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r

Washington, D.C. 20549

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission file number 001-38183

(Exact name of registrant as specified in its charter)

(Address of principal executive offices) (Zip Code)

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of April 23, 2025, the registrant had 22,498,082 shares of Class A Common Stock and zero shares of Class B Common Stock outstanding.

The information in this Quarterly Report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact included in this Quarterly Report, regarding our strategy, future operations, financial position, estimated revenue and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this Quarterly Report, the words “may,” “should,” “intend,” “could,” “believe,” “anticipate,” “estimate,” “expect,” “outlook,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements represent Ranger’s expectations or beliefs concerning future events, and it is possible that the results described in this Quarterly Report will not be achieved.

These forward-looking statements are subject to risks, uncertainties, and other factors, many of which are outside of Ranger’s control. Should one or more of these risks or uncertainties described occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. These risks could materially and adversely affect our financial condition, results of operations and prospects, and include, but are not limited to, the risks described under “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2024 (the “Annual Report”) filed with the U.S. Securities and Exchange Commission (the “SEC”), those set forth from time-to-time in other filings by the Company with the SEC, and those in this Form 10-Q, including the following factors:

•reductions in capital spending by participants in the oil and natural gas industry;

•volatility of oil and natural gas prices, as well as fuel conservation measures, impacting the supply and demand for oil and natural gas;

•capital expenditures for new equipment as we grow our operations and capital expenditures resulting from environmental initiatives, new regulatory requirements, and advancements in oilfield services technologies;

•intense competition (including as to pricing) that may cause us to lose market share and could negatively affect our ability to market our services and expand our operations;

•reduced demand for our services, including as a result of fuel conservation measures and resulting reduction in demand for oil and natural gas;

•difficulties we may have managing the growth of our business, including through potential future acquisitions and mergers;

•customer concentrations and reliance upon a few large customers that may adversely affect our revenue and operating results;

•increasing competition for workers, as well as labor shortages, and challenges to our ability to attract, hire, and retain qualified and skilled employees;

•unsatisfactory safety performance may negatively affect our current and future customer relationships, and to the extent we fail to retain existing customers or attract new customers, adversely impact our revenue;

•accidents, blowouts, explosions, craterings, fires, oil spills and releases of drilling, completion or fracturing fluids or hazardous materials or pollutants into the environment;

•claims, including personal injury and property damages;

•federal and state legislative and regulatory initiatives that could result in increased costs and additional operating restrictions or delays, as well as adversely affect demand for our support services;

•environmental and occupational health and safety laws and regulations that may expose us to significant costs and liabilities;

•risks arising from climate change, and increased attention and proposed and future requirements relating to sustainability, environmental, social, and governance (“ESG”) matters and conservation measures may adversely impact our or our customers’ businesses;

•seasonal weather conditions, severe weather events and natural disasters that could severely disrupt normal operations and harm our business;

•cybersecurity and data privacy risks, including interruptions, failures or attacks in our information technology system;

•interest rate risk as a result of our revolving credit facility and financing agreement to fund operations;

•certain restrictions under the terms of our Wells Fargo Revolving Credit Facility (as defined below) may limit our future ability to pay cash dividends;

•liquidity and access to capital that could result in challenges and vulnerabilities associated with our ability to secure the necessary financial resources to support its operations, growth, and strategic initiatives;

•potential challenges, uncertainties, and risks associated with the rapid development and adoption of new technologies that could displace our existing asset base or impact traditional oil and gas operations, including automation, artificial intelligence, and renewable energy solutions;

•sufficiency of our insurance program to adequately protect against potential risks and liabilities;

•commodity price risk due to fluctuations in the prices of oil and natural gas, and resulting impacts on the activity levels of our exploration and production (“E&P”) customers;

•the impact of geopolitical, economic and market conditions and developments, including changes in global trade policies and tariffs, on our industry and commodity prices;

•credit risk associated with our trade receivables;

•general economic conditions or a weakening of the broader energy industry, including as a result of inflation or recession; and

•risks related to our ownership and capital structure.

Our future results will depend upon various other risks and uncertainties, including, but not limited to, those detailed in our current and past filings with the SEC. Those documents are available through our website or through the SEC’s Electronic Data Gathering and Analysis Retrieval system at www.sec.gov.

All forward‑looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, any forward-looking statements speak only as of the date on which it is made. We disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this cautionary section, to reflect events or circumstances after the date of this Quarterly Report.

Ranger Energy Services, Inc. (“Ranger, Inc.,” “Ranger,” “we,” “us,” “our” or the “Company”) is a provider of onshore high specification well service rigs, wireline services, and additional processing solutions and ancillary services in the United States (“U.S.”). The Company provides an extensive range of well site services to leading U.S. E&P companies that are fundamental to establishing and maintaining the flow of oil and natural gas throughout the productive life of a well.

Our service offerings consist of well completion support, workover, well maintenance, wireline, and other complementary services, as well as 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 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 complimentary services often utilized in conjunction with our High Specification Rigs and Wireline Services segments. These services primarily include equipment rentals, plug and abandonment, logistics, coil tubing, and processing solutions.

The Company’s operations take place 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, Gulf Coast, South Central Oklahoma Oil Province and Sooner Trend, Anadarko Basin, and Canadian and Kingfisher Counties plays.

Ranger, Inc. was incorporated as a Delaware corporation in February 2017. In conjunction with the initial public offering of Class A Common Stock, par value $0.01 per share (“Class A Common Stock”), which closed on August 16, 2017 (the “Offering”), and the corporate reorganization Ranger Inc. underwent in connection with the Offering, Ranger Inc. became a holding company, and its sole material assets consist of membership interests in RNGR Energy Services, LLC, a Delaware limited liability company (“Ranger LLC”). Ranger LLC owns all of the outstanding equity interests in Ranger Energy Services, LLC (“Ranger Services”) and Torrent Energy Services, LLC (“Torrent Services”), and the other subsidiaries through which it operates its assets. Ranger LLC is the sole managing member of Ranger Services and Torrent Services, and is responsible for all operational, management and administrative decisions relating to Ranger Services, its subsidiaries, and Torrent Services’ business and consolidates the financial results of Ranger Services, its subsidiaries, and Torrent Services.

The unaudited Condensed Consolidated Financial Statements of the Company have been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”) for interim financial information and the SEC instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, certain information and disclosures have been condensed or omitted. The Condensed Consolidated Financial Statements reflect all normal and recurring adjustments that are, in the opinion of management, necessary for the fair presentation of the results of operations for the interim periods. These interim financial statements should be read in conjunction with our audited consolidated financial statements and related notes included in the Annual Report. Interim results for the periods presented may not be indicative of results that will be realized for future periods.

The Company’s significant accounting policies are disclosed in Note 2 — Summary of Significant Accounting Policies of the Annual Report.

The preparation of Condensed Consolidated Financial Statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the Condensed Consolidated Financial Statements and the reported amounts of revenue and expenses during the reporting period. Management uses historical and other pertinent information to determine these estimates. Actual results could differ from such estimates.

Areas where critical accounting estimates are made by management include:

•Depreciation and amortization of property and equipment and intangible assets;

•Impairment of property and equipment and intangible assets;

•Collectability of accounts receivable and estimates of allowance for credit losses;

•Income taxes; and

•Equity-based compensation.

In November 2023, the FASB issued Accounting Standards Update No. 2023-07, “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures” (“ASU 2023-07”), which is intended to improve reportable segment disclosure requirements, primarily through enhanced disclosures about significant segment expenses. The guidance is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption was permitted. The guidance is to be applied retrospectively to all prior periods presented in the financial statements. Upon transition, the segment expense categories and amounts disclosed in the prior periods should be based on the significant segment expense categories identified and disclosed in the period of adoption. The Company adopted this standard on December 31, 2024 within “Part II, Item 8. Financial Statements and Supplementary Data—Note 16 — Segment Reporting.”

In December 2023, the FASB issued Accounting Standards Update No. 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures” (“ASU 2023-09”), which modifies the rules on income tax disclosures to require entities to disclose (1) specific categories in the rate reconciliation, (2) the income or loss from continuing operations before income tax expense or benefit (separated between domestic and foreign) and (3) income tax expense or benefit from continuing operations (separated by federal, state and foreign). ASU 2023-09 also requires entities to disclose their income tax payments to international, federal, state and local jurisdictions, among other changes. The guidance is effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued or made available for issuance. ASU 2023-09 should be applied on a prospective basis, but retrospective application is permitted. The Company adopted this standard on a prospective basis on December 31, 2024 within “Part II, Item 8. Financial Statements and Supplementary Data—Note 12 — Income Taxes.”

In November 2024, the FASB issued Accounting Standards Update No. 2024-03, “Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses” (“ASU 2024-03”). The guidance in ASU 2024-03 requires public business entities to disclose in the notes to the financial statements, among other things, specific information about certain costs and expenses including purchases of inventory; employee compensation; and depreciation, amortization and depletion expenses for each caption on the income statement where such expenses are included. ASU 2024-03 is effective for annual reporting periods beginning after December 15, 2026, and interim reporting periods beginning after December 15, 2027. In January 2025, the FASB issued Accounting Standards Update 2025-01—Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Clarifying the effective date, which only impacts public business entities with non-calendar year-end reporting periods. As such, the original effective date pronounced in ASU 2024-03 remains applicable for Ranger. Based on both the ASU 2024-03 and subsequent clarification in ASU 2025-01, early adoption is permitted, and the amendments may be applied prospectively to reporting periods after the effective date or retrospectively to all periods presented in the financial statements. We are currently evaluating the potential impact of adopting this new guidance on our consolidated financial statements and related disclosures.

Assets held for sale include the net book value of assets the Company plans to sell within the next 12 months and are primarily related to excess non-working assets. Long-lived assets that meet the held for sale criteria are held for sale and reported at the lower of their carrying value or fair value less estimated costs to sell.

As of March 31, 2025, the Company classified $0.8 million of idle high specification rigs within our broader rig portfolio as held for sale as they are being actively marketed, as compared to $0.6 million of land and buildings held for sale as of March 31, 2024.

For the three months ended March 31, 2025 and 2024, the Company recognized a net loss on assets previously held in Property and equipment of $0.7 million and a net gain on assets previously held for sale of $1.3 million, respectively, which is shown on the Condensed Consolidated Statements of Operations.

Property and equipment, net include the following (in millions):

Depreciation expense was $10.4 million and $11.0 million for the three months ended March 31, 2025 and 2024, respectively.

Definite lived intangible assets are comprised of the following (in millions):

Amortization expense was $0.2 million and $0.2 million for the three months ended March 31, 2025 and 2024, respectively. Amortization expense for the future periods is expected to be as follows (in millions):

Accrued expenses include the following (in millions):

The Company has operating leases, primarily for real estate and equipment, with terms that vary from one to nine years, included in operating lease costs in the table below. The operating leases are included in Short-term lease liability and Long-term lease liability in the Condensed Consolidated Balance Sheets.

Lease costs associated with yard and field offices are included in cost of services and executive offices are included in general and administrative costs in the Condensed Consolidated Statements of Operations. Lease costs and other information related to operating leases for the three months ended March 31, 2025 and 2024, are as follows (in millions):

As of March 31, 2025, aggregate future minimum lease payments under operating leases are as follows (in millions):

On February 1, 2025 the Company entered into an agreement to sublease a 38,033 square foot property located in Midland, Texas. The sublease will cover the remaining term of the head lease for the property with no renewal options, ending September 30, 2027. Sublease income will be reported separately from the operating lease expense as part of other income. The Company recognized an impairment to the right of use asset associated with this operating lease of $0.4 million, in accordance with ASC 360-10 on February 1, 2025. The fair value of the right of use asset was measured as the present value of the future sublease cash flows using the Company’s incremental borrowing rate.

The Company leases certain assets, primarily automobiles, under finance leases with terms that are generally three to five years. The assets and liabilities under finance leases are recorded at the lower of the present value of the minimum lease payments or the fair value of the assets. The assets are amortized over the shorter of the estimated useful lives or over the lease term. The finance leases are included in Property and equipment, net, Short-term lease liability and Long-term lease liability in the Condensed Consolidated Balance Sheets.

Lease costs and other information related to finance leases for the three months ended March 31, 2025 and 2024, are as follows (in millions):

As of March 31, 2025, aggregate future minimum lease payments under finance leases are as follows (in millions):

The Company has sale, lease-back agreements for land and certain other fixed assets with terms that vary from 18 months to 13 years. The sales did not qualify for sale accounting, therefore these leases were classified as finance leases and no gain or loss was recorded. The net book value of the assets remained in Property and equipment, net and are depreciating over their original useful lives.

As of March 31, 2025, aggregate future lease payments of the financing liabilities are as follows (in millions):

The Wells Fargo Revolving Credit Facility was drawn in part on May 31, 2023, to repay the Revolving Credit Facility, M&E Term Loan Facility, and the Secured Promissory Note, as defined below. The undrawn portion of the Wells Fargo Revolving Credit Facility is available to fund working capital and other general corporate expenses and for other-permitted uses, including the financing of permitted investments and restricted payments, such as dividends and share repurchases. The Wells Fargo Revolving Credit Facility is subject to a borrowing base that is calculated based upon a percentage of the Company’s eligible accounts receivable and eligible unbilled revenue less certain reserves. The Company’s eligible accounts receivable serve as collateral for the borrowings under the Wells Fargo Revolving Credit Facility, which is scheduled to mature on May 31, 2028. The Wells Fargo Revolving Credit Facility includes an acceleration clause and cash dominion provisions under certain circumstances that permits the administrative agent to sweep cash daily from certain bank accounts into an account of the administrative agent to repay the Company’s obligations under the Revolving Credit Facility. The borrowings of the Wells Fargo Revolving Credit Facility, therefore, will be classified as Long-term debt, current portion on the Condensed Consolidated Balance Sheets.

In 2017, the Company adopted the Ranger Energy Services, Inc. 2017 Long Term Incentive Plan (the “2017 Plan”). The Company has granted shares of restricted stock (“restricted shares” or “RSAs”), restricted stock units (“restricted units” or “RSUs”), and performance-based restricted stock units (“performance stock units” or “PSUs”) under the 2017 Plan.

While the Company has historically granted RSAs, which generally vest in three equal annual installments following the year in which they were granted, during the three months ended March 31, 2025, the Company did not grant any RSAs. As of March 31, 2025, there was an aggregate of $3.4 million of unrecognized expense related to RSAs issued which is expected to be recognized over a weighted average period of 1.6 years.

Beginning in 2025, the Company stopped issuing RSAs and began issuing RSUs to certain employees in lieu of RSAs. These employee RSUs generally vest in three equal annual installments, with the first installment occurring on March 14, 2026. In addition, the Company began granting RSUs in 2024 to certain non-employee directors, which vest on the first anniversary of the date of the grant. During the three months ended March 31, 2025, the Company granted approximately 232,500 RSUs to employees, with an approximated aggregate value of $4.0 million. As of March 31, 2025, there was an aggregate of $4.1 million of unrecognized expense related to RSUs issued to non-employee directors and employees which is expected to be recognized over a weighted average period of 2.6 years.

Certain non-employee directors grant may elect for a portion of their RSUs to settle in the form of restricted cash units (“RCUs”), which vest on the same schedule as the originally granted RSUs.

RCUs are cash-settled with the value of each vested RCU equal to the closing price per share of our Class A Common Stock on the vesting date. The Company determined that RCUs are in-substance liabilities accounted for as liability instruments in accordance with ASC 718, Compensation—Stock Compensation, due to this cash settlement feature. RCUs are remeasured based on the closing price per share of the Company’s Class A Common Stock at the end of each reporting period. As of March 31, 2025, the liability associated with unvested RCUs was $0.1 million, which is included in Accrued expenses in the Condensed Consolidated Balance Sheets.

The performance criteria applicable to performance stock units that have been granted by the Company are based on relative total shareholder return, which measures the Company’s total shareholder return as compared to the total shareholder return of a designated peer group, and absolute total shareholder return. Generally, the performance stock units are subject to a three-year performance period.

During the three months ended March 31, 2025, the Company granted approximately 136,000 target shares of market-based performance stock units, of which 68,000 were granted at a relative grant date fair value of approximately $22.46 per share and 68,000 were granted at an absolute grant date fair value of approximately $18.24 per share.

Shares granted during the three months ended March 31, 2025 are expected to vest (if at all) following the completion of the applicable performance period on December 31, 2027. As of March 31, 2025, there was an aggregate of $4.7 million of unrecognized compensation cost related to performance stock units which are expected to be recognized over a weighted average period of 1.7 years.

Effective March 3, 2025, the Company modified the absolute total shareholder return calculation for grants made to three grantees in 2023 and 2024 to include dividends in the calculation of absolute shareholder return. The total incremental compensation cost resulting from this modification was $0.1 million.

In March 2023, the Company announced a share repurchase program allowing the Company to purchase Class A Common Stock held by non-affiliates, not to exceed $35.0 million in aggregate value. On March 4, 2024, the Company announced that its Board of Directors approved an additional share repurchase program authorization of $50.0 million, bringing the total share repurchase program authorization to $85.0 million in aggregate value. Share repurchases may take place in any transaction form as allowable by the SEC. Approval of the program by the Board of Directors of the Company is specific for the next 36 months allowing the Company to utilize the expanded $50 million of approved capacity through March 4, 2027.

During the three months ended March 31, 2025, the Company did not repurchase any of the Company’s Class A Common Stock on the open market. As of March 31, 2025, an aggregate of 3,325,800 shares of Class A Common Stock were purchased for a total of $34.8 million, net of tax since the inception of the repurchase plan announced on March 7, 2023 and $50.2 million remained available under the share repurchase program. The Company has accrued stock repurchase excise tax of $0.1 million for the three months ended March 31, 2025.

In 2023, the Board of Directors approved the initiation of a quarterly dividend of $0.05 per share. The Company increased the quarterly dividend to $0.06 per share in 2025. The Company paid dividend distributions totaling $1.3 million for the three months ended March 31, 2025. The declaration of any future dividends is subject to the Board of Directors’ discretion and approval.

During the three months ended March 31, 2025, four customers accounted for approximately 29%, 11%, 13% and 11%, respectively, of the Company’s consolidated revenues. These customers contributed 70% of the revenue for high specification rigs, 28% for wireline services, and 66% for processing solutions and ancillary services. As of March 31, 2025, approximately 64% of the net accounts receivable balance was due from these four customers.

During the three months ended March 31, 2024, four customers accounted for approximately 12%, 11%, 10% and 10%, respectively, of the Company’s consolidated revenue. These customers contributed 62% of the revenue for high specification rigs, 9% for wireline services, and 29% for processing solutions and ancillary services. As of March 31, 2024, approximately 15% of the net accounts receivable balance, in aggregate, was due from this customer.

The Company is a corporation and is subject to U.S. federal income tax. The Company uses an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating the estimated annual effective tax rate, the Company considers forecasted annual pre-tax income and estimated permanent book versus tax differences. Adjustments to the effective tax rate and other income tax related estimates could occur during the year as information and assumptions change which could include, but are not limited to, changes to forecasted amounts, estimates of permanent book versus tax differences, and changes to tax laws and rates. The effective U.S. federal income tax rate applicable to the Company for the three months ended March 31, 2025 and 2024 was (30.6%) and 27.0%, respectively. The Company is subject to the Texas Margin Tax, which requires tax payments at a maximum statutory effective rate of 0.75% on the taxable margin of each taxable entity that does business in Texas.

Historically, utilization of a portion of the Company's net operating loss carryforwards has been subject to limitations of utilization under Section 382 of the Internal Revenue Code of 1986 (“Section 382”), as amended. The Company incurred an ownership change, triggering another Section 382 loss limitation, during the three months ended June 30, 2023.

As the Company continues to experience increasing profits and no longer has a trailing 3-year cumulative taxable loss, we currently believe that it is more likely than not to fully utilize all deferred tax assets including those associated with the net operating loss carry-forward. Accordingly, the Company released all valuation allowances previously recorded resulting in a discrete tax benefit for the period ended September 30, 2023.

Total income tax expense for the three months ended March 31, 2025 differed from amounts computed by applying the U.S. federal statutory tax rates to pre-tax income or loss primarily due to the beneficial impact of equity compensation which vested during the first quarter of 2025. Tax expense for the first quarter of 2024 was impacted by state income taxes as well as certain non-deductible expenses.

The Company is subject to the following material taxing jurisdictions: the United States and Texas. As of March 31, 2025, the Company has no current tax years under audit. The Company remains subject to examination for federal income taxes and state income taxes for tax years 2021 through 2024.

The Company has evaluated all tax positions for which the statute of limitations remains open and believes that the material positions taken would more likely than not be sustained upon examination. Therefore, as of March 31, 2025, the Company had not established any reserves for, nor recorded any unrecognized benefits related to, uncertain tax positions.

Earnings per share is based on the amount of earnings allocated to the shareholders and the weighted average number of shares outstanding during the period for each class of Common Stock. The numerator and denominator used to compute earnings per share were as follows (in millions, except share and per share data):

From time to time, the Company is involved in various legal matters arising in the normal course of business. The Company does not believe that the ultimate resolution of these currently pending matters will have a material adverse effect on its condensed consolidated financial position or results of operations. We maintain insurance policies with insurers in amounts and with coverage and deductibles that we, with the advice of our insurance advisers and brokers, believe are reasonable and prudent. We cannot, however, assure you that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal injury and property damage or that these levels of insurance will be available in the future at economical prices.

The Company’s operations are located in the United States and organized into three reportable segments: High Specification Rigs, Wireline Services and Processing Solutions and Ancillary Services. The balances included in Other reflect other general and administrative costs, which are not directly attributable to High Specification Rigs, Wireline Services or Processing Solutions and Ancillary Services. The reportable segments comprise the structure used by the Chief Operating Decision Maker (“CODM”) to make key operating decisions and assess performance during the years presented in the accompanying Consolidated Financial Statements. The Chief Executive Officer is regarded as the Company’s CODM. The primary profitability measurement used by the CODM to review segment operating results is Adjusted EBITDA. We define Adjusted EBITDA as net income or loss before net interest expense, income tax expense, depreciation and amortization, equity-based compensation, loss on debt retirement, gain or loss on disposal of property and equipment, acquisition related costs, severance and reorganization costs, significant and unusual legal fees and settlements, impairment of assets, and certain other non-cash and certain other items that we do not view as indicative of our ongoing performance. The CODM utilizes Adjusted EBITDA to allocate resources for each segment predominantly in the annual planning process and to monitor segment results compared to prior period, forecasted results, and the annual plan.

The reportable segments have been categorized based on services provided in each line of business. The tables below present the operating income (loss) measurement and Adjusted EBITDA, as the Company believes this is most consistent with the principals used in measuring the financial statements.

During the fourth quarter of 2022, the Company determined assets are routinely utilized across multiple segments and Management does not utilize the net property and equipment value as a metric to evaluate the profitability of the respective segments. Therefore, the net property and equipment values have been removed from the segment data presented below.

The following is a description of each operating segment:

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 complimentary services often utilized in conjunction with our High Specification Rigs and Wireline Services segments. These services primarily include equipment rentals, plug and abandonment, 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, debt retirements and other items similar in nature.

Certain segment information for the three months ended March 31, 2025 and 2024 is as follows (in millions):

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On April 29, 2025, the Board of Directors declared a quarterly cash dividend of $0.06 per share payable May 23, 2025 to common stockholders of record at the close of business on May 9, 2025. The declaration of any future dividends is subject to the Board of Directors’ discretion and approval.

The Company evaluated subsequent events and transactions that occurred after the balance sheet date through the date the financial statements are issued. Based upon this review, the Company did not identify any other subsequent events that would have required adjustment or disclosure in the financial statements.

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 complimentary services often utilized in conjunction with our High Specification Rigs and Wireline Services segments. These services primarily include equipment rentals, coil tubing, plug and abandonment, 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, debt retirements and other items similar in nature.

For additional financial information about our segments, please see “Item 1. Financial Information — Note 15 — Segment Reporting.”

Despite drilling and completion activity declines during 2024, the Company was able to maintain relatively consistent performance in most service lines and this trend has continued through the first quarter of 2025. Our Wireline segment continues to face weakness in demand as completions activity declines and competition increases as a result of these reduced activity levels. Typical seasonality and weather impacts from the first quarter are expected to abate as temperatures across the basins in which we operate increase and longer days result in a greater number of workable hours for our equipment and crews.

Consolidation occurring at the E&P operator level within the energy industry is expected to impact U.S. onshore activity levels although the full extent of this impact is not yet known. The Company has, thus far, benefited from this consolidation and, over the long-term, the Company expects favorable preference from these larger organizations where the well-established processes and systems of Ranger are more valued. Our work with larger operators also benefits our business because their long-term production plans are less likely to include shut-in plans for wells when compared to smaller swing operators when short-term supply shocks and market price declines occur. To date, we have not seen a significant change in work plans with our largest customers on U.S. land; however, crude pricing below $60 per barrel could trigger activity reductions across the U.S. upstream complex. Our business is buoyed by the production-oriented focus of our service lines, as the least expensive barrel of crude oil coming to market domestically is most often from a previously drilled well to which we serve as a primary service provider. Furthermore, as relates to natural gas, the EIA expects U.S. natural gas demand to increase on the back of a rise in exports, serving as a potential tailwind for our assets both in gas markets where we have comparatively little exposure today and as a catalyst for tightening of asset availability given the ability of assets to work across production basins.

The Company believes current geopolitical events will continue to have an impact on our industry, including the impact of the current administration’s tariff policy on broader macroeconomic growth and associated energy demand. We are also monitoring the supply side, as the potential for increased production from OPEC+ could have an impact on domestic production levels especially among smaller producers. Considering the rapidly evolving events and the interplay of supply and demand within oil and gas commodities sector, numerous unknown factors could materially impact our operations. These events have already, and are likely to continue, influencing commodity prices, causing volatility that could have a material effect on our earnings, cash flows, and financial condition.

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.

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 businesses nor reporting segments.

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.

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, loss on debt retirement, gain or loss on disposal of property and equipment, significant and unusual legal fees and settlements, impairment of assets, and certain 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.

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).

Revenue. Revenue for the three months ended March 31, 2025 decreased $1.7 million, or 1%, to $135.2 million from $136.9 million for the three months ended March 31, 2024. The change in revenue by segment was as follows:

High Specification Rigs. High Specification Rigs revenue for the three months ended March 31, 2025 increased $7.8 million, or 10%, to $87.5 million from $79.7 million for the three months ended March 31, 2024. The revenue increase is attributable to slightly improved pricing and the average revenue per rig hour increasing 3% to $756 for the three months ended March 31, 2025 from $718 for the three months ended March 31, 2024 due to the build out of complete rig packages with additional equipment, coupled by a corresponding increase in total rig hours to 115,700 hours for the three months ended March 31, 2025 from 111,000 hours reported for three months ended March 31, 2024.

Wireline Services. Wireline Services revenue for the three months ended March 31, 2025 decreased $15.6 million, or 48%, to $17.2 million from $32.8 million for the three months ended March 31, 2024. The decreased revenue was primarily attributable to a decrease in completion services revenue of $11.5 million where there was a 64% decrease in completed stage counts to 1,400 for the three months ended March 31, 2025 from 3,400 for the three months ended March 31, 2024. This decrease in completion services revenue and stage count is indicative of lower operational activity reflecting the Company’s decision to pursue only work with appropriate margins. Wireline production associated services revenues decreased year over year due to the more extreme weather conditions in 2025 driving activity levels lower while pump down revenue decreased year over year due to a reduction in operational activity as a result of weather impacts and additional competitive dynamics across basins.

Processing Solutions and Ancillary Services. Processing Solutions and Ancillary Services revenue for the three months ended March 31, 2025 increased $6.1 million, or 25%, to $30.5 million from $24.4 million for the three months ended March 31, 2024.

The increase in revenue is primarily attributable to increases in revenue within rentals, coil tubing, and plugging and abandonment by $3.4 million, $2.4 million, and $0.4 million, respectively.

Cost of services (exclusive of depreciation and amortization). Cost of services for the three months ended March 31, 2025 decreased $5.4 million, or 4%, to $115.4 million from $120.8 million for the three months ended March 31, 2024. As a percentage of revenue, cost of services was 85% and 88% for the three months ended March 31, 2025 and 2024, respectively. The change in cost of services by segment was as follows:

High Specification Rigs. High Specification Rigs cost of services for the three months ended March 31, 2025 increased $3.8 million, to $70.1 million from $66.3 million for the three months ended March 31, 2024. The increase was primarily attributable to an increase in variable expenses, notably employee-related labor costs, repair and maintenance costs, and travel costs of $2.0 million, $0.5 million and $0.5 million, respectively. As a percentage of High Specification Rigs revenue, cost of services was 80% for the three months ended March 31, 2025, a decrease from 83% for the three months ended March 31, 2024.

Wireline Services. Wireline Services cost of services for the three months ended March 31, 2025 decreased $12.3 million, or 38%, to $20.3 million from $32.6 million for the three months ended March 31, 2024. The decrease in wireline services cost of sales was primarily attributable to reductions in completion services costs of $10.8 million as the Company continued to reorganize this service line during the quarter to align with lower operating levels. As a percentage of Wireline Services revenue, cost of services increased from 99% for the three months ended March 31, 2024 to 118% for the three months ended March 31, 2025 primarily due to declining operating leverage from lower activity levels.

Processing Solutions and Ancillary Services. Processing Solutions and Ancillary Services cost of services for the three months ended March 31, 2025 increased $3.1 million, or 14%, to $25.0 million from $21.9 million for the three months ended March 31, 2024. The increase was primarily attributable to increased direct material costs and employee-related labor costs which accounted for $1.5 million and $0.9 million, respectively. As a percentage of Processing Solutions and Ancillary Services revenue, cost of services improved from 90% for the three months ended March 31, 2024 to 82% for the three months ended March 31, 2025 due to increased operational efficiencies and cost reductions.

General & Administrative. General and administrative expenses remained relatively flat; the three months ended March 31, 2025 increased $0.4 million, or 6%, to $7.1 million from $6.7 million for the three months ended March 31, 2024.

Depreciation and Amortization. Depreciation and amortization for the three months ended March 31, 2025 decreased $0.6 million, or 5%, to $10.6 million from $11.2 million for the three months ended March 31, 2024. The decrease was attributable to capital expenditures with longer useful lives added during the latter half of 2024 into 2025.

Interest Expense, net. Interest expense, net decreased from $0.8 million for the three months ended March 31, 2024 to $0.6 million for the three months ended March 31, 2025. The changes in interest expense were attributable to reduced borrowings on the Wells Fargo Revolving Credit Facility and decreased borrowing costs on finance leases.

Income Tax Expense or Benefit. Income tax benefit for the three months ended March 31, 2025 decreased $0.4 million, or 80%, resulting in an income tax benefit of $0.1 million compared to income tax benefit of $0.5 million for three months ended March 31, 2024. The lower tax rate for the period ended March 31, 2025 resulted from beneficial equity compensation which vested during the first quarter of 2025.

Net Income (loss). Net income for the three months ended March 31, 2025 increased $1.4 million, or 175%, to $0.6 million from a loss of $0.8 million for the three months ended March 31, 2024. The increase in net income was driven by continued increases in High Specification Rigs and Ancillary Services, partially offset by reduced operating income from activity declines in the Wireline segment.

Adjusted EBITDA is not a financial measure determined in accordance with U.S. GAAP. 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, loss on debt retirement, gain or loss on disposal of property and equipment, significant and unusual legal fees and settlements, impairment of assets, and certain other non-cash and certain other items that we do not view as indicative of our ongoing performance.

We believe Adjusted EBITDA is a useful performance measure because it allows for an effective evaluation of our operating performance when compared to our peers, without regard to our financing methods or capital structure. We exclude the items listed above from net income (loss) in arriving at Adjusted EBITDA because these amounts can vary substantially within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income (loss) determined in accordance with U.S. GAAP. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are reflected in Adjusted EBITDA. Our presentation of Adjusted EBITDA should not be construed as an indication that our results will be unaffected by the items excluded from Adjusted EBITDA. Our computations of Adjusted EBITDA may not be identical to other similarly titled measures of other companies. The following table presents reconciliations of net income (loss) to Adjusted EBITDA, our most directly comparable financial measure calculated and presented in accordance with U.S. GAAP.

The following is an analysis of our Adjusted EBITDA. See “Item 1. Financial Information—Note 15—Segment Reporting” and “—Results of Operations” for further details (in millions).