values per company; fiscal periods may differ. Descriptive arithmetic - not a score, rating, or ranking. ## Selected Fundamentals | Metric | Value | Unit | FY | Filed | | --- | ---: | --- | ---: | --- | | Revenue | 546900000 | USD | 2025 | 2026-03-05 | | Net income | 12300000 | USD | 2025 | 2026-03-05 | | Assets | 419300000 | USD | 2025 | 2026-03-05 | ## Financials Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-03-05. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001699039.json. Derived margins, ratios, and free cash flow are computed from the extracted annual SEC facts. | Metric | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Revenue | | 154,000,000 | 303,100,000 | 336,900,000 | 187,800,000 | 293,100,000 | 608,500,000 | 636,600,000 | 571,100,000 | 546,900,000 | | Net income | | -6,600,000 | -3,300,000 | 1,800,000 | -10,300,000 | 8,600,000 | 15,100,000 | 23,800,000 | 18,400,000 | 12,300,000 | | Operating income | -4,500,000 | -20,600,000 | -2,100,000 | 12,400,000 | -17,200,000 | -40,500,000 | 19,700,000 | 36,900,000 | 28,600,000 | 15,400,000 | | Diluted EPS | | -0.78 | -0.39 | 0.21 | -1.21 | 0.63 | 0.65 | 0.95 | 0.81 | 0.54 | | Operating cash flow | -5,200,000 | -17,300,000 | 27,600,000 | 51,900,000 | 25,500,000 | -39,400,000 | 44,500,000 | 90,800,000 | 84,500,000 | 69,000,000 | | Capital expenditures | 11,200,000 | 21,700,000 | 75,900,000 | 24,200,000 | 7,200,000 | 5,600,000 | 13,800,000 | 36,500,000 | 34,100,000 | 26,100,000 | | Dividends paid | 3,000,000 | | | | | | 0.00 | 2,400,000 | 4,500,000 | 5,500,000 | | Share buybacks | | | 0.00 | 700,000 | 3,100,000 | 0.00 | 0.00 | 19,300,000 | 15,500,000 | 12,200,000 | | Assets | 135,700,000 | 259,700,000 | 302,500,000 | 293,500,000 | 240,600,000 | 393,100,000 | 381,600,000 | 378,000,000 | 381,600,000 | 419,300,000 | | Liabilities | 23,100,000 | 64,000,000 | 110,500,000 | 90,500,000 | 55,800,000 | 144,400,000 | 115,400,000 | 106,200,000 | 107,800,000 | 119,200,000 | | Stockholders' equity | | 103,700,000 | 101,900,000 | 113,200,000 | 101,900,000 | 248,700,000 | 266,200,000 | 271,800,000 | 273,800,000 | 300,100,000 | | Cash and cash equivalents | 3,400,000 | 5,300,000 | 2,600,000 | 6,900,000 | 2,800,000 | 600,000 | 3,700,000 | 15,700,000 | 40,900,000 | 10,300,000 | | Free cash flow | -16,400,000 | -39,000,000 | -48,300,000 | 27,700,000 | 18,300,000 | -45,000,000 | 30,700,000 | 54,300,000 | 50,400,000 | 42,900,000 | ### Ratios ROE and ROA use period-end equity/assets. Liabilities / equity uses total liabilities divided by stockholders' equity. Current ratio uses current assets divided by current liabilities when both are reported. | Metric | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Net margin | | -4.29% | -1.09% | 0.53% | -5.48% | 2.93% | 2.48% | 3.74% | 3.22% | 2.25% | | Operating margin | | -13.38% | -0.69% | 3.68% | -9.16% | -13.82% | 3.24% | 5.80% | 5.01% | 2.82% | | Return on equity | | -6.36% | -3.24% | 1.59% | -10.11% | 3.46% | 5.67% | 8.76% | 6.72% | 4.10% | | Return on assets | | -2.54% | -1.09% | 0.61% | -4.28% | 2.19% | 3.96% | 6.30% | 4.82% | 2.93% | | Liabilities / equity | | 0.62 | 1.08 | 0.80 | 0.55 | 0.58 | 0.43 | 0.39 | 0.39 | 0.40 | | Current ratio | 1.87 | 0.93 | 1.04 | 1.07 | 1.08 | 1.02 | 1.88 | 1.96 | 2.21 | 1.75 | ## As-reported value updates 2 tracked differences above grepcent's stated thresholds were found between the earliest XBRL-filed value and the value currently on file for the same fiscal period. Ledger: /company/RNGR/revisions/ ## Quarterly Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-04-28. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001699039.json. Flow metrics use discrete quarter-length periods from 10-Q/10-Q/A filings. Q4 revenue and net income are derived only when annual FY and nine-month YTD facts exist for the same fiscal year; derived Q4 values are labeled. EPS Q4 is not derived. | Quarter | End date | Revenue | Net income | Diluted EPS | Method | | --- | --- | ---: | ---: | ---: | --- | | 2022-Q2 | 2022-06-30 | | | -0.02 | reported discrete quarter | | 2022-Q3 | 2022-09-30 | | | 0.54 | reported discrete quarter | | 2023-Q1 | 2023-03-31 | | | 0.25 | reported discrete quarter | | 2023-Q2 | 2023-06-30 | 163,200,000 | 6,100,000 | 0.24 | reported discrete quarter | | 2023-Q3 | 2023-09-30 | 164,400,000 | 9,400,000 | 0.38 | reported discrete quarter | | 2023-Q4 | 2023-12-31 | 151,500,000 | 2,100,000 | | derived Q4 = FY annual - nine-month YTD | | 2024-Q1 | 2024-03-31 | 136,900,000 | -800,000 | -0.03 | reported discrete quarter | | 2024-Q2 | 2024-06-30 | 138,100,000 | 4,700,000 | 0.21 | reported discrete quarter | | 2024-Q3 | 2024-09-30 | 153,000,000 | 8,700,000 | 0.39 | reported discrete quarter | | 2024-Q4 | 2024-12-31 | 143,100,000 | 5,800,000 | | derived Q4 = FY annual - nine-month YTD | | 2025-Q1 | 2025-03-31 | 135,200,000 | 600,000 | 0.03 | reported discrete quarter | | 2025-Q2 | 2025-06-30 | 140,600,000 | 7,300,000 | 0.32 | reported discrete quarter | | 2025-Q3 | 2025-09-30 | 128,900,000 | 1,200,000 | 0.05 | reported discrete quarter | | 2025-Q4 | 2025-12-31 | 142,200,000 | 3,200,000 | | derived Q4 = FY annual - nine-month YTD | | 2026-Q1 | 2026-03-31 | 159,100,000 | 3,000,000 | 0.12 | reported discrete quarter | ## Filed narrative (10-K & 10-Q) ## Business Verbatim Item 1 Business section from RNGR's latest 10-K: [/company/RNGR/business/](/company/RNGR/business/). ## Risk Factors Verbatim Item 1A Risk Factors from RNGR's latest 10-K: [/company/RNGR/risk-factors/](/company/RNGR/risk-factors/). ## Latest quarter (10-Q) Latest 10-Q source: https://www.sec.gov/Archives/edgar/data/1699039/000162828026050161/rngr-20260630.htm Extracted structurally from real Item 2 body heading to real Item 3/4 boundary. Confidence: high Filing date: 2026-07-28 Report date: 2026-06-30 Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations The following discussion and analysis should be read in conjunction with the historical financial statements and related notes included in Part I, Item 1. Financial Statements (Unaudited) of this Quarterly Report on Form 10-Q (the “Quarterly Report”). This discussion contains “forward-looking statements” reflecting our current expectations, estimates and assumptions concerning events and financial trends that may affect our future operating results or financial position. Actual results and the timing of events may differ materially from those contained in these forward-looking statements due to a number of factors. Factors that could cause or contribute to such differences include, but are not limited to, market prices and demand for oil and natural gas, capital expenditures, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed elsewhere in this report. Please read the Cautionary Statement Regarding Forward-Looking Statements. Also, please read the risk factors and other cautionary statements described under “Risk Factors” in this Quarterly Report and in our Annual Report. We assume no obligation to update any of these forward-looking statements except as required by law. Except as otherwise indicated or required by the context, all references in this Quarterly Report to the “Company,” “Ranger,” “Ranger, Inc.,” “we,” “us,” or “our” relate to Ranger Energy Services, Inc. and its consolidated subsidiaries. How We Evaluate Our Operations We provide services within the U.S. that are organized into three reporting segments: High Specification Rigs, Wireline Services, and Processing Solutions and Ancillary Services, which are described below. The reportable segments have been categorized based on the nature of services provided within each line of business. Our service offerings consist of well completion support, workover, well maintenance, wireline, and other complementary services, as well as well installation, commissioning, and operation of modular equipment, which are conducted in three reportable segments, as follows: •High Specification Rigs. Provides high specification well service rigs and complementary equipment and services to facilitate operations throughout the lifecycle of a well. •Wireline Services. Provides services necessary to bring and maintain a well on production and consists of our completion, production and pump down service lines. •Processing Solutions and Ancillary Services. Provides other services often utilized in conjunction with our High Specification Rigs and Wireline Services segments. These services include equipment rentals, plug and abandonment, logistics, coil tubing, mixing plants and chemicals, tubing and inspection, transportation, and processing solutions. •Other. Other represents costs not allocable to the reporting segments and includes corporate general and administrative expense and depreciation of corporate furniture and fixtures, amortization, impairments and other items similar in nature. For additional financial information about our segments, please see “Item 1. Financial Statements (Unaudited)—Note 17 — Segment Reporting.” Business Outlook Market conditions across the oilfield services sector were mixed during the second quarter of 2026. Geopolitical developments and disruptions to global oil supply contributed to elevated commodity prices and continued market volatility. The Company expects customer activity to continue to be shaped primarily by operators’ longer-term capital discipline, basin-level economics and production priorities rather than short-term commodity price movements alone. Our production-oriented service lines continue to support relative resilience in our core business. Although elevated commodity prices and potential supply constraints may support customer activity in the near term, the timing and extent of any corresponding changes in customer spending in the mid to longer term is unclear. The longer global oil and gas supply chain disruptions persist, there is an increased likelihood of supply shortages which could drive up commodity prices further. Elevated prices may cause ultimate demand weakening which would have the potential to affect North American oil and gas activity. The Company continues to monitor macroeconomic and industry developments that may affect demand for its services. During the second quarter of 2026, the West Texas Intermediate (“WTI”) crude oil spot price averaged approximately $96 per barrel, compared to approximately $72 per barrel during the first quarter of 2026 and approximately $65 per barrel during the second quarter of 2025. For the six months ended June 30, 2026, the WTI crude oil spot price averaged approximately $84 per barrel, compared to approximately $68 per barrel during the same period in 2025. The U.S. Energy Information Administration (“EIA”) noted in its July 2026 Short-Term Energy Outlook that WTI crude oil prices are expected to average approximately 24 $70 per barrel during the third quarter of 2026 before declining to approximately $66 per barrel during the fourth quarter of 2026. The EIA also forecast U.S. crude oil production to average approximately 13.7 million barrels per day in 2026. Although commodity prices have been impacted by recent disruptions in the Middle East, the Company believes customers will continue to prioritize efficient production from existing wells and disciplined development activity. As a provider of production- and completion-oriented well services with solely domestic operations, we believe our service offering is positioned to benefit from customer demand tied to maintaining and enhancing production. However, reductions in customer capital spending, weakening oil demand, sustained cost inflation or increased competitive pricing pressures could adversely affect utilization, pricing and financial results, particularly in service lines more directly exposed to discretionary completions activity. Following the acquisition of AWS in November 2025, the Company has a larger presence in the Permian Basin and an operating footprint more heavily concentrated in this basin than in prior operating periods. AWS complements the Company’s existing service offerings and contributed to the Company’s financial results during the first half of 2026. During the remainder of the year, the Company remains focused on continuing to realize the expected benefits of the acquisition, maintaining service quality for customers and preserving liquidity and balance sheet flexibility. The Company also continues to monitor longer-term trends that may influence demand for its services, including ongoing regulatory focus on emissions and flaring, the pace of natural gas infrastructure development and data center power demands and also changing customer demand for field-level gas processing solutions. While the Company’s direct exposure to natural gas markets is more limited than its exposure to crude oil markets, these factors could provide incremental support for certain of the Company’s service offerings. Financial Metrics How We Generate Revenue Rig hours and stage counts, as they relate to our High Specification Rigs and parts of our Wireline Services segments, respectively, are important indicators of our activity levels and profitability. Rig hours represent the aggregate number of hours that our well service rigs actively worked. Stage counts represent the number of completed stages during the periods presented for the completion service line within our Wireline Services segment. Generally, during the period in which our services are provided, our customers are billed on an hourly basis for our high specification rigs services or, as it relates to our wireline services, customers are billed upon the completion of the well, on a monthly basis, or on a per job basis. The rates at which the customers are billed are generally predetermined based upon a contractual agreement. Costs of Conducting Our Business The principal costs associated with conducting our business are personnel, repairs and maintenance, general and administrative, and depreciation expense. Cost of Services. The primary costs associated with our cost of services are related to personnel expenses and repairs and maintenance of our fixed assets. A significant portion of these expenses are variable, and therefore typically managed based on industry conditions and demand for our services. Further, there is generally a correlation between our revenue generated and personnel and repairs and maintenance costs, which are dependent upon the operational activity. Personnel costs associated with our operational employees represent the most significant cost of our business. A substantial portion of our labor costs is attributable to our field crews and is partly variable based on the requirements of specific customers. General & Administrative. General and administrative expenses are corporate in nature and are included within Other. These costs include the majority of centrally-located company management and administrative personnel and are not attributable to any of our lines of business or reporting segments. Operating Income or Loss We analyze our operating income or loss by segment, which we have defined as revenue less cost of services and depreciation expense. We believe this is a key financial metric as it provides insight into profitability and operational performance based on the historical cost basis of our assets. Adjusted EBITDA We view Adjusted EBITDA, which is a non‑GAAP financial measure, as an important indicator of performance. The CODM primarily uses Adjusted EBITDA to assess segment profitability and make resource allocation decisions. We define Adjusted EBITDA as net income or loss before net interest expense, income tax expense, depreciation and amortization, equity-based compensation, acquisition related costs, severance and reorganization costs, gain on sale of assets, significant and unusual legal fees and settlements, impairment of assets, employee retention credit, adjustment to contingent consideration, and certain 25 other non‑cash and certain other items that we do not view as indicative of our ongoing performance. See “—Results of Operations” and “—Note Regarding Non‑GAAP Financial Measure” for more information and reconciliations of net income (loss) to Adjusted EBITDA, the most directly comparable financial measure calculated and presented in accordance with U.S. GAAP. Results of Operations Three Months Ended June 30, 2026 compared to Three Months Ended June 30, 2025 The following is an analysis of our operating results. See “—How We Evaluate Our Operations” for definitions of rig hours, stage counts and other analogous information, as well as key operating metrics (in millions). [Excerpt truncated for page length; source filing is linked above.] ## Latest 10-K MD&A (excerpt) Latest 10-K Item 7 source: https://www.sec.gov/Archives/edgar/data/1699039/000162828026015248/rngr-20251231.htm Complete FY 2025 MD&A: /company/RNGR/mda/fy2025/ Extracted structurally from real Item 7 body heading to real Item 7A/8 boundary. Confidence: high Filing date: 2026-03-05 Report date: 2025-12-31 Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations The following discussion and analysis should be read in conjunction with the historical financial statements and related notes included elsewhere in this Annual Report. This discussion contains “forward‑looking statements” reflecting our current expectations, estimates and assumptions concerning events and financial trends that may affect our future operating results or financial position. These statements include certain risks and uncertainties. Please read “Cautionary Statement Regarding Forward‑Looking Statements” and the risk factors described under “Part I, Item 1A.-Risk Factors” for more details. 30 2025 Business Update Business Outlook We are a provider of onshore high specification well service rigs and complementary services in the U.S. We provide an extensive range of well site services to leading U.S. E&P companies that are fundamental to establishing, maintaining and enhancing the flow of oil and natural gas throughout the productive life of a well. Additionally, we serve to assist our customers in decommissioning wells at the end of their economic life. A comprehensive discussion of each of our reporting segments is included below in the section titled “How We Evaluate Our Operations.” We operate in most of the active oil and natural gas basins in the U.S., including the Permian Basin, Denver-Julesburg Basin, Bakken Shale, Eagle Ford Shale, Haynesville Shale, Gulf Coast, South Central Oklahoma Oil Province and Sooner Trend Anadarko Basin Canadian and Kingfisher Counties plays. As the Company looks ahead to 2026, we anticipate that our core business will remain resilient in the face of continued macroeconomic pressures. We expect our financial results to show meaningful year-over-year improvement, driven by our production-oriented focus, our continued relationships with our core customers that represent the largest E&P businesses in the Lower 48, and our increased exposure to the Permian Basin following the acquisition of AWS. We believe the acquisition of AWS will deliver more than $36.0 million in Adjusted EBITDA in fiscal year 2026, while legacy Ranger business lines are expected to remain largely flat year-over-year in the current oil and gas environment. As we are a production-focused business with solely domestic operations, we have considered the U.S. Energy Information Administration’s (“EIA”) estimate that daily crude oil production in the U.S. is expected to remain flat from 2025 to 2026 at 13.6 million barrels per day, up from 13.2 million barrels per day in 2024. The EIA estimates that Lower 48 crude oil production in the U.S. is expected to average 11.1 million barrels per day in 2026, down from 11.3 million barrels per day in 2025 but still up from 11.0 million barrels per day in 2024. In the Permian Basin, where we have our largest base of operations following the acquisition of AWS, crude oil production is expected to remain flat from 2025 to 2026 at 6.6 million barrels per day, up from 6.3 million barrels per day in 2024. With supply and demand remaining imbalanced, downward pressure on prices is forecasted by both the International Energy Agency and the U.S. Energy Information Administration, with oil prices expected to average approximately $56 per barrel during 2026 as compared to $69 per barrel in 2025 and $81 per barrel in 2024. Our business should benefit from increased demand for natural gas, driven by domestic electricity demand and international demand for increasing LNG exports from the U.S. While our direct exposure to natural gas markets is limited in comparison to our crude oil exposure, the assets both we and our competition operate in basins are capable of being deployed across both crude oil and natural gas wells and tightening in either market should benefit the broader complex. We also see potential tailwinds for our Torrent natural gas processing solution as increases in regulatory requirements around flaring and natural gas demand provide a positive long-term setup. Acquisitions and Integrations During the last five years, the Company placed significant focus on acquiring and integrating assets and associated operations, described below, into current business processes. Through these acquisitions and their subsequent integrations, Ranger has continued to refine its business strategies and processes to focus on the performance of the Company and anticipates that acquisitions will continue to play a key role in the business going forward. During 2021, Ranger Energy Acquisition, LLC entered into an Asset Purchase Agreement for certain assets of Basic Energy Services, Inc. and certain of its subsidiaries. As consideration for the assets acquired, the Company paid $36.7 million in cash, where such cash was generated through the issuance of Series A Preferred Stock. Purchased assets included well servicing rigs, fishing and rental assets, coiled tubing units, and rolling stock assets required to support the operating assets as well as certain real property. Separately, during 2021, the Company made two additional acquisitions of wireline service providers that operated throughout the Permian, Denver-Julesburg and Powder River Basins and the Bakken Shale. These acquisitions significantly expanded the scale and scope of the existing wireline business. During 2023, the Company complemented the earlier acquisitions with the purchase of certain pumping assets and associated equipment to continue to bolster its wireline segment capabilities. In November 2025 the Company completed the acquisition of AWS, which operates a fleet of high specification rigs and complementary supporting equipment within the Permian Basin, for a total estimated consideration of approximately $88.6 million, consisting of $61.8 million in cash paid at closing, net of a $3.0 million working capital adjustment, 1,998,401 shares of Class A Common Stock issued to the seller, and a $2.3 million contingent consideration measured at fair value that the seller is eligible to receive based on the performance of the AWS acquisition during the 12 months following the acquisition date. To fund the cash portion of the acquisition, the Company borrowed $22.0 million under its Wells Fargo Revolving Credit Facility, of which $18.5 million has since been repaid, leaving a balance of $3.5 million as of December 31, 2025. As a result, the Company maintained substantial available liquidity following the acquisition. The business is highly 31 complementary to our existing services and is expected to contribute more than $36.0 million in Adjusted EBITDA in fiscal year 2026 as it is integrated into the Company. The financial results of AWS subsequent to the acquisition date are included within the High Specification Rigs and Processing Solutions and Ancillary Services reporting segments. From the acquisition date through December 31, 2025, the acquired business contributed approximately $26.7 million of revenue and $6.9 million of net income to the Company’s consolidated results. We remained active in the pursuit of accretive opportunities and will continue to do so during 2026. Internal Controls and Procedures Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, the Company conducted an evaluation of the effectiveness of our internal control over financial reporting as of December 31, 2025 based on the guidelines established in the Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on its assessment, management concluded that the Company’s internal control over financial reporting was effective as of December 31, 2025. For further information, please see “Part II, Item 9A. Controls and Procedures.” How We Evaluate Our Operations We provide services within the U.S. that are organized into three reporting segments: High Specification Rigs, Wireline Services, and Processing Solutions and Ancillary Services, which are described below. The reportable segments have been categorized based on the nature of services provided within each line of business. Our service offerings consist of well completion support, workover, well maintenance, wireline, other complementary services, as well as well installation, commissioning and operating of modular equipment, which are conducted in three reportable segments, as follows: •High Specification Rigs. Provides high specification well service rigs to facilitate operations throughout the lifecycle of a well. •Wireline Services. Provides services necessary to bring and maintain a well on production and consists of our completion, production and pump down service lines. •Processing Solutions and Ancillary Services. Provides other services often utilized in conjunction with our High Specification Rigs and Wireline Services segments. These services include equipment rentals, plug and abandonment, logistics, coil tubing, mixing plants and chemicals, tubing and inspection, transportation, and processing solutions. •Other. Other represents costs not allocable to the reporting segments and includes corporate general and administrative expense and depreciation of corporate furniture and fixtures, amortization, impairments and other items similar in nature. Financial Metrics How We Generate Revenue Rig hours and stage counts, as it relates to our High Specification Rigs and parts of our Wireline Services segments, respectively, are important indicators of our activity levels and profitability. Rig hours represent the aggregate number of hours that our well service rigs actively worked. Stage counts represent the number of completed stages during the periods presented for the completion service line within our Wireline Services segment. Generally, during the period our services are being provided, our customers are billed on an hourly basis for our high specification rig services or, as it relates to our wireline services, customers are billed upon the completion of the well, on a monthly basis, or on a per job basis. The rates for which the customer is billed is generally predetermined based upon a contractual agreement. Costs of Conducting Our Business The principal costs associated with conducting our business are personnel, repairs and maintenance, general and administrative, and depreciation expense. Cost of Services. The primary costs associated with our cost of services are related to personnel expenses and repairs and maintenance of our fixed assets. A significant portion of these expenses are variable, and therefore typically managed based on industry conditions and demand for our services. Further, there is generally a correlation between our revenue generated and personnel and repairs and maintenance costs, which are dependent upon the operational activity. 32 Personnel costs associated with our operational employees represent the most significant cost of our business. A substantial portion of our labor costs is attributable to our field crews and is partly variable based on the requirements of specific customers. General & Administrative. General and administrative expenses are corporate in nature and are included within Other. These costs include the majority of centrally-located company management and administrative personnel and are not attributable to any of our lines of businesses nor reporting segments. Operating Income or Loss We analyze our operating income or loss by segment, which we have defined as revenue less cost of services and depreciation expense. We believe this is a key financial metric as it provides insight on profitability and operational performance based on the historical cost basis of our assets. Adjusted EBITDA We view Adjusted EBITDA, which is a non‑GAAP financial measure, as an important indicator of performance. The Chief Operat [Excerpt truncated for page length; the complete text is on the linked full-MD&A page.] Read the full FY 2025 MD&A: /company/RNGR/mda/fy2025/ All MD&A years: /company/RNGR/mda/ ## MD&A history Prior-year 10-K MD&A spans are extracted from SEC filings with the same bounded parser used for the latest filing. Each year's full verbatim text is on its own sub-page. - [FY 2024 MD&A](/company/RNGR/mda/fy2024/): filed 2025-03-04; accession 0001699039-25-000015 (https://www.sec.gov/Archives/edgar/data/1699039/000169903925000015/rngr-20241231.htm) - [FY 2023 MD&A](/company/RNGR/mda/fy2023/): filed 2024-03-05; accession 0001699039-24-000025 (https://www.sec.gov/Archives/edgar/data/1699039/000169903924000025/rngr-20231231.htm) - [FY 2022 MD&A](/company/RNGR/mda/fy2022/): filed 2023-03-13; accession 0001699039-23-000016 (https://www.sec.gov/Archives/edgar/data/1699039/000169903923000016/rngr-20221231.htm) - [FY 2021 MD&A](/company/RNGR/mda/fy2021/): filed 2022-03-30; accession 0001699039-22-000029 (https://www.sec.gov/Archives/edgar/data/1699039/000169903922000029/rngr-20211231.htm) ## Macro cross-references Indicators mapped to this company's SIC classification (industry 1389 Oil & Gas Field Services, NEC) by grepcent's deterministic macro-sector crosswalk. A navigational mapping, not a statistical or causal claim. - [INDPRO](/indicator/INDPRO/): Industrial Production: Total Index - [TCU](/indicator/TCU/): Capacity Utilization: Total Index - [PPIACO](/indicator/PPIACO/): Producer Price Index by Commodity: All Commodities - [DGS10](/indicator/DGS10/): Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity - [FEDFUNDS](/indicator/FEDFUNDS/): Federal Funds Effective Rate Macro-to-micro threads including this sector: [Inflation (CPI / PCE / PPI)](/thread/inflation-cpi-pce-ppi/). All macro indicators: /indicators/ ## For LLMs & downloads Markdown twin: /company/RNGR.md · JSON record: /company/RNGR.json · verified financials: /company/RNGR/financials.json / /company/RNGR/financials.csv · machine TOC for the whole site: /llms.txt