[10-Q] Granite Ridge Resources, Inc. Quarterly Earnings Report
Filing Impact
Filing Sentiment
Form Type
10-Q
Form 4 highlights: Journey Medical Corp. (DERM) reported that director Jayne Miranda Toledano received 20,000 restricted stock units (RSUs) on 05-Aug-2025 at $0 cost under the 2015 Stock Plan. The award lifts her total beneficial ownership to 108,618 common shares.
The RSUs vest in three tranches: 6,667 shares on 05-Aug-2028, 6,667 on 05-Aug-2029 and 6,666 on 05-Aug-2030. No sales, option exercises or other dispositions were disclosed.
- The grant is a non-cash equity incentive intended to align the director鈥檚 interests with long-term shareholder value.
- Any share dilution will be incremental and spread over the 2028-2030 period, contingent on continued service and vesting conditions.
Punti salienti del Modulo 4: Journey Medical Corp. (DERM) ha comunicato che la direttrice Jayne Miranda Toledano ha ricevuto 20.000 unit脿 azionarie vincolate (RSU) il 05 agosto 2025 a costo zero, ai sensi del Piano Azionario 2015. Questo premio porta la sua partecipazione totale a 108.618 azioni ordinarie.
Le RSU maturano in tre tranche: 6.667 azioni il 05 agosto 2028, 6.667 il 05 agosto 2029 e 6.666 il 05 agosto 2030. Non sono state riportate vendite, esercizi di opzioni o altre disposizioni.
- La concessione rappresenta un incentivo azionario non monetario volto ad allineare gli interessi della direttrice con il valore a lungo termine per gli azionisti.
- Eventuali diluizioni azionarie saranno incrementali e distribuite nel periodo 2028-2030, soggette alla continuazione del servizio e alle condizioni di maturazione.
Aspectos destacados del Formulario 4: Journey Medical Corp. (DERM) inform贸 que la directora Jayne Miranda Toledano recibi贸 20,000 unidades restringidas de acciones (RSU) el 5 de agosto de 2025 sin costo, bajo el Plan de Acciones de 2015. Este otorgamiento eleva su propiedad total a 108,618 acciones comunes.
Las RSU se liberan en tres partes: 6,667 acciones el 5 de agosto de 2028, 6,667 el 5 de agosto de 2029 y 6,666 el 5 de agosto de 2030. No se reportaron ventas, ejercicios de opciones u otras disposiciones.
- La concesi贸n es un incentivo de capital no monetario dise帽ado para alinear los intereses de la directora con el valor a largo plazo para los accionistas.
- Cualquier diluci贸n de acciones ser谩 incremental y distribuida entre 2028 y 2030, condicionada a la continuidad del servicio y al cumplimiento de las condiciones de liberaci贸n.
Form 4 欤检殧 雮挫毄: Journey Medical Corp. (DERM)鞚� 鞚挫偓鞚� Jayne Miranda Toledano臧� 2015雲� 欤检嫕 瓿勴殟鞐� 霐半澕 2025雲� 8鞗� 5鞚检棎 牍勳毄 鞐嗢澊 20,000臧滌潣 鞝滍暅 欤检嫕 雼渼(RSU)毳� 氚涭晿雼り碃 氤搓碃頄堨姷雼堧嫟. 鞚� 靾橃棳搿� 攴鸽厐鞚� 齑� 鞁れ 氤挫湢 欤检嫕 靾橂姅 108,618欤�臧� 霅橃棃鞀惦媹雼�.
RSU電� 靹� 彀鞐� 瓯胳硱 氩犾姢韺呺惄雼堧嫟: 2028雲� 8鞗� 5鞚检棎 6,667欤�, 2029雲� 8鞗� 5鞚检棎 6,667欤�, 2030雲� 8鞗� 5鞚检棎 6,666欤检瀰雼堧嫟. 韺愲Г, 鞓奠厴 頄夓偓 霕愲姅 旮绊儉 觳橂秳鞚� 氤搓碃霅橃 鞎婌晿鞀惦媹雼�.
- 鞚� 靾橃棳電� 鞚挫偓鞚� 鞚挫澋鞚� 鞛リ赴 欤检＜ 臧�旃橃檧 鞚检箻鞁滍偆旮� 鞙勴暅 順勱笀鞚� 鞎勲媽 欤检嫕 鞚胳劶韹半笇鞛呺媹雼�.
- 欤检嫕 頋劃鞚� 鞝愳鞝侅澊氅� 2028雲勲秬韯� 2030雲勱箤歆� 攵勳偘霅橃柎 氚滌儩頃橂┌, 瓿勳啀 攴茧 氚� 氩犾姢韺� 臁瓣贝鞐� 霐半澕 雼澕歆戨媹雼�.
Points cl茅s du Formulaire 4 : Journey Medical Corp. (DERM) a annonc茅 que la directrice Jayne Miranda Toledano a re莽u 20 000 unit茅s d'actions restreintes (RSU) le 5 ao没t 2025 sans co没t, dans le cadre du Plan d'Actions 2015. Cette attribution porte sa d茅tention totale 脿 108 618 actions ordinaires.
Les RSU sont acquises en trois tranches : 6 667 actions le 5 ao没t 2028, 6 667 le 5 ao没t 2029 et 6 666 le 5 ao没t 2030. Aucune vente, exercice d鈥檕ption ou autre disposition n鈥檃 茅t茅 signal茅e.
- L鈥檃ttribution constitue une incitation en actions non mon茅taire visant 脿 aligner les int茅r锚ts de la directrice avec la cr茅ation de valeur 脿 long terme pour les actionnaires.
- Toute dilution des actions sera progressive et r茅partie sur la p茅riode 2028-2030, sous r茅serve de la poursuite du service et des conditions d鈥檃cquisition.
Formular 4 Highlights: Journey Medical Corp. (DERM) meldete, dass Direktorin Jayne Miranda Toledano am 05. August 2025 20.000 eingeschr盲nkte Aktieneinheiten (RSUs) ohne Kosten im Rahmen des Aktienplans von 2015 erhalten hat. Die Zuteilung erh枚ht ihren Gesamtbesitz auf 108.618 Stammaktien.
Die RSUs werden in drei Tranchen freigegeben: 6.667 Aktien am 05. August 2028, 6.667 am 05. August 2029 und 6.666 am 05. August 2030. Es wurden keine Verk盲ufe, Aus眉bung von Optionen oder sonstige Ver盲u脽erungen gemeldet.
- Die Zuteilung ist eine nicht monet盲re Aktienanreizma脽nahme, die darauf abzielt, die Interessen der Direktorin mit dem langfristigen Wert f眉r die Aktion盲re in Einklang zu bringen.
- Eine eventuelle Aktienverw盲sserung erfolgt schrittweise und verteilt sich 眉ber den Zeitraum 2028 bis 2030, abh盲ngig von fortgesetzter Dienstzeit und Vesting-Bedingungen.
Positive
- None.
Negative
- None.
Insights
TL;DR Routine RSU grant; boosts insider alignment, limited immediate market impact.
The filing shows no insider selling鈥攐nly a 20,000-share equity award that increases the director鈥檚 stake to 108,618 shares. Because the RSUs vest over five years, the cash鈥恌low effect is minimal and dilution is deferred. While positive for governance, the grant is not large enough to alter valuation or near-term float; therefore I view the event as neutral for the stock.
TL;DR Long-dated RSUs enhance board alignment鈥攎arginally positive signal.
Granting multi-year RSUs rather than cash strengthens retention and links compensation to future performance. The absence of sales reduces concerns about insider sentiment. The staggered vesting through 2030 promotes long-term oversight, a modest governance positive, but the small size limits strategic impact.
Punti salienti del Modulo 4: Journey Medical Corp. (DERM) ha comunicato che la direttrice Jayne Miranda Toledano ha ricevuto 20.000 unit脿 azionarie vincolate (RSU) il 05 agosto 2025 a costo zero, ai sensi del Piano Azionario 2015. Questo premio porta la sua partecipazione totale a 108.618 azioni ordinarie.
Le RSU maturano in tre tranche: 6.667 azioni il 05 agosto 2028, 6.667 il 05 agosto 2029 e 6.666 il 05 agosto 2030. Non sono state riportate vendite, esercizi di opzioni o altre disposizioni.
- La concessione rappresenta un incentivo azionario non monetario volto ad allineare gli interessi della direttrice con il valore a lungo termine per gli azionisti.
- Eventuali diluizioni azionarie saranno incrementali e distribuite nel periodo 2028-2030, soggette alla continuazione del servizio e alle condizioni di maturazione.
Aspectos destacados del Formulario 4: Journey Medical Corp. (DERM) inform贸 que la directora Jayne Miranda Toledano recibi贸 20,000 unidades restringidas de acciones (RSU) el 5 de agosto de 2025 sin costo, bajo el Plan de Acciones de 2015. Este otorgamiento eleva su propiedad total a 108,618 acciones comunes.
Las RSU se liberan en tres partes: 6,667 acciones el 5 de agosto de 2028, 6,667 el 5 de agosto de 2029 y 6,666 el 5 de agosto de 2030. No se reportaron ventas, ejercicios de opciones u otras disposiciones.
- La concesi贸n es un incentivo de capital no monetario dise帽ado para alinear los intereses de la directora con el valor a largo plazo para los accionistas.
- Cualquier diluci贸n de acciones ser谩 incremental y distribuida entre 2028 y 2030, condicionada a la continuidad del servicio y al cumplimiento de las condiciones de liberaci贸n.
Form 4 欤检殧 雮挫毄: Journey Medical Corp. (DERM)鞚� 鞚挫偓鞚� Jayne Miranda Toledano臧� 2015雲� 欤检嫕 瓿勴殟鞐� 霐半澕 2025雲� 8鞗� 5鞚检棎 牍勳毄 鞐嗢澊 20,000臧滌潣 鞝滍暅 欤检嫕 雼渼(RSU)毳� 氚涭晿雼り碃 氤搓碃頄堨姷雼堧嫟. 鞚� 靾橃棳搿� 攴鸽厐鞚� 齑� 鞁れ 氤挫湢 欤检嫕 靾橂姅 108,618欤�臧� 霅橃棃鞀惦媹雼�.
RSU電� 靹� 彀鞐� 瓯胳硱 氩犾姢韺呺惄雼堧嫟: 2028雲� 8鞗� 5鞚检棎 6,667欤�, 2029雲� 8鞗� 5鞚检棎 6,667欤�, 2030雲� 8鞗� 5鞚检棎 6,666欤检瀰雼堧嫟. 韺愲Г, 鞓奠厴 頄夓偓 霕愲姅 旮绊儉 觳橂秳鞚� 氤搓碃霅橃 鞎婌晿鞀惦媹雼�.
- 鞚� 靾橃棳電� 鞚挫偓鞚� 鞚挫澋鞚� 鞛リ赴 欤检＜ 臧�旃橃檧 鞚检箻鞁滍偆旮� 鞙勴暅 順勱笀鞚� 鞎勲媽 欤检嫕 鞚胳劶韹半笇鞛呺媹雼�.
- 欤检嫕 頋劃鞚� 鞝愳鞝侅澊氅� 2028雲勲秬韯� 2030雲勱箤歆� 攵勳偘霅橃柎 氚滌儩頃橂┌, 瓿勳啀 攴茧 氚� 氩犾姢韺� 臁瓣贝鞐� 霐半澕 雼澕歆戨媹雼�.
Points cl茅s du Formulaire 4 : Journey Medical Corp. (DERM) a annonc茅 que la directrice Jayne Miranda Toledano a re莽u 20 000 unit茅s d'actions restreintes (RSU) le 5 ao没t 2025 sans co没t, dans le cadre du Plan d'Actions 2015. Cette attribution porte sa d茅tention totale 脿 108 618 actions ordinaires.
Les RSU sont acquises en trois tranches : 6 667 actions le 5 ao没t 2028, 6 667 le 5 ao没t 2029 et 6 666 le 5 ao没t 2030. Aucune vente, exercice d鈥檕ption ou autre disposition n鈥檃 茅t茅 signal茅e.
- L鈥檃ttribution constitue une incitation en actions non mon茅taire visant 脿 aligner les int茅r锚ts de la directrice avec la cr茅ation de valeur 脿 long terme pour les actionnaires.
- Toute dilution des actions sera progressive et r茅partie sur la p茅riode 2028-2030, sous r茅serve de la poursuite du service et des conditions d鈥檃cquisition.
Formular 4 Highlights: Journey Medical Corp. (DERM) meldete, dass Direktorin Jayne Miranda Toledano am 05. August 2025 20.000 eingeschr盲nkte Aktieneinheiten (RSUs) ohne Kosten im Rahmen des Aktienplans von 2015 erhalten hat. Die Zuteilung erh枚ht ihren Gesamtbesitz auf 108.618 Stammaktien.
Die RSUs werden in drei Tranchen freigegeben: 6.667 Aktien am 05. August 2028, 6.667 am 05. August 2029 und 6.666 am 05. August 2030. Es wurden keine Verk盲ufe, Aus眉bung von Optionen oder sonstige Ver盲u脽erungen gemeldet.
- Die Zuteilung ist eine nicht monet盲re Aktienanreizma脽nahme, die darauf abzielt, die Interessen der Direktorin mit dem langfristigen Wert f眉r die Aktion盲re in Einklang zu bringen.
- Eine eventuelle Aktienverw盲sserung erfolgt schrittweise und verteilt sich 眉ber den Zeitraum 2028 bis 2030, abh盲ngig von fortgesetzter Dienstzeit und Vesting-Bedingungen.
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the quarterly period ended June 30, 2025
OR
| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the transition period from ______ to _______
Commission File Number: 001-41537
___________________________________
( Exact Name of Registrant as Specified in Its Charter )
___________________________________
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification Number) | |||||||
| (Address of principal executive offices) | (Zip Code) | |||||||
(214 ) 396-2850
(Registrant’s telephone number, including area code)
(Former name, former address and former fiscal year, if changed since last report)
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol | Name of each exchange on which registered | ||||||||||||
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 x No o
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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes x No o
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.
| Large accelerated filer | o | x | Non-accelerated filer | o | Smaller reporting company | |||||||||||||||||||||
| Emerging growth company | ||||||||||||||||||||||||||
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. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No x
As of August 4, 2025, there were 131,247,812 shares of our common stock, par value $0.0001, outstanding.
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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
We are including the following discussion to inform our existing and potential security holders generally of some of the risks and uncertainties that can affect our company and to take advantage of the “safe harbor” protection for forward-looking statements that applicable federal securities law afford.
From time to time, our management or persons acting on our behalf may make "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 Securities Exchange Act of 1934, as amended (the "Exchange Act"), to inform existing and potential security holders about our company. All statements other than statements of historical facts included in this Quarterly Report on Form 10-Q (this "Report"), including, without limitation, statements regarding our financial position, operating and financial performance, business strategy, plans and objectives of management for future operations, industry conditions, indebtedness covenant compliance, capital expenditures, production, cash flow, borrowing base under our Credit Agreement (as defined below), our intention or ability to pay or increase dividends on our capital stock, and impairment are forward-looking statements. When used in this Report, forward-looking statements are generally accompanied by terms or phrases such as “estimate,” “project,” “predict,” “believe,” “expect,” “continue,” “anticipate,” “target,” “could,” “plan,” “intend,” “seek,” “goal,” “will,” “should,” “may” or other words and similar expressions that convey the uncertainty of future events or outcomes. Items contemplating or making assumptions about actual or potential future production, sales, market size, collaborations, cash flows, and trends or operating results also constitute such forward-looking statements.
Forward-looking statements involve inherent risks and uncertainties, and important factors (many of which are beyond our company’s control) could cause actual results to differ materially from those set forth in the forward-looking statements, including the following:
•changes in current or future commodity prices and interest rates;
•supply chain disruptions;
•infrastructure constraints and related factors affecting our properties;
•our ability to acquire additional development opportunities and potential or pending acquisition transactions, as well as the effects of such acquisitions on our company’s cash position and levels of indebtedness;
•changes in our reserves estimates or the value thereof;
•operational risks including, but not limited to, the pace of drilling and completions activity on our properties;
•changes in the markets in which Granite Ridge competes;
•geopolitical risk and changes in applicable laws, legislation, or regulations, including those relating to environmental matters;
•cyber-related risks;
•the fact that reserve estimates depend on many assumptions that may turn out to be inaccurate and that any material inaccuracies in reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves;
•the outcome of any known and unknown litigation and regulatory proceedings;
•limited liquidity and trading of Granite Ridge’s securities;
•acts of war, terrorism or uncertainty regarding the effects and duration of global hostilities, including the Israel-Hamas conflict, the Russia-Ukraine war, continued instability in the Middle East, and any associated armed conflicts or related sanctions which may disrupt commodity prices and create instability in the financial markets;
•market conditions and global, regulatory, technical, and economic factors beyond Granite Ridge’s control, including the potential adverse effects of world health events affecting capital markets, general economic
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conditions, global supply chains, uncertainties with respect to trade policies (including the imposition of tariffs) and Granite Ridge’s business and operations;
•increasing regulatory and investor emphasis on, and attention to, environmental, social, and governance matters;
•our ability to establish and maintain effective internal control over financial reporting; and
•other factors discussed in our Annual Report on Form 10-K for the year ended December 31, 2024 (the "2024 Form 10-K") under “Risk Factors,” as updated by any subsequent Quarterly Reports on Form 10-Q, including this Report, which we file with the United States Securities and Exchange Commission (“SEC”).
We have based any forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. If one or more of these risks or uncertainties materialize, or if the underlying assumptions prove incorrect, our actual results may vary materially from those expected or projected.
Reserve engineering is a process of estimating underground accumulations of natural gas and oil that cannot be measured in an exact manner. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data, and the price and cost assumptions made by reservoir engineers. In addition, the results of drilling, testing and production activities, or changes in commodity prices, may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of natural gas and oil that are ultimately recovered.
Readers are urged not to place undue reliance on these forward-looking statements, which speak only as of the date of this Report. We assume no obligation to update any forward-looking statements in order to reflect any event or circumstance that may arise after the date of this Report, other than as may be required by applicable law or regulation. Readers are urged to carefully review and consider the various disclosures made by us in our reports filed with the SEC which attempt to advise interested parties of the risks and factors that may affect our business, financial condition, results of operations and cash flows. If one or more of these risks or uncertainties materialize, or if the underlying assumptions prove incorrect, our actual results may vary materially from those expected or projected.
3
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TABLE OF CONTENTS
| PAGE | ||||||||
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS | 2 | |||||||
PART I – FINANCIAL INFORMATION | 5 | |||||||
Item 1. | Financial Statements | 5 | ||||||
Condensed Consolidated Balance Sheets | 5 | |||||||
Condensed Consolidated Statements of Operations | 6 | |||||||
Condensed Consolidated Statements of Changes in Equity | 7 | |||||||
Condensed Consolidated Statements of Cash Flows | 8 | |||||||
Notes to Condensed Consolidated Financial Statements | 9 | |||||||
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 23 | ||||||
Item 3. | Quantitative and Qualitative Disclosures about Market Risk | 33 | ||||||
Item 4. | Controls and Procedures | 34 | ||||||
PART II – OTHER INFORMATION | 34 | |||||||
Item 1. | Legal Proceedings | 34 | ||||||
Item 1A. | Risk Factors | 34 | ||||||
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 35 | ||||||
Item 3. | Defaults Upon Senior Securities | 35 | ||||||
Item 4. | Mine Safety Disclosures | 35 | ||||||
Item 5. | Other Information | 35 | ||||||
Item 6. | Exhibits | 35 | ||||||
Signatures | 36 | |||||||
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PART I – FINANCIAL INFORMATION
Item 1. Financial Statements
GRANITE RIDGE RESOURCES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
Unaudited
| (in thousands, except par value and share data) | June 30, 2025 | December 31, 2024 | |||||||||
| ASSETS | |||||||||||
| Current assets: | |||||||||||
| Cash | $ | $ | |||||||||
| Revenue receivable | |||||||||||
| Advances to operators | |||||||||||
| Prepaid and other current assets | |||||||||||
| Derivative assets - commodity derivatives | |||||||||||
| Equity investments | |||||||||||
| Total current assets | |||||||||||
| Property and equipment: | |||||||||||
| Oil and gas properties, successful efforts method | |||||||||||
| Accumulated depletion | ( | ( | |||||||||
| Total property and equipment, net | |||||||||||
| Long-term assets: | |||||||||||
| Derivative assets - commodity derivatives | |||||||||||
| Other long-term assets | |||||||||||
| Total long-term assets | |||||||||||
| Total assets | $ | $ | |||||||||
| LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||||||
| Current liabilities: | |||||||||||
| Accounts payable and accrued liabilities | $ | $ | |||||||||
| Derivative liabilities - commodity derivatives | |||||||||||
| Other liabilities | |||||||||||
| Total current liabilities | |||||||||||
| Long-term liabilities: | |||||||||||
| Long-term debt | |||||||||||
| Derivative liabilities - commodity derivatives | |||||||||||
| Asset retirement obligations | |||||||||||
| Deferred tax liability | |||||||||||
| Total long-term liabilities | |||||||||||
| Total liabilities | |||||||||||
| Stockholders' Equity: | |||||||||||
Common stock, $ | |||||||||||
| Additional paid-in capital | |||||||||||
| Retained earnings | |||||||||||
Treasury stock, at cost, | ( | ( | |||||||||
| Total stockholders' equity | |||||||||||
| Total liabilities and stockholders' equity | $ | $ | |||||||||
The accompanying notes are an integral part to these condensed consolidated financial statements.
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GRANITE RIDGE RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
Unaudited
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| (in thousands, except per share data) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Revenues: | |||||||||||||||||||||||
| Oil and natural gas sales | $ | $ | $ | $ | |||||||||||||||||||
| Operating costs and expenses: | |||||||||||||||||||||||
| Lease operating expenses | |||||||||||||||||||||||
| Production and ad valorem taxes | |||||||||||||||||||||||
| Depletion and accretion expense | |||||||||||||||||||||||
| Impairments of unproved properties | |||||||||||||||||||||||
| General and administrative | |||||||||||||||||||||||
| Other, net | ( | ||||||||||||||||||||||
| Total operating costs and expenses | |||||||||||||||||||||||
| Net operating income | |||||||||||||||||||||||
| Other income (expense): | |||||||||||||||||||||||
| Gain (loss) on derivatives - commodity derivatives | ( | ( | |||||||||||||||||||||
| Interest expense, net | ( | ( | ( | ( | |||||||||||||||||||
| Loss on equity investments | ( | ( | ( | ( | |||||||||||||||||||
| Other income (loss) | ( | ( | |||||||||||||||||||||
| Total other income (expense) | ( | ( | ( | ||||||||||||||||||||
| Income before income taxes | |||||||||||||||||||||||
| Income tax expense | |||||||||||||||||||||||
| Net income | $ | $ | $ | $ | |||||||||||||||||||
| Net income per share: | |||||||||||||||||||||||
| Basic | $ | $ | $ | $ | |||||||||||||||||||
| Diluted | $ | $ | $ | $ | |||||||||||||||||||
| Weighted-average number of shares outstanding: | |||||||||||||||||||||||
| Basic | |||||||||||||||||||||||
| Diluted | |||||||||||||||||||||||
The accompanying notes are an integral part to these condensed consolidated financial statements.
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GRANITE RIDGE RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
Unaudited
| Three and Six Months Ended June 30, 2025 | |||||||||||||||||||||||||||||||||||||||||
| Common Stock Issued | Additional Paid-in Capital | Retained Earnings | Treasury Stock | Total Stockholders' Equity | |||||||||||||||||||||||||||||||||||||
| (in thousands) | Shares | Amount | Shares | Amount | |||||||||||||||||||||||||||||||||||||
| As of January 1, 2025 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
| Grants of restricted stock | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||
| Forfeitures of restricted stock | ( | — | — | — | — | — | — | ||||||||||||||||||||||||||||||||||
| Stock-based compensation | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| Purchase of treasury stock | — | — | — | — | ( | ( | ( | ||||||||||||||||||||||||||||||||||
Common stock dividend declared ($ | — | — | — | ( | — | — | ( | ||||||||||||||||||||||||||||||||||
| Net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| As of March 31, 2025 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
| Grants of restricted stock | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||
| Forfeitures of restricted stock | ( | — | — | — | — | — | — | ||||||||||||||||||||||||||||||||||
| Stock-based compensation | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
Common stock dividend declared ($ | — | — | — | ( | — | — | ( | ||||||||||||||||||||||||||||||||||
| Net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| As of June 30, 2025 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
| Three and Six Months Ended June 30, 2024 | |||||||||||||||||||||||||||||||||||||||||
| Common Stock Issued | Additional Paid-in Capital | Retained Earnings | Treasury Stock | Total Stockholders' Equity | |||||||||||||||||||||||||||||||||||||
| (in thousands) | Shares | Amount | Shares | Amount | |||||||||||||||||||||||||||||||||||||
| As of January 1, 2024 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
| Grants of restricted stock | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||
| Stock-based compensation | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| Purchase of treasury stock | — | — | — | — | ( | ( | ( | ||||||||||||||||||||||||||||||||||
Common stock dividend declared ($ | — | — | — | ( | — | — | ( | ||||||||||||||||||||||||||||||||||
| Net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| As of March 31, 2024 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
| Stock-based compensation | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
Common stock dividend declared ($ | — | — | — | ( | — | — | ( | ||||||||||||||||||||||||||||||||||
| Net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||
| As of June 30, 2024 | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part to these condensed consolidated financial statements.
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GRANITE RIDGE RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Unaudited
| Six Months Ended June 30, | |||||||||||
| (in thousands) | 2025 | 2024 | |||||||||
| Operating activities: | |||||||||||
| Net income | $ | $ | |||||||||
| Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
| Depletion and accretion expense | |||||||||||
| Impairments of unproved properties | |||||||||||
| Unrealized (gain) loss on derivatives - commodity derivatives | ( | ||||||||||
| Stock-based compensation | |||||||||||
| Amortization of deferred financing costs | |||||||||||
| Loss on equity investments | |||||||||||
| Deferred income taxes | |||||||||||
| Other | ( | ( | |||||||||
| Increase (decrease) in cash attributable to changes in operating assets and liabilities: | |||||||||||
| Revenue receivable | ( | ||||||||||
| Other receivable | |||||||||||
| Accounts payable and accrued liabilities | ( | ||||||||||
| Prepaid and other current assets | ( | ||||||||||
| Other liabilities | |||||||||||
| Net cash provided by operating activities | |||||||||||
| Investing activities: | |||||||||||
| Capital expenditures for oil and natural gas properties | ( | ( | |||||||||
| Acquisition of oil and natural gas properties | ( | ( | |||||||||
| Proceeds from the sale of equity investments | |||||||||||
| Proceeds from sale of oil and natural gas properties | |||||||||||
| Refund of advances to operators | |||||||||||
| Net cash used in investing activities | ( | ( | |||||||||
| Financing activities: | |||||||||||
| Proceeds from borrowing on credit facilities | |||||||||||
| Repayments of borrowing on credit facilities | ( | ||||||||||
| Deferred financing costs | ( | ( | |||||||||
| Purchase of treasury shares | ( | ( | |||||||||
| Payment of dividends | ( | ( | |||||||||
| Net cash provided by financing activities | |||||||||||
| Net change in cash and restricted cash | ( | ||||||||||
| Cash and restricted cash at beginning of period | |||||||||||
| Cash and restricted cash at end of period | $ | $ | |||||||||
| Supplemental disclosure of non-cash investing activities: | |||||||||||
| Change in accrued capital expenditures included in accounts payable and accrued liabilities | $ | ( | $ | ||||||||
| Advances to operators applied to development of oil and natural gas properties | $ | $ | |||||||||
| Cash and restricted cash: | |||||||||||
| Cash | $ | $ | |||||||||
| Restricted cash included in other long-term assets | |||||||||||
| Cash and restricted cash | $ | $ | |||||||||
The accompanying notes are an integral part to these condensed consolidated financial statements.T
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
1. Nature of Operations
Granite Ridge Resources, Inc. (together with its consolidated subsidiaries, “Granite Ridge” or the “Company”), a Delaware corporation, is a scaled energy company which aims to provide shareholders with exposure similar to energy private equity through operated partnerships and traditional non-operated assets in multiple basins throughout North America.
2. Summary of Significant Accounting Policies
A complete discussion of the Company’s significant accounting policies is included in the 2024 Form 10-K.
Interim Financial Statements, Basis of Presentation, Consolidation, and Significant Estimates
The condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“U.S. GAAP”). The accompanying condensed consolidated financial statements include the accounts of the Company and all of its wholly owned subsidiaries. All intercompany balances and transactions have been eliminated in consolidation.
The accompanying condensed consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the condensed consolidated balance sheet at December 31, 2024 is derived from audited consolidated financial statements. In the opinion of management, the accompanying condensed consolidated financial statements reflect all adjustments necessary to present fairly the Company’s condensed consolidated financial statements. All such adjustments are of a normal, recurring nature.
The preparation of the 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 at the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates of reserves are used to determine depletion and to conduct impairment analysis. Estimating reserves is inherently uncertain, including the projection of future rates of production and the timing of development expenditures. Additional significant estimates include, but are not limited to, fair value of derivative financial instruments, fair value of equity investments, fair value of business combinations, asset retirement obligations, revenue receivable and income taxes. Actual results could differ from those estimates. The results for interim periods are not necessarily indicative of annual results.
Certain reclassifications have been made to prior period amounts to conform to the current period presentation.
Segment Reporting
The Company operates in one
Oil and Natural Gas Properties
The Company uses the successful efforts method of accounting for oil and natural gas producing activities, as further defined under Accounting Standards Codification ("ASC") 932, Extractive Activities - Oil and Gas (“ASC 932”). Costs to
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
acquire mineral interests in oil and gas properties, to drill and equip exploratory leases that find proved reserves, and to drill and equip development leases and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determinations of whether the wells have proved reserves. If the Company determines that the wells do not have proved reserves, the costs are charged to expense.
Capitalized leasehold costs relating to proved properties are depleted using the unit-of-production method based on proved reserves. The depletion of capitalized drilling and development costs and integrated assets is based on the unit-of-production method using proved developed reserves. The Company recognized depletion expense of $53.2 million and $41.4 million for the three months ended June 30, 2025 and 2024, respectively, and $101.4 million and $82.2 million for the six months ended June 30, 2025 and 2024, respectively.
The Company reviews its long-lived assets to be held and used, including proved oil and natural gas properties, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable; for instance, when there are declines in commodity prices or well performance. An impairment loss is indicated if the sum of the expected undiscounted future net cash flows is less than the carrying amount of the assets. For each property determined to be impaired, an impairment loss equal to the difference between the carrying value of the properties and the estimated fair market value is recognized at that time. The fair value of impaired assets is determined using the market or income valuation approach. The income approach is calculated using a discounted cash flow model. Discounted future cash flows use a discount rate similar to that used by market participants, or comparable market value if available. Estimating future cash flows involves the use of judgments, including estimation of the proved and risk-adjusted unproved oil and natural gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. No
Equity Investments
In December 2023, the Company completed the sale of certain of its Permian Basin assets to Vital Energy, Inc. ("Vital Energy") for consideration of 561,752 shares of Vital Energy's common stock and 541,155 shares of Vital Energy's 2.0 2.0 342,636 shares of Vital Energy’s common stock and realized a loss on sale of $10.5 million, which is included in loss on equity investments within the Company’s condensed consolidated statements of operations for the three and six months ended June 30, 2025. No 685,271 shares of Vital Energy’s common stock.
The Company follows the guidance in ASC 321, Investments - Equity Securities ("ASC 321") for its investment in the common and preferred stock of Vital Energy. ASC 321 requires equity investments with readily determinable fair values to be measured at fair value, with unrealized holding gains and losses recorded as a gain or loss in the condensed consolidated statements of operations. For the preferred stock that did not have a readily determinable fair value, the Company did not elect the measurement alternative in ASC 321 and instead accounted for the preferred stock at fair value with unrealized gains and losses recorded through net income for the periods until the preferred stock was converted into common stock. The Company recognized an unrealized gain of $4.7 million and unrealized loss of $5.2 million for the three and six months ended June 30, 2025, respectively, included in loss on equity investments within the Company’s condensed consolidated statements of operations that accounts for the change in fair value of the common stock. For the three and six months ended June 30, 2024, the Company recognized an unrealized loss of $8.8 million and $1.0 million, respectively, that reflects the change in fair value of the common and preferred stock.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
Revenue Recognition
The Company’s revenues are primarily derived from its interests in the sale of oil and natural gas production. The Company recognizes revenue from its interests in the sales of oil and natural gas in the period that its performance obligations are satisfied.
Performance obligations are satisfied when the customer obtains control of the product, when the Company has no further obligations to perform related to the sale, when the transaction price has been determined, and when collectability is probable.
The Company receives payment from the sale of oil and natural gas production from one to three months after delivery. The transaction price is variable as it is based on market prices for oil and natural gas, less revenue deductions such as gathering, transportation, and compression costs. Management has determined that the variable revenue constraint is overcome at the date control passes to the customer since the variable consideration to be received can be reasonably estimated based on daily market prices and historical transportation charges. Revenue is presented net of these costs within the condensed consolidated statements of operations. At the end of each month when the performance obligation is satisfied, the variable consideration can be reasonably estimated and amounts due from customers are accrued in revenue receivable in the condensed consolidated balance sheets. Variances between the Company’s estimated revenue and actual payments are recorded in the month the payment is received; however, differences have been and are insignificant.
The Company does not disclose the value of unsatisfied performance obligations under its contracts with customers as it applies the practical expedient in accordance with ASC 606. The expedient, as described in ASC 606-10-50-14(a), applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.
Take in Kind Oil and Natural Gas Revenues
Under certain arrangements, the Company has the right to take a volume of unprocessed gas in kind at the operator's wellhead, representing its proportionate share of its natural gas production, in lieu of receiving a net payment from the operator. The Company currently takes certain natural gas volumes in kind in lieu of monetary settlement. When the Company elects to take volumes in kind, it pays third parties to transport the natural gas it took in kind to downstream delivery points, where it then sells to customers at prices applicable to those downstream markets. In such situations, revenues are recognized during the month in which control transfers to the customer at the delivery point and it is probable the Company will collect the consideration it is entitled to receive. Sales proceeds are generally received by the Company within one month after the month in which a sale has occurred. In these scenarios, gathering and processing costs and transportation expenses the Company incurs to transport the volumes to downstream customers are recorded in lease operating expenses in the condensed consolidated statements of operations.
Disaggregated Oil and Natural Gas Revenues
The Company’s disaggregated revenue has two primary sources: oil sales and natural gas sales. Substantially all of the Company’s oil and natural gas sales come from six geographic areas in the United States: the Eagle Ford Basin (Texas), the Permian Basin (Texas/New Mexico), the Haynesville Basin (Texas/Louisiana), the Denver-Julesburg “DJ” Basin (Colorado), the Bakken Basin (Montana/North Dakota), and the Appalachian Basin (Ohio). The following tables present
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
the disaggregation of the Company’s oil and natural gas revenues by basin for the three and six months ended June 30, 2025 and 2024.
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Oil | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
| Permian | $ | $ | $ | $ | |||||||||||||||||||
| Eagle Ford | |||||||||||||||||||||||
| Bakken | |||||||||||||||||||||||
| Haynesville | |||||||||||||||||||||||
| DJ | |||||||||||||||||||||||
| Appalachian | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
Recently Issued and Applicable Accounting Pronouncements (Issued and Not Yet Adopted)
In December 2023, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures ("ASU 2023-09"), which requires disaggregated information about a reporting entity’s effective tax rate reconciliation as well as information on income taxes paid. The standard is intended to benefit investors by providing more detailed income tax disclosures that would be useful in making capital allocation decisions. ASU 2023-09 was effective for annual periods beginning after December 15, 2024, with early adoption is permitted. The Company is currently assessing the effect that ASU 2023-09 will have on its disclosures.
3. Derivative Financial Instruments
The Company uses derivative financial instruments in connection with its oil and natural gas operations to provide an economic hedge of the Company’s exposure to commodity price risk associated with anticipated future oil and natural gas production. The Company does not hold or issue derivative financial instruments for speculative trading purposes.
The Company does not designate its derivative instruments to qualify for hedge accounting. Accordingly, the Company reflects changes in the fair value of its derivative instruments in its condensed consolidated statements of operations as they occur.
Collar Option Contracts and Swaps
The Company’s derivative financial instruments consist of collar option contracts and swaps.
A collar option is established with the sale of a short call option (ceiling price) and the purchase of a long put option (floor price) set to expire at a predetermined date in the future. The options give the owner the right but not the obligation to exercise the option at the expiration date.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
When the settlement price is below the established floor price, the Company receives an amount from its counterparty equal to the difference between the settlement price and the floor price multiplied by the hedged contract volume. When the settlement price is above the established ceiling price, the Company pays its counterparty an amount equal to the difference between the settlement price and the ceiling price multiplied by the hedged contract volume. When the settlement price is between the established floor and the ceiling, no amounts are due to or from the counterparty.
A swap contract allows the Company to receive a fixed price and pay a floating market price to the counterparty for the hedged commodity.
The Company has master netting agreements on individual derivative instruments with its counterparties and therefore certain amounts may be presented on a net basis in the condensed consolidated balance sheets.
Volume of Derivative Activities
The following table sets forth the Company’s outstanding commodity derivative contracts as of June 30, 2025.
| Third Quarter | Fourth Quarter | Total 2025 | 2026 | |||||||||||||||||||||||
| Collar (oil) | ||||||||||||||||||||||||||
| Volume (Bbl) | ||||||||||||||||||||||||||
| Weighted-average floor price ($/Bbl) | $ | $ | $ | $ | ||||||||||||||||||||||
| Weighted-average ceiling price ($/Bbl) | $ | $ | $ | $ | ||||||||||||||||||||||
| Collar (natural gas) | ||||||||||||||||||||||||||
| Volume (Mcf) | ||||||||||||||||||||||||||
| Weighted-average floor price ($/Mcf) | $ | $ | $ | $ | ||||||||||||||||||||||
| Weighted-average ceiling price ($/Mcf) | $ | $ | $ | $ | ||||||||||||||||||||||
| Swaps (natural gas) | ||||||||||||||||||||||||||
| Volume (Mcf) | ||||||||||||||||||||||||||
| Weighted-average price ($/Mcf) | $ | $ | $ | $ | ||||||||||||||||||||||
The following table summarizes the amounts reported as gain (loss) on derivatives - commodity derivatives in the condensed consolidated statements of operations for the three and six months ended June 30, 2025 and 2024:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Net cash receipts from (payments on) commodity derivatives | |||||||||||||||||||||||
| Oil derivatives | $ | $ | ( | $ | $ | ( | |||||||||||||||||
| Natural gas derivatives | |||||||||||||||||||||||
| Total net cash receipts from (payments on) commodity derivatives | $ | $ | $ | $ | |||||||||||||||||||
| Unrealized gain (loss) on commodity derivatives | |||||||||||||||||||||||
| Oil derivatives | $ | $ | $ | $ | ( | ||||||||||||||||||
| Natural gas derivatives | ( | ( | ( | ||||||||||||||||||||
| Total unrealized gain (loss) on commodity derivatives | $ | $ | ( | $ | $ | ( | |||||||||||||||||
| Total gain (loss) on derivatives - commodity derivatives | $ | $ | ( | $ | $ | ( | |||||||||||||||||
4. Fair Value Measurements
The Company has adopted and follows ASC 820, Fair Value Measurements and Disclosures, for measurement and disclosures about fair value of its financial instruments. ASC 820 establishes a framework for measuring fair value in U.S. GAAP, and expands disclosures about fair value measurements. To increase consistency and comparability in fair value
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
measurements and related disclosures, ASC 820 establishes a fair value hierarchy which prioritizes the inputs to valuation techniques used to measure fair value into three (3) broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. The three (3) levels of fair value hierarchy defined by ASC 820 are:
Level 1 — Inputs are unadjusted, quoted prices in active markets for identical assets or liabilities at the measurement date.
Level 2 — Inputs (other than quoted market prices included in Level 1) are either directly or indirectly observable for the asset or liability through correlation with market data at the measurement date and for the duration of the instrument’s anticipated life.
Level 3 — Inputs reflect management’s best estimate of what market participants would use in pricing the asset or liability at the measurement date. Consideration is given to the risk inherent in the valuation technique and the risk inherent in the inputs to the model. Valuation of instruments includes unobservable inputs to the valuation methodology that are significant to the measurement of fair value of assets or liabilities.
As defined by ASC 820, the fair value of a financial instrument is the amount at which the instrument could be exchanged in a current transaction between willing parties, other than in a forced or liquidation sale, which was further clarified as the price that would be received to sell an asset or paid to transfer a liability (“an exit price”) in an orderly transaction between market participants at the measurement date.
As required, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.
The following table presents the carrying amounts and fair values of the Company’s financial instruments as of June 30, 2025 and December 31, 2024:
| June 30, 2025 | December 31, 2024 | ||||||||||||||||||||||
(in thousands) | Carrying Value | Fair Value | Carrying Value | Fair Value | |||||||||||||||||||
| Assets: | |||||||||||||||||||||||
| Derivative instruments - commodity derivatives | $ | $ | $ | $ | |||||||||||||||||||
| Equity investments | $ | $ | $ | $ | |||||||||||||||||||
| Liabilities: | |||||||||||||||||||||||
| Revolving credit facilities | $ | $ | $ | $ | |||||||||||||||||||
| Derivative instruments - commodity derivatives | $ | $ | $ | $ | |||||||||||||||||||
Revolving credit facilities — The carrying amounts of the revolving credit facilities approximate their fair values, as the applicable interest rates are variable and reflective of market rates.
Other financial assets and liabilities — The carrying amounts of the Company’s other financial assets and liabilities, such as revenue receivable and accrued liabilities, approximate their fair values because of the short maturity of these instruments.
Derivative instruments - commodity derivatives — The fair value of the Company’s derivative instruments is estimated by management considering various factors, including closing exchange and over-the-counter quotations and the time value of the underlying commitments. The fair value of the Company’s commodity derivative instruments is considered to be a Level 2 measurement. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data, or supported by observable levels at which transactions are executed in the marketplace. The Company’s valuation models are primarily industry-standard models that consider
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
various inputs including: (i) quoted forward prices for commodities, (ii) current market and contractual prices for the underlying instruments, (iii) applicable credit-adjusted risk-free rate curves, as well as other relevant economic measures.
Equity investments — The fair value of the Company’s investment in Vital Energy's common stock was valued using the instrument's publicly listed trading price, which is considered to be a Level 1 measurement due to the use of an observable market quote in an active market. The fair value of the Company's investment in Vital Energy's preferred stock was estimated by management considering various factors, including the publicly listed trading price of Vital Energy's common shares and the present value of expected dividends prior to the conversion of the preferred shares. The fair value of the investment in preferred stock was considered to be a Level 2 measurement. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace.
On June 4, 2024, the 2.0 % cumulative mandatorily convertible preferred securities of Vital Energy were converted into 541,155 shares of common stock of Vital Energy. Prior to this conversion, the common shares of Vital Energy owned by the Company were not entitled to vote and bore a restricted legend to that effect. As of June 30, 2025 and December 31, 2024, the Company held 685,271 and 1,027,907 shares, respectively, of Vital Energy’s common stock, for which the fair value is a Level 1 measurement.
Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The following tables summarize (i) the valuation of each of the Company’s financial instruments by required fair value hierarchy levels and (ii) the gross fair value by the appropriate balance sheet classification, even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the Company’s condensed consolidated balance sheets as of June 30, 2025 and December 31, 2024. The Company nets the fair value of commodity derivative instruments by counterparty in the Company’s condensed consolidated balance sheets.
| June 30, 2025 | |||||||||||||||||||||||||||||||||||
| Fair Value Measurement Using | |||||||||||||||||||||||||||||||||||
| (in thousands) | Level 1 | Level 2 | Level 3 | Total Fair Value | Gross Amounts Offset in the Condensed Consolidated Balance Sheet | Net Fair Value Presented in the Condensed Consolidated Balance Sheet | |||||||||||||||||||||||||||||
| Equity investments | $ | $ | $ | $ | $ | — | $ | ||||||||||||||||||||||||||||
| Assets (at fair value): | |||||||||||||||||||||||||||||||||||
| Commodity derivatives – current portion | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Commodity derivatives – noncurrent portion | |||||||||||||||||||||||||||||||||||
| Liabilities (at fair value): | |||||||||||||||||||||||||||||||||||
| Commodity derivatives – current portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Commodity derivatives – noncurrent portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Net derivative instruments | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
| December 31, 2024 | |||||||||||||||||||||||||||||||||||
| Fair Value Measurement Using | |||||||||||||||||||||||||||||||||||
| (in thousands) | Level 1 | Level 2 | Level 3 | Total Fair Value | Gross Amounts Offset in the Condensed Consolidated Balance Sheet | Net Fair Value Presented in the Condensed Consolidated Balance Sheet | |||||||||||||||||||||||||||||
| Equity investments | $ | $ | $ | $ | $ | — | $ | ||||||||||||||||||||||||||||
| Assets (at fair value): | |||||||||||||||||||||||||||||||||||
| Commodity derivatives – current portion | $ | $ | $ | $ | $ | ( | $ | ||||||||||||||||||||||||||||
| Liabilities (at fair value): | |||||||||||||||||||||||||||||||||||
| Commodity derivatives – current portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Commodity derivatives – noncurrent portion | ( | ( | ( | ||||||||||||||||||||||||||||||||
| Net derivative instruments | $ | $ | ( | $ | $ | ( | $ | $ | ( | ||||||||||||||||||||||||||
Fair Values – Nonrecurring
Asset retirement obligations — The fair value measurements of asset retirement obligations are measured on a nonrecurring basis when a well is drilled or acquired or when production equipment and facilities are installed or acquired using a discounted cash flow model based on inputs that are not observable in the market and therefore represent Level 3 inputs. Significant inputs to the fair value measurement of asset retirement obligations include estimates of the costs of plugging and abandoning oil and natural gas wells, removing production equipment and facilities and restoring the surface of the land as well as estimates of the economic lives of the oil and natural gas wells and future inflation rates.
5. Acquisitions and Divestitures
Asset Acquisitions
During the six months ended June 30, 2025 and 2024, the Company acquired various oil and natural gas properties. The following table presents the cumulative adjusted purchase price of transactions accounted for as asset acquisitions in accordance with ASC Topic 805, Business Combinations (“ASC 805”) by basin included in oil and gas properties on the Company’s condensed consolidated balance sheets:
| Six Months Ended June 30, | ||||||||||||||
| (in thousands) | 2025 | 2024 | ||||||||||||
| Permian | $ | $ | ||||||||||||
| DJ | ||||||||||||||
| Appalachian | ||||||||||||||
| Total | $ | $ | ||||||||||||
In addition, during the six months ended June 30, 2024, the Company recorded closing adjustments that reduced the acquisition price of business combinations completed during 2023 by $1.1 million.
During the six months ended June 30, 2025 and 2024, the Company divested of certain proved and unproved properties for total proceeds of $0.2 million and $2.9 million, respectively. During the six months ended June 30, 2025, proceeds from the divested unproved properties of $0.1 million resulted in a gain on sale, which is included in other, net in the condensed consolidated statements of operations.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
6. Stock Incentive Plan
The Granite Ridge Resources, Inc. 2022 Omnibus Incentive Plan (the “Plan”) provides the Company the ability to grant, among other award types, stock options, restricted stock awards, and performance stock units ("PSUs") to directors, officers, employees and consultants or advisors employed by or providing service to the Company.
During the six months ended June 30, 2025 and 2024, the Company granted restricted stock awards, stock options, and PSUs. Stock-based compensation expense during the three and six months ended June 30, 2025 was $0.4 million and $1.0 million, respectively. Stock-based compensation expense during the three and six months ended June 30, 2024 was $0.6 million and $1.1 million, respectively.
Restricted Stock Awards - The Company grants service-based restricted stock awards to certain of its employees and consultants under the Plan, which generally vest ratably over a period of three years or cliff vest at the end of five years , and to non-employee directors, which vest in full after one year . Restricted stock awards are valued at the closing price of the Company's common stock on the date of grant. All restricted shares are legally issued and outstanding. If an employee terminates employment prior to the restriction lapse date, the awarded shares are forfeited and canceled and are no longer considered issued and outstanding. For restricted stock awards granted prior to March 2025, the holders of such unvested restricted stock awards have voting rights and the right to receive dividends. For restricted stock awards granted in March 2025 and thereafter, the holders of such unvested restricted stock awards do not have voting rights but do have the right to receive dividends. The Company recognizes compensation expense utilizing graded vesting whereby compensation expense is recognized over the service period for each separately vesting tranche.
PSUs - The Company grants PSUs to certain of its officers under the Plan. PSUs represent the contingent right to receive shares of the Company’s common stock once the PSU is vested and earned. PSUs, other than those granted during the three months ended June 30, 2025, cliff vest at the end of three years , generally subject to continued employment through the performance period. The total number of shares eligible to be earned may range from zero to 200 % of the target number of PSUs granted, determined based upon achievement of certain "financial performance" and "market performance" criteria for the Company and individual performance criteria for the officers awarded PSUs. Financial performance is based on the Company's financial performance at the end of the applicable performance period, while market performance is based on the relative standing of total shareholder return (“TSR”) achieved by the Company compared to the TSR achieved by a predetermined group of peer companies at the end of the applicable performance period. Individual performance criteria is based on the officers' performance relative to individual performance goals at the end of the performance period. The Company utilizes the Monte Carlo simulation method to determine the fair value of the PSUs based on market performance, while PSUs based on financial performance are valued using the closing price of the Company's common stock on the date of grant.
During the three months ended June 30, 2025, the Company granted 644,330 PSUs to certain of its officers under the Plan. These PSUs are eligible to vest, generally subject to continued employment, upon the satisfaction of certain stock price thresholds during the performance period, which ends on December 31, 2032. Each PSU represents the contingent right to receive one share of common stock once the PSU is earned. Each PSU is earned based on whether the Company’s stock price achieves a target average stock price for any 20 consecutive trading days during the performance period. If the stock price thresholds are not met by the end of the performance period, the PSUs will be forfeited and no shares of common stock will be issued. Compensation expense for these awards is based on the grant date fair market value of the award, calculated using a Monte Carlo simulation, and such costs are recorded on a straight-line basis over the derived requisite service period for each separately vesting portion of the award, as if the award was, in-substance, multiple awards, as applicable.
Stock Options - The Company grants stock options to certain of its officers under the Plan. The Company's outstanding stock options expire 10 years following the date of grant. Pursuant to the stock options granted under the Plan, 33 % of the options vest immediately with an additional 33 % to vest on each of the next two anniversaries of the date of the grant, generally subject to continued employment through each such vesting date. During the first quarter of 2025, the Company granted 110,257 stock options with an exercise price of $5.61 per share. During the first quarter of 2024, the Company granted 134,375 stock options with an exercise price per share of $6.06 .
Stock Awards - The Company may issue other awards to its employees and consultants under the Plan.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
A summary of the Company’s activity under the Plan for the restricted stock awards, PSUs and stock options for the six months ended June 30, 2025 is presented below:
| Restricted Stock Awards | Performance Stock Units | Stock Options | |||||||||||||||
| Outstanding at December 31, 2024 | |||||||||||||||||
Awards granted(1) | |||||||||||||||||
| Awards canceled/forfeited | ( | ( | ( | ||||||||||||||
Awards vested(2) | ( | ||||||||||||||||
| Outstanding at June 30, 2025 | |||||||||||||||||
| (1) Weighted average grant date fair value per share / unit | $ | $ | $ | ||||||||||||||
(2) Represents restricted stock and PSUs vested during the period. During the six months ended June 30, 2025, | |||||||||||||||||
A summary of the Company’s activity under the Plan for the restricted stock awards, PSUs and stock options for the six months ended June 30, 2024 is presented below:
| Restricted Stock Awards | Performance Stock Units | Stock Options | |||||||||||||||
| Outstanding at December 31, 2023 | |||||||||||||||||
Awards granted(1) | |||||||||||||||||
Awards vested(2) | ( | ||||||||||||||||
| Outstanding at June 30, 2024 | |||||||||||||||||
| (1) Weighted average grant date fair value per share / unit | $ | $ | $ | ||||||||||||||
(2) Represents restricted stock and PSUs vested during the period. During the six months ended June 30, 2024, | |||||||||||||||||
7. Income Taxes
The Company is a C corporation and subject to U.S. federal, state, and local income taxes. The Company records income taxes through the use of an estimated annual effective tax rate and specific events that are discretely recognized as they occur. For the three and six months ended June 30, 2025, the Company recorded income tax expense of $7.8 million and $10.7 million, respectively. For the three and six months ended June 30, 2024, the Company recorded income tax expense of $1.7 million and $6.5 million, respectively.
At the end of each interim period, the Company applies an estimated annualized effective tax rate to the current period income or loss before income taxes, which can produce interim effective tax rate fluctuations. The Company’s effective income tax rate was 23.7 % and 23.4 % for the three and six months ended June 30, 2025, respectively. For the three and six months ended June 30, 2024, the Company’s effective income tax rate was 24.8 % and 23.4 %, respectively. The effective tax rate differs from the enacted statutory rate of 21 % primarily due to the impact of certain discrete items and state income taxes.
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 June 30, 2025 and December 31, 2024, the Company had no
On July 4, 2025, President Trump signed the One Big Beautiful Bill Act (“OBBBA”) into law. The OBBBA includes, among other things, a permanent extension of 100% bonus depreciation for certain capital expenditures and modifications to the interest expense limitation under Section 163(j). In accordance with ASC Topic 740, Income Taxes, the effects of the tax law are recognized in the period of enactment and therefore not reflected in the Company’s unaudited condensed
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
8. Debt
The carrying value of the Company’s total debt was $275.0 million and $205.0 million at June 30, 2025 and December 31, 2024, respectively.
Granite Ridge Credit Agreement
On October 24, 2022, Granite Ridge entered into a senior secured revolving credit agreement (as amended, the “Credit Agreement”) with a syndicate of banks, currently led by Bank of America, N.A., as administrative agent. The Credit Agreement has a maturity date of five years from the effective date thereof, or October 24, 2027.
The borrowing base is redetermined semiannually on or about April 1 and October 1 of each calendar year, and is subject to additional adjustments from time to time, including for asset sales, elimination or reduction of hedge positions and incurrence of other debt.
On April 29, 2025, the Company and its lenders entered into the Fifth Amendment to Credit Agreement, which amended the Credit Agreement to, among other things, (a) increase the borrowing base from $325.0 million to $375.0 million, and (b) increase the aggregate elected commitments from $325.0 million to $375.0 million.
The Company and the Required Lenders (as defined in the Credit Agreement) may request one unscheduled redetermination of the borrowing base between each scheduled redetermination. The amount of the borrowing base is determined by the lenders in their sole discretion and consistent with the oil and gas lending criteria of the lenders at the time of the relevant redetermination. The amount the Company is able to borrow under the Credit Agreement is subject to compliance with the financial covenants, satisfaction of various conditions precedent to borrowing and other provisions of the Credit Agreement.
At June 30, 2025, the Company had outstanding borrowings of $275.0 million and $0.3 million of letters of credit issued and outstanding under the Credit Agreement, resulting in availability of $99.7 million. The Credit Agreement is guaranteed by the restricted subsidiaries of Granite Ridge and is secured by a first priority mortgage and security interest in substantially all of the Company’s and its restricted subsidiaries’ assets.
Borrowings under the Credit Agreement may be base rate loans or secured overnight financing rate (“SOFR”) loans. Interest is payable quarterly for base rate loans and at the end of the applicable interest period for SOFR loans. SOFR loans bear interest at SOFR plus an applicable margin ranging from 300 to 400 basis points, depending on the percentage of the borrowing base utilized, plus an additional 10 , 15 or 20 basis point credit spread adjustment for a one, three or six month interest period, respectively. Base rate loans bear interest at a rate per annum equal to the greatest of: (i) the U.S. prime rate as published by the Wall Street Journal; (ii) the federal funds effective rate plus 50 basis points; and (iii) the adjusted SOFR rate for a one-month interest period plus 100 basis points, plus, in the case of this clause (iii) an additional 10 basis point credit spread adjustment, plus, in the case of any base rate loan, an applicable margin ranging from 200 to 300 basis points, depending on the percentage of the borrowing base utilized.
The Company also pays a commitment fee on unused elected commitment amounts under its facility of 50 basis points. The Company may repay any amounts borrowed under the Credit Agreement prior to the maturity date without any premium or penalty.
The Credit Agreement contains certain financial covenants, including the maintenance of the following financial ratios:
(i)a leverage ratio, which is the ratio of Consolidated Total Debt to EBITDAX (each as defined in the Credit Agreement), of not greater than 3.00 to 1.00 as of the last day of any fiscal quarter, and
(ii)a Current Ratio (as defined in the Credit Agreement), of not less than 1.00 to 1.00 as of the last day of each fiscal quarter.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
At June 30, 2025, the Company was in compliance with all covenants required by the Credit Agreement.
9. Equity
Common Stock Dividends - The Company paid dividends of $14.4 million, or $0.11 per share, and $28.8 million, or $0.22 per share during the three and six months ended June 30, 2025, respectively. For the three and six months ended June 30, 2024, the Company paid dividends of $14.4 million, or $0.11 per share, and $28.7 million, or $0.22 per share, respectively. Any payment of future dividends will be at the discretion of the Company’s Board of Directors.
10. Related Party Transactions
Upon formation in 2022, Granite Ridge entered into a Management Services Agreement (the "MSA") with Grey Rock Administration, LLC (the “Manager”). Under the MSA, the Manager provides general management, administrative, and operating services covering the oil and gas assets and other properties of the Company and other day-to-day business and affairs of the Company. In accordance with the MSA, the Company pays the Manager an annual services fee of $10.0 million and reimburses the Manager for certain Granite Ridge group costs related to the operation of the Company’s assets (including for third party costs allocated or attributable to the assets of the Company). The initial term of the MSA expires on April 30, 2028; however, the MSA will automatically renew for additional consecutive one-year renewal terms until terminated in accordance with its terms. Upon any termination of the MSA, the Manager shall provide transition services for a period of up to 90 days.
For the three and six months ended June 30, 2025, service fees for the Company under the MSA were approximately $2.5 million and $5.0 million, respectively, and are included in general and administrative expenses within the accompanying condensed consolidated statements of operations. For the three and six months ended June 30, 2024, service fees for the Company under the MSA of $2.5 million and $5.0 million, respectively, were consistent with the same periods of 2025.
11. Risk Concentrations
As a non-operator, 100 % of the Company’s wells are operated by third-party operating partners. As a result, the Company is highly dependent on the success of these third-party operators. If they are not successful in the development, exploitation, production and exploration activities relating to the Company’s leasehold interests, or are unable or unwilling to perform, the Company’s financial condition and results of operations could be adversely affected. These risks are heightened in a low commodity price environment, which may present significant challenges to these third-party operators. The Company’s third-party operators will make decisions in connection with their operations that may not be in the Company’s best interests, and the Company may have little or no ability to exercise influence over the operational decisions of its third-party operators.
In the normal course of business, the Company maintains its cash balances in financial institutions, which at times may exceed federally insured limits. The Company is subject to credit risk to the extent any financial institution with which it conducts business is unable to fulfill contractual obligations on its behalf. Management monitors the financial condition of such financial institutions and does not anticipate any losses from these counterparties.
Derivative Counterparties - The Company uses credit and other financial criteria to evaluate the creditworthiness of counterparties to its derivative instruments. The Company believes that all of its derivative counterparties are currently acceptable credit risks. All of the Company’s outstanding derivative instruments are covered by International Swap Dealers Association Master Agreements (“ISDAs”) entered into with parties that are also lenders under the Company’s Credit Agreement. The Company’s obligations under the derivative instruments are secured pursuant to the Credit Agreement, and no additional collateral has been posted by the Company.
12. Earnings Per Share
The Company uses the two-class method of calculating earnings per share because certain of the Company’s unvested stock-based awards qualify as participating securities.
The Company’s basic earnings (loss) per share attributable to common stockholders is computed as (i) net income (loss) as reported, (ii) less participating basic earnings (iii) divided by weighted average basic common shares outstanding. The
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
Company’s diluted earnings (loss) per share attributable to common stockholders is computed as (i) basic earnings (loss) attributable to common stockholders, (ii) plus reallocation of participating earnings (iii) divided by weighted average diluted common shares outstanding.
The following table presents the basic and diluted earnings per share computations for the three and six months ended June 30, 2025 and 2024:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||
| Net income | $ | $ | $ | $ | |||||||||||||||||||||||||
| Participating basic earnings (a) | ( | ( | ( | ( | |||||||||||||||||||||||||
| Basic earnings attributable to common stockholders | |||||||||||||||||||||||||||||
| AG真人官方location of participating earnings | |||||||||||||||||||||||||||||
| Diluted earnings attributable to common stockholders | $ | $ | $ | $ | |||||||||||||||||||||||||
| Weighted average common shares outstanding: | |||||||||||||||||||||||||||||
| Weighted average common shares outstanding – basic | |||||||||||||||||||||||||||||
| Dilutive performance stock units | |||||||||||||||||||||||||||||
| Dilutive stock options | |||||||||||||||||||||||||||||
| Weighted average common shares outstanding – diluted | |||||||||||||||||||||||||||||
| Net income per common share: | |||||||||||||||||||||||||||||
| Basic | $ | $ | $ | $ | |||||||||||||||||||||||||
| Diluted | $ | $ | $ | $ | |||||||||||||||||||||||||
| (a) Unvested restricted stock awards represent participating securities because they participate in nonforfeitable dividends or distributions with the common equity holders of the Company. Participating earnings represent the distributed and undistributed earnings of the Company attributable to the participating securities. Unvested restricted stock awards do not participate in undistributed net losses as they are not contractually obligated to do so. | |||||||||||||||||||||||||||||
The following table is a summary of the PSUs and stock options, which were not included in the computation of diluted earnings per share, as inclusion of these items would be antidilutive.
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||
| Number of antidilutive common shares: | |||||||||||||||||||||||||||||
| Antidilutive performance stock units | |||||||||||||||||||||||||||||
| Antidilutive stock options | |||||||||||||||||||||||||||||
| Total antidilutive common shares | |||||||||||||||||||||||||||||
13. Subsequent Events
The Company’s Board of Directors declared a regular quarterly cash dividend of $0.11 for the third quarter of 2025. The dividend will be paid on September 15, 2025 to stockholders of record as of August 29, 2025.
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GRANITE RIDGE RESOURCES, INC.
Notes to Condensed Consolidated Financial Statements
14. Supplementary Data
Capitalized Costs
| (in thousands) | June 30, 2025 | December 31, 2024 | |||||||||
| Oil and natural gas properties: | |||||||||||
| Proved | $ | $ | |||||||||
| Unproved | |||||||||||
| Less: accumulated depletion | ( | ( | |||||||||
| Net capitalized costs for oil and natural gas properties | $ | $ | |||||||||
Costs Incurred for Oil and Natural Gas Producing Activities
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||||||||
| Property acquisition costs: | |||||||||||||||||||||||||||||||||||
| Proved | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
| Unproved | |||||||||||||||||||||||||||||||||||
| Development costs | |||||||||||||||||||||||||||||||||||
| Total costs incurred for oil and natural gas properties | $ | $ | $ | $ | |||||||||||||||||||||||||||||||
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Item 2. Management’s Discussion and Analysis of Financial Conditions and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our unaudited condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q.
The following 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 for oil and natural gas, capital expenditures, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed below and elsewhere in this Report. Please read “Cautionary Note Regarding Forward‑Looking Statements.” Also, please read the risk factors and other cautionary statements described under “Part I, Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2024 (the "2024 Form 10-K") and elsewhere in this Report. We assume no obligation to update any of these forward‑looking statements, except as required by applicable law.
Overview
Granite Ridge is a scaled energy company which aims to provide shareholders with exposure similar to energy private equity through operated partnerships and traditional non-operated assets. We own assets in six prolific unconventional basins across the United States. We aim to deliver a diversified portfolio with best-in-class full cycle returns by investing in a large number of high-graded opportunities developed by proven public and private operators. We focus on success as measured by total shareholder returns, which we seek to balance with a low leverage profile.
Selected Factors That Affect Our Operating Results
Our revenues, cash flows from operations and future growth depend substantially upon:
•the timing and success of drilling and production activities by our operating partners;
•the prices and the supply and demand for oil and natural gas;
•the quantity of oil and natural gas production from the wells in which we participate;
•changes in the fair value of the derivative instruments we use to reduce our exposure to fluctuations in the price of oil and natural gas;
•our ability to continue to identify and acquire high-quality acreage and drilling opportunities; and
•the level of our operating expenses.
In addition to the factors that affect companies in our industry generally, the location of substantially all of our acreage in the Eagle Ford, Permian, Bakken, Haynesville, Denver-Julesburg, and Appalachian Basins subjects our operating results to factors specific to these regions. These factors include the potential adverse impact of weather on drilling, production and transportation activities, particularly during the winter and spring months, as well as infrastructure limitations, transportation capacity, regulatory matters, and other factors that may specifically affect one or more of these regions.
The price of oil and natural gas can vary depending on the market in which it is sold and the means of transportation used to transport the oil and natural gas to market.
The price at which our oil and natural gas production is sold typically reflects either a premium or discount to the NYMEX benchmark price. Thus, our operating results are also affected by changes in the oil and natural gas price differentials between the applicable benchmark and the sales prices we receive for our oil and natural gas production.
Our oil price differential to the NYMEX benchmark price during the three months ended June 30, 2025 and 2024 was a discount of $(3.16) per barrel and $(3.97) per barrel, respectively. For the six months ended June 30, 2025 and 2024, our
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oil price differential to the NYMEX benchmark price was a discount of $(3.01) per barrel and $(1.68) per barrel, respectively.
Our natural gas price differential to the average NYMEX price during the three months ended June 30, 2025 and 2024 was a discount of $(0.87) per Mcf and $(0.09) per Mcf, respectively. For the six months ended June 30, 2025 and 2024, our natural gas price differential to the average NYMEX price was a discount of $(0.55) per Mcf and $(0.20) per Mcf, respectively.
Market Conditions
The price that we receive for the oil and natural gas our operators produce is largely a function of market supply and demand. Because our oil and natural gas revenues are heavily weighted toward oil, we are more significantly impacted by changes in oil prices than by changes in the price of natural gas. Worldwide supply in terms of output, especially production from properties within the United States, the production quota set by OPEC, and the strength of the U.S. dollar can adversely impact oil prices.
Historically, commodity prices have been volatile, and we expect that volatility to continue in the future. Although we cannot predict the occurrence of events that may affect future commodity prices, or the degree to which these prices will be affected, the prices for any commodity that we produce will generally approximate current market prices in the geographic region of the production. From time to time, we expect that we may hedge a portion of our commodity price risk to mitigate the impact of price volatility on our business.
Prices for various quantities of oil and natural gas that we produce significantly impact our revenues and cash flows. The following table lists average NYMEX spot prices for oil and natural gas for the three and six months ended June 30, 2025 and 2024.
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||
Average NYMEX Prices(1) | |||||||||||||||||||||||
| Oil (per Bbl) | $ | 64.57 | $ | 81.81 | $ | 68.12 | $ | 79.69 | |||||||||||||||
| Natural gas (per Mcf) | $ | 3.19 | $ | 2.07 | $ | 3.66 | $ | 2.11 | |||||||||||||||
(1)Based on average NYMEX spot prices. | |||||||||||||||||||||||
For the three months ended June 30, 2025, the average NYMEX oil pricing was $64.57 per barrel of oil, or 21% lower than the average NYMEX price per barrel for the three months ended June 30, 2024. Our settled derivatives increased our realized oil price per barrel by $0.49 for the three months ended June 30, 2025 and decreased our realized oil price per barrel by $0.38 for the three months ended June 30, 2024. For the three months ended June 30, 2025, our average realized oil price per barrel after reflecting settled derivatives was $61.90 compared to $77.46 for the three months ended June 30, 2024. For the six months ended June 30, 2025, the average NYMEX oil pricing was $68.12 per barrel of oil, or 15% lower than the average NYMEX price per barrel for the six months ended June 30, 2024. Our settled derivatives increased our realized oil price per barrel by $0.23 for the six months ended June 30, 2025 and decreased our realized oil price per barrel by $0.14 for the six months ended June 30, 2024. For the six months ended June 30, 2025, our average realized oil price per barrel after reflecting settled derivatives was $65.34 compared to $77.87 for the six months ended June 30, 2024.
For the three months ended June 30, 2025, the average NYMEX natural gas pricing was $3.19 per Mcf, or 54% higher than the average NYMEX price per Mcf for the three months ended June 30, 2024. Our settled derivatives increased our realized natural gas price per Mcf by $0.03 for the three months ended June 30, 2025 and increased our realized natural gas price per Mcf by $0.65 for the three months ended June 30, 2024. For the three months ended June 30, 2025, our average realized natural gas price per Mcf after reflecting settled derivatives was $2.35 compared to $2.63 for the three months ended June 30, 2024. For the six months ended June 30, 2025, the average NYMEX natural gas pricing was $3.66 per Mcf, or 73% higher than the average NYMEX price per Mcf for the six months ended June 30, 2024. Our settled derivatives increased our realized natural gas price per Mcf by $0.01 for the six months ended June 30, 2025 and increased our realized natural gas price per Mcf by $0.50 for the six months ended June 30, 2024. For the six months ended June 30, 2025, our average realized natural gas price per Mcf after reflecting settled derivatives was $3.12 compared to $2.41 for the six months ended June 30, 2024.
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Results of Operations
The following table sets forth summary production and operating data for the periods indicated. Because of normal production declines, increased or decreased drilling activities, fluctuations in commodity prices and the effects of
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acquisitions and divestitures, the historical information presented below should not be interpreted as being indicative of future results.
| Three months ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||
| 2025 | 2024 | 2025 | 2024 | ||||||||||||||||||||||||||||||||
| Net Sales (in thousands): | |||||||||||||||||||||||||||||||||||
| Oil sales | $ | 89,462 | $ | 77,493 | $ | 181,309 | $ | 153,259 | |||||||||||||||||||||||||||
| Natural gas and related product sales | 19,757 | 13,159 | 50,841 | 26,389 | |||||||||||||||||||||||||||||||
| Total revenues | $ | 109,219 | $ | 90,652 | $ | 232,150 | $ | 179,648 | |||||||||||||||||||||||||||
| Net Production: | |||||||||||||||||||||||||||||||||||
| Oil (MBbl) | 1,457 | 996 | 2,784 | 1,965 | |||||||||||||||||||||||||||||||
| Natural gas (MMcf) | 8,500 | 6,643 | 16,326 | 13,845 | |||||||||||||||||||||||||||||||
Total (MBoe)(1) | 2,874 | 2,103 | 5,505 | 4,273 | |||||||||||||||||||||||||||||||
| Average Daily Production: | |||||||||||||||||||||||||||||||||||
| Oil (Bbl) | 16,009 | 10,940 | 15,384 | 10,795 | |||||||||||||||||||||||||||||||
| Natural gas (Mcf) | 93,404 | 72,997 | 90,200 | 76,074 | |||||||||||||||||||||||||||||||
Total (Boe)(1) | 31,576 | 23,106 | 30,417 | 23,474 | |||||||||||||||||||||||||||||||
| Average Sales Prices: | |||||||||||||||||||||||||||||||||||
| Oil (per Bbl) | $ | 61.41 | $ | 77.84 | $ | 65.11 | $ | 78.01 | |||||||||||||||||||||||||||
| Effect of gain (loss) on settled oil derivatives on average price (per Bbl) | 0.49 | (0.38) | 0.23 | (0.14) | |||||||||||||||||||||||||||||||
Oil net of settled oil derivatives (per Bbl)(2) | $ | 61.90 | $ | 77.46 | $ | 65.34 | $ | 77.87 | |||||||||||||||||||||||||||
| Natural gas sales (per Mcf) | $ | 2.32 | $ | 1.98 | $ | 3.11 | $ | 1.91 | |||||||||||||||||||||||||||
| Effect of gain on settled natural gas derivatives on average price (per Mcf) | 0.03 | 0.65 | 0.01 | 0.50 | |||||||||||||||||||||||||||||||
Natural gas sales net of settled natural gas derivatives (per Mcf)(2) | $ | 2.35 | $ | 2.63 | $ | 3.12 | $ | 2.41 | |||||||||||||||||||||||||||
| AG真人官方ized price on a Boe basis excluding settled commodity derivatives | $ | 38.01 | $ | 43.12 | $ | 42.17 | $ | 42.05 | |||||||||||||||||||||||||||
| Effect of gain on settled commodity derivatives on average price (per Boe) | 0.34 | 1.88 | 0.16 | 1.56 | |||||||||||||||||||||||||||||||
AG真人官方ized price on a Boe basis including settled commodity derivatives(2) | $ | 38.35 | $ | 45.00 | $ | 42.33 | $ | 43.61 | |||||||||||||||||||||||||||
| Operating Expenses (in thousands): | |||||||||||||||||||||||||||||||||||
| Lease operating expenses | $ | 20,118 | $ | 13,669 | $ | 36,358 | $ | 29,148 | |||||||||||||||||||||||||||
| Production and ad valorem taxes | 6,437 | 6,881 | 14,805 | 12,630 | |||||||||||||||||||||||||||||||
| Depletion and accretion expense | 53,412 | 41,592 | 101,857 | 82,533 | |||||||||||||||||||||||||||||||
| General and administrative | 8,517 | 6,623 | 15,980 | 13,115 | |||||||||||||||||||||||||||||||
| Costs and Expenses (per Boe): | |||||||||||||||||||||||||||||||||||
| Lease operating expenses | $ | 7.00 | $ | 6.50 | $ | 6.60 | $ | 6.82 | |||||||||||||||||||||||||||
| Production and ad valorem taxes | $ | 2.24 | $ | 3.27 | $ | 2.69 | $ | 2.96 | |||||||||||||||||||||||||||
| Depletion and accretion | $ | 18.59 | $ | 19.78 | $ | 18.50 | $ | 19.32 | |||||||||||||||||||||||||||
| General and administrative | $ | 2.96 | $ | 3.15 | $ | 2.90 | $ | 3.07 | |||||||||||||||||||||||||||
| Net Producing Wells at Period-End: | 227.42 | 191.94 | 227.42 | 191.94 | |||||||||||||||||||||||||||||||
(1)Natural gas is converted to Boe using the ratio of one barrel of oil to six Mcf of natural gas. (2)The presentation of realized prices including settled commodity derivatives is a result of including the net cash receipts from (payments on) commodity derivatives that are presented in the footnotes to our condensed consolidated financial statements. This presentation of average prices with derivatives is a means by which to reflect the actual cash performance of our commodity derivatives for the respective periods and presents oil and natural gas prices with derivatives in a manner consistent with the presentation generally used by the investment community. | |||||||||||||||||||||||||||||||||||
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Oil, Natural Gas and Related Product Sales
Our revenues vary from year to year primarily due to changes in realized commodity prices and production volumes. Our oil and natural gas sales for the three months ended June 30, 2025 increased 20% from the same period in 2024. Oil revenues for the three months ended June 30, 2025 increased by 15% compared to the same period in 2024, driven by a 46% increase in production, partially offset by a 21% decrease in realized prices, excluding the effect of settled commodity derivatives. Natural gas revenues increased by 50% for the three months ended June 30, 2025 compared to 2024, driven by a 17% increase in realized natural gas prices, excluding the effect of settled commodity derivatives, and a 28% increase in production.
Our oil and natural gas sales for the six months ended June 30, 2025 increased 29% from the same period in 2024. Oil revenues for the first half of 2025 increased by 18% compared to the same period in 2024, driven by a 42% increase in production, partially offset by a 17% decrease in realized prices, excluding the effect of settled commodity derivatives. Natural gas revenues increased by 93% for the first half of 2025 compared to 2024 as a result of a 63% increase in realized natural gas prices, excluding the effect of settled commodity derivatives, and an 18% increase in production.
Production from oil and gas properties increased as a result of drilling success and the acquisition of additional net revenue interests. The number of wells we participated in increased from 191.94 net wells on June 30, 2024 to 227.42 net wells on June 30, 2025.
Lease Operating Expenses
Lease operating expenses were $20.1 million ($7.00 per Boe) for the three months ended June 30, 2025, an increase of 47% from $13.7 million ($6.50 per Boe) during the same period in 2024. The increase was primarily due to an increase in well count due to acquisitions and additional wells successfully drilled and completed, resulting in an increase in saltwater disposal costs of $1.9 million, or 58%, and an overall increase in service costs.
Lease operating expenses were $36.4 million ($6.60 per Boe) for the six months ended June 30, 2025, an increase of 25% from $29.1 million ($6.82 per Boe) during the same period in 2024. The increase was primarily due to an increase in production as a result of increased well count, resulting in increased saltwater disposal costs, facilities costs and an overall increase in cost of services.
Production and Ad Valorem Taxes
We generally pay production taxes based on realized oil and natural gas sales. Production taxes were $5.3 million ($1.86 per Boe) for the three months ended June 30, 2025 compared to $5.4 million ($2.59 per Boe) during the same period in 2024. As a percentage of oil and natural gas sales, our production taxes were 5% and 6% during the three months ended June 30, 2025 and 2024, respectively.
Production taxes were $11.9 million ($2.16 per Boe) for the six months ended June 30, 2025 compared to $9.7 million ($2.28 per Boe) during the same period in 2024. As a percentage of oil and natural gas sales, our production taxes were 5% during both the six months ended June 30, 2025 and 2024.
Production taxes fluctuate with the market value of our production sold, while ad valorem taxes are generally based on the valuation of our oil and natural gas properties at the beginning of the year, which vary across the different areas in which we operate.
Ad valorem taxes were $1.1 million and $2.9 million for the three and six months ended June 30, 2025, respectively, compared to $1.4 million and $2.9 million during the same periods in 2024.
Depletion and Accretion
Depletion and accretion was $53.4 million ($18.59 per Boe) for the three months ended June 30, 2025, an increase of 28% from $41.6 million ($19.78 per Boe) during the same period in 2024. The increase in depletion and accretion expense was primarily due to the increase in depletion expense resulting from the increase in production.
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Depletion and accretion was $101.9 million ($18.50 per Boe) for the six months ended June 30, 2025, an increase of 23% from $82.5 million ($19.32 per Boe) during the same period in 2024. The increase in depletion and accretion expense was primarily due to the increase in production.
Impairment of Unproved Properties
No impairment of unproved properties was recorded for the three months ended June 30, 2025 and 2024. In the first quarter of 2024, we recognized impairment expense of $0.7 million on unproved properties in the Permian Basin as the operator of those properties no longer intends to drill certain locations. During the six months ended June 30, 2025 no impairment of unproved properties was recorded.
General and Administrative
The following table provides components of our general and administrative expenses for the three and six months ended June 30, 2025 and 2024:
| Three months ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||||||||
| General and administrative expenses | $ | 8,122 | $ | 6,040 | $ | 14,932 | $ | 12,020 | |||||||||||||||||||||||||||
| Non-cash stock-based compensation | 395 | 583 | 1,048 | 1,095 | |||||||||||||||||||||||||||||||
| Total general and administrative expenses | $ | 8,517 | $ | 6,623 | $ | 15,980 | $ | 13,115 | |||||||||||||||||||||||||||
Total general and administrative expenses were $8.5 million ($2.96 per Boe) for the three months ended June 30, 2025, an increase of 29% from $6.6 million ($3.15 per Boe) during the same period in 2024. The increase was primarily due to severance expense incurred during the period as a result of a management transition as well as expenses related to capital market activities.
Total general and administrative expenses were $16.0 million ($2.90 per Boe) for the six months ended June 30, 2025, an increase of 22% from $13.1 million ($3.07 per Boe) during the same period in 2024. The increase was primarily due to severance expense incurred during the period as a result of a management transition as well as expenses related to capital market activities.
Gain/(Loss) on Derivatives – Commodity Derivatives
The following table sets forth the gain (loss) on derivatives for the three and six months ended June 30, 2025 and 2024:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||
| Net cash receipts from (payments on) commodity derivatives | |||||||||||||||||||||||
| Oil derivatives | $ | 708 | $ | (376) | $ | 642 | $ | (279) | |||||||||||||||
| Natural gas derivatives | 263 | 4,327 | 216 | 6,938 | |||||||||||||||||||
| Total net cash receipts from (payments on) commodity derivatives | $ | 971 | $ | 3,951 | $ | 858 | $ | 6,659 | |||||||||||||||
| Unrealized gain (loss) on commodity derivatives | |||||||||||||||||||||||
| Oil derivatives | $ | 9,519 | $ | 1,094 | $ | 10,873 | $ | (6,281) | |||||||||||||||
| Natural gas derivatives | 13,435 | (5,830) | (2,663) | (4,324) | |||||||||||||||||||
| Total unrealized gain (loss) on commodity derivatives | $ | 22,954 | $ | (4,736) | $ | 8,210 | $ | (10,605) | |||||||||||||||
| Total gain (loss) on derivatives - commodity derivatives | $ | 23,925 | $ | (785) | $ | 9,068 | $ | (3,946) | |||||||||||||||
Our earnings are affected by the changes in the value of our derivatives portfolio between periods and the related cash settlements of those derivatives, which could be significant. To the extent the future commodity price outlook declines between measurement periods, we will have mark-to-market gains; while to the extent future commodity price outlook increases between measurement periods, we will have mark-to-market losses.
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Interest Expense
Interest expense was $5.9 million for the three months ended June 30, 2025 compared to $5.8 million for the three months ended June 30, 2024. The increase in interest expense during the three months ended June 30, 2025 as compared to 2024 was primarily due to a higher average outstanding balance on the revolving credit facility, partially offset by a decrease in interest rates during 2025.
Interest expense was $10.9 million for the six months ended June 30, 2025 compared to $9.0 million for the six months ended June 30, 2024. The increase in interest expense during the six months ended June 30, 2025 as compared to 2024 was primarily due to a higher average outstanding balance on the revolving credit facility during 2025.
Loss on Equity Investments
We recorded a loss on equity investments of $5.8 million for the three months ended June 30, 2025. During the second quarter of 2025, the Company divested 342,636 shares of Vital Energy’s common stock and realized a loss on sale of $10.5 million. This was partially offset by an unrealized gain of $4.7 million from the change in fair value of the common stock of Vital Energy during the period. We recorded an unrealized loss of $8.8 million for the three months ended June 30, 2024 from the change in fair value of the common and preferred stock of Vital Energy.
We recorded a loss on equity investments of $15.8 million for the six months ended June 30, 2025. The loss is a result of a $10.5 million realized loss on sale of Vital Energy’s common stock and an unrealized loss of $5.2 million from the change in fair value of the common stock of Vital Energy. We recorded an unrealized loss of $1.0 million for the six months ended June 30, 2024 from the change in fair value of the common and preferred stock of Vital Energy.
Income Tax Expense
We recorded income tax expense of $7.8 million and $10.7 million for the three and six months ended June 30, 2025 compared to $1.7 million and $6.5 million for the three and six months ended June 30, 2024.The effective income tax rate differs from the statutory rate primarily due to the impact of certain discrete items and state income taxes.
Liquidity and Capital Resources
Our main sources of liquidity and capital resources as of the periods covered by this Report have been internally generated cash flow from operations and credit facility borrowings. Our primary use of capital has been for the development and acquisition of oil and natural gas properties. We continually monitor potential capital sources for opportunities to enhance liquidity or otherwise improve our financial position.
As of June 30, 2025, we had $275.0 million of debt outstanding under our Credit Agreement. We had $103.4 million of liquidity as of June 30, 2025, consisting of $99.7 million of committed borrowing availability under the Credit Agreement and $3.7 million of cash on hand.
On April 29, 2025, the Company and its lenders entered into the Fifth Amendment to the Credit Agreement, which amended the Credit Agreement to, among other things, increase the borrowing base and aggregate elected commitments from $325.0 million to $375.0 million.
With our cash on hand, cash flow from operations, and borrowing capacity under the Credit Agreement, we believe that we will have sufficient cash flow and liquidity to fund our budgeted capital expenditures and operating expenses for at least the next twelve months. However, we may seek additional access to capital and liquidity. We cannot assure you that any additional capital will be available to us on favorable terms or at all.
Capital Commitments
Our recent capital commitments have been to fund the development and acquisition of oil and natural gas properties. We expect to fund our near-term capital requirements and working capital needs with cash on hand, cash flows from operations and available borrowing capacity under our Credit Agreement. Our capital expenditures could be curtailed if our cash flows decline from expected levels.
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Common Stock Dividends
We paid dividends of $14.4 million, or $0.11 per share, and $28.8 million, or $0.22 per share during the three and six months ended June 30, 2025, respectively. For the three and six months ended June 30, 2024, the Company paid dividends of $14.4 million, or $0.11 per share, and $28.7 million, or $0.22 per share, respectively.
Any payment of future dividends will be at the discretion of the Company’s Board of Directors.
Cash Flows
The following table summarizes our changes in cash and restricted cash for the six months ended June 30, 2025 and 2024:
| Six Months Ended June 30, | |||||||||||
| (in thousands) | 2025 | 2024 | |||||||||
| Net cash provided by operating activities | $ | 154,134 | $ | 132,842 | |||||||
| Net cash used in investing activities | (200,533) | (152,579) | |||||||||
| Net cash provided by financing activities | 40,723 | 22,849 | |||||||||
| Net change in cash and restricted cash | $ | (5,676) | $ | 3,112 | |||||||
Cash Flows from Operating Activities
The primary factors impacting our cash flows from operating activities generally include: (i) levels of production from our oil and natural gas properties, (ii) prices we receive from sales of oil and natural gas production, including settlement proceeds or payments related to our commodity derivatives, (iii) operating costs of our oil and natural gas properties, (iv) costs of our general and administrative activities and (v) interest expense. Our cash flows from operating activities have historically been impacted by fluctuations in oil and natural gas prices and our production volumes.
The $21.3 million increase in operating cash flows during the six months ended June 30, 2025 as compared to the same period in 2024 was primarily due to the increase in oil and natural gas sales during the six months ended June 30, 2025 as compared to the same period in 2024.
Our net cash provided by operating activities included a reduction of $2.0 million and a benefit of $6.4 million for the six months ended June 30, 2025 and 2024, respectively, associated with changes in working capital items. Changes in working capital items adjust for the timing of receipts and payments of actual cash.
Cash Flows from Investing Activities
For the six months ended June 30, 2025, our net cash used in investing activities was $200.5 million, which consisted primarily of $164.5 million of capital expenditures for development of oil and natural gas properties and $44.9 million of acquisitions of oil and natural gas properties.
For the six months ended June 30, 2024, our net cash used in investing activities was $152.6 million, which consisted primarily of $135.9 million of capital expenditures for development of oil and natural gas properties and $20.9 million of acquisitions of oil and natural gas properties.
Cash Flows from Financing Activities
For the six months ended June 30, 2025, our net cash provided by financing activities was $40.7 million, primarily due to $70.0 million of net borrowings under our Credit Agreement, partially offset $28.8 million of dividends paid on our common stock.
For the six months ended June 30, 2024, our net cash provided by financing activities was $22.8 million, primarily due to $55.0 million of borrowings under our Credit Agreement, partially offset by $28.7 million of dividends paid on our common stock and $0.4 million of common stock repurchases.
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Granite Ridge Credit Agreement
At June 30, 2025, the Company had outstanding borrowings of $275.0 million and $0.3 million of letters of credit issued and outstanding under the Credit Agreement, resulting in availability of $99.7 million. The Credit Agreement is guaranteed by the restricted subsidiaries of Granite Ridge and is secured by a first priority mortgage and security interest in substantially all of the Company’s and its restricted subsidiaries’ assets.
On October 24, 2022, Granite Ridge entered into a senior secured revolving credit agreement with a syndicate of banks, currently led by Bank of America, N.A., as administrative agent. The Credit Agreement has a maturity date of five years from the effective date thereof, or October 24, 2027.
The borrowing base is redetermined semiannually on or about April 1 and October 1 of each calendar year, and is subject to additional adjustments from time to time, including for asset sales, elimination or reduction of hedge positions and incurrence of other debt.
On April 29, 2025, the Company and its lenders entered into the Fifth Amendment to Credit Agreement, which amended the Credit Agreement to, among other things, (a) increase the borrowing base from $325.0 million to $375.0 million, and (b) increase the aggregate elected commitments from $325.0 million to $375.0 million.
Borrowings under the Credit Agreement may be base rate loans or secured overnight financing rate (“SOFR”) loans. Interest is payable quarterly for base rate loans and at the end of the applicable interest period for SOFR loans. SOFR loans bear interest at SOFR plus an applicable margin ranging from 300 to 400 basis points, depending on the percentage of the borrowing base utilized, plus an additional 10, 15 or 20 basis point credit spread adjustment for a one, three or six month interest period, respectively. Base rate loans bear interest at a rate per annum equal to the greatest of: (i) the U.S. prime rate as published by the Wall Street Journal; (ii) the federal funds effective rate plus 50 basis points; and (iii) the adjusted SOFR rate for a one-month interest period plus 100 basis points, plus, in the case of this clause (iii) an additional 10 basis point credit spread adjustment, plus, in the case of any base rate loan, an applicable margin ranging from 200 to 300 basis points, depending on the percentage of the borrowing base utilized.
The Company also pays a commitment fee on unused elected commitment amounts under its facility of 50 basis points. The Company may repay any amounts borrowed under the Credit Agreement prior to the maturity date without any premium or penalty.
The Credit Agreement contains certain financial covenants, including the maintenance of the following financial ratios:
(i)a leverage ratio, which is the ratio of Consolidated Total Debt to EBITDAX (each as defined in the Credit Agreement), of not greater than 3.00 to 1.00 as of the last day of any fiscal quarter, and
(ii)a Current Ratio (as defined in the Credit Agreement), of not less than 1.00 to 1.00 as of the last day of each fiscal quarter.
The Credit Agreement contains additional restrictive covenants that limit our ability and our restricted subsidiaries to, among other things, incur additional indebtedness, incur additional liens, enter into mergers and acquisitions, make or declare dividends, repurchase or redeem junior debt, make investments and loans, engage in transactions with affiliates, sell assets and enter into certain hedging transactions. In addition, the Credit Agreement is subject to customary events of default, including a change in control. If an event of default occurs and is continuing, the administrative agent may, with the consent of majority lenders, or shall, at the direction of the majority lenders, accelerate any amounts outstanding and terminate lender commitments.
As of June 30, 2025, we were in compliance with all covenants required by the Credit Agreement.
Known Contractual and Other Obligations; Planned Capital Expenditures
Contractual and Other Obligations
Our contractual obligations include long-term debt, cash interest expense on debt, derivative liabilities, asset retirement obligations and an annual service fee to the Manager. Since December 31, 2024, there have been no material changes in
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our contractual obligations, other than the $70.0 million increase in long-term debt due to borrowings under the Credit Agreement.
Planned Capital Expenditures
For 2025, we are budgeting for approximately $400 million to $420 million in total planned capital expenditures, including approximately $120 million of acquisitions of oil and natural gas properties. Our costs incurred on oil and natural gas properties, excluding acquisitions, during the three months ended June 30, 2025 and 2024 totaled $77.2 million and $67.0 million, respectively, and $148.6 million and $129.6 million during the six months ended June 30, 2025 and 2024, respectively. Our capital expenditures for the six months ended June 30, 2025 were primarily funded with cash flows from operations and borrowings under the Credit Agreement. We expect to fund planned capital expenditures with cash generated from operations and, if required, borrowings under our Credit Agreement.
The amount, timing and allocation of capital expenditures are largely discretionary and subject to change based on a variety of factors. If oil and natural gas prices decline below our acceptable levels, or costs increase above our acceptable levels, we may choose to defer a portion of our budgeted capital expenditures until later periods to achieve the desired balance between sources and uses of liquidity and prioritize capital projects that we believe have the highest expected returns and potential to generate near-term cash flow. We may also increase our capital expenditures significantly to take advantage of opportunities we consider to be attractive. We will carefully monitor and may adjust our projected capital expenditures in response to changes in prices, availability of financing, drilling and acquisition costs, industry conditions, the timing of regulatory approvals, contractual obligations, internally generated cash flow, and other factors both within and outside our control.
Acquisitions
The following table reflects our expenditures for acquisitions of proved and unproved properties for the three and six months ended June 30, 2025 and 2024:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||||||||
| (in thousands) | 2025 | 2024 | 2025 | 2024 | |||||||||||||||||||||||||
| Property acquisition costs: | |||||||||||||||||||||||||||||
| Proved | $ | — | $ | 1,677 | $ | 13,341 | $ | 2,824 | |||||||||||||||||||||
| Unproved | 10,069 | 17,115 | 31,090 | 18,596 | |||||||||||||||||||||||||
| Total property acquisition costs | $ | 10,069 | $ | 18,792 | $ | 44,431 | $ | 21,420 | |||||||||||||||||||||
Satisfaction of Our Cash Obligations for the Next Twelve Months
With our Credit Agreement and our positive cash flows from operations, we believe we will have sufficient capital to meet our drilling commitments, expected general and administrative expenses, and other cash needs for the next twelve months. Nonetheless, any strategic acquisition of assets or increase in drilling activity may lead us to seek additional capital. We may also choose to seek additional capital rather than utilize our credit to fund accelerated or continued drilling at the discretion of management and depending on prevailing market conditions. We will evaluate any potential opportunities for acquisitions as they arise. However, there can be no assurance that any additional capital will be available to us on favorable terms or at all.
Effects of Inflation and Pricing
The oil and natural gas industry is typically very cyclical and the demand for goods and services of oilfield companies, suppliers and others associated with the industry put extreme pressure on the economic stability and pricing structure within the industry. Typically, as prices for oil and natural gas increase, so do all associated costs. Conversely, in a period of declining prices, associated cost declines are likely to lag and may not adjust downward in proportion.
Material changes in prices also impact our current revenue stream, estimates of future reserves, borrowing base calculations of bank loans, impairment assessments of oil and natural gas properties, and values of properties in purchase and sale transactions. Material changes in prices can impact the value of oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. Higher prices for oil and natural gas could result in increases in the costs of materials, services and personnel.
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Critical Accounting Estimates
The establishment and consistent application of accounting policies is a vital component of accurately and fairly presenting our financial statements in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”), as well as ensuring compliance with applicable laws and regulations governing financial reporting. While there are rarely alternative methods or rules from which to select in establishing accounting and financial reporting policies, proper application often involves significant judgment regarding a given set of facts and circumstances and a complex series of decisions. Further, these estimates and other factors, including those outside of management’s control, could have a significant adverse impact to the financial condition, results of operations and cash flows of the Company.
In management’s opinion, the more significant reporting areas impacted by management’s judgments and estimates are the choice of accounting method for oil and natural gas activities, oil and natural gas reserve estimation, revenue recognition, impairment of long-lived assets and valuation of financial derivatives.
There have been no material changes in our critical accounting policies and procedures during the six months ended June 30, 2025. See our disclosure of critical accounting policies in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Item 8. Financial Statements and Supplementary Data” of our 2024 Form 10-K.
Recently Issued or Adopted Accounting Pronouncements
For discussion of recent accounting pronouncements, see Note 2 of the Notes to Condensed Consolidated Financial Statements.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
Commodity Price Risk
We are exposed to market risk as the prices of our commodities are subject to fluctuations resulting from changes in supply and demand. To reduce our exposure to changes in the prices of our commodities, we have entered into, and may in the future enter into, additional commodity price risk management arrangements for a portion of our oil and natural gas production. The agreements that we have entered into generally have the effect of providing us with a fixed price for a portion of our expected future oil and natural gas production over a fixed period of time. Our commodity price risk management arrangements are recorded at fair value and thus changes to the future commodity prices will have an impact on our earnings. For the six months ended June 30, 2025, a 10% increase in average commodity prices would have decreased the fair value of commodity derivatives by $21.4 million. We may incur significant unrealized losses in the future from our use of derivative financial instruments to the extent market prices increase and our derivatives contracts remain in place.
We generally use derivatives to economically hedge a portion of our anticipated future production. Any payments due to counterparties under our derivative contracts are funded by proceeds received from the sale of our production. Production receipts, however, lag payments to the counterparties. Any interim cash needs are funded by cash from operations or borrowings under our Credit Agreement.
Interest Rate Risk
At June 30, 2025, our exposure to interest rate changes related primarily to the borrowings under the Credit Agreement. The interest we pay on these borrowings is set periodically based upon market rates. We had total indebtedness of $275.0 million outstanding under our Credit Agreement at June 30, 2025. The impact of a one percent increase in interest rates on this amount of debt would result in increased annual interest expense of approximately $2.8 million.
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We may utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce interest rate expense related to existing debt issues. Interest rate derivatives are used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio. We had no outstanding interest rate derivative contracts at June 30, 2025.
Item 4. Controls and Procedures
Disclosure Controls and Procedures
Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in company reports filed or submitted under the Exchange Act is accumulated and communicated to management, including our Chief Executive Officer and Interim Chief Financial Officer, to allow timely decisions regarding required disclosure.
In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints and that management is required to apply judgment in evaluating the benefits of possible controls and procedures relative to their costs.
As of June 30, 2025, an evaluation was performed under the supervision and with the participation of management, including our Chief Executive Officer and Interim Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) under the Exchange Act. Based upon our evaluation, our Chief Executive Officer and Interim Chief Financial Officer have concluded that as of June 30, 2025, our disclosure controls and procedures were effective at a level of reasonable assurance.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the second quarter of 2025 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
PART II – OTHER INFORMATION
Item 1. Legal Proceedings
The Company was not a party to any material legal proceedings during the three months ended June 30, 2025. In the future, the Company may be subject from time to time to litigation claims and governmental and regulatory proceedings arising in the ordinary course of business.
Item 1A. Risk Factors
Other than as set forth below, there have been no material changes in our risk factors from those described in our 2024 Form 10-K.
U.S. and foreign trade policies, including the assessment of tariffs and other impositions on imported goods, may have a material adverse impact on our business.
There is currently significant uncertainty about the future relationship between the United States and various other countries, including changes arising as a result of the new presidential administration, with respect to trade policies, treaties, tariffs, taxes, and other limitations on cross-border operations. For example, on April 2, 2025, the U.S. government announced a 10% universal tariff on product imports that, as of the date of this Report, continues to apply to countries with which the U.S. has a trade surplus. Since then, the U.S. government has imposed new trade tariffs, increased existing tariffs, and abruptly paused or reversed trade policies. Such tariffs could cause inflation, slow economic growth, intensify trade disputes and have placed downward pressure on oil prices. In addition, tariffs have the potential to significantly
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increase our operating and capital costs. If we were unable to mitigate the impacts of any such increased costs, our business and our results of operations could be adversely affected.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
None.
Item 3. Defaults Upon Senior Securities
None.
Item 4. Mine Safety Disclosures
Not applicable.
Item 5. Other Information
Item 6. Exhibits
| Exhibit No. | Description | |||||||
| 3.1 | Amended and Restated Certificate of Incorporation of Granite Ridge Resources, Inc. (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed with the SEC on October 28, 2022). | |||||||
| 3.2 | Amended and Restated Bylaws of Granite Ridge Resources, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed with the SEC on October 28, 2022). | |||||||
| 10.1* | Fifth Amendment to Credit Agreement, dated as of April 29, 2025, by and among Granite Ridge Resources, Inc., as borrower, the guarantors party thereto, Bank of America, N.A., as administrative agent, and the lenders party thereto. | |||||||
| 31.1* | Certification of the Company’s Chief Executive Officer Pursuant to Section 302 of the Sarbanes Oxley Act of 2002. | |||||||
| 31.2* | Certification of the Company’s Chief Financial Officer Pursuant to Section 302 of the Sarbanes Oxley Act of 2002. | |||||||
| 32.1* | Certification of the Company’s Chief Executive Officer and Chief Financial Officer Pursuant to Section 906 of the Sarbanes Oxley Act of 2002. | |||||||
| 101.INS* | Inline XBRL Instance Document | |||||||
| 101.SCH* | Inline XBRL Taxonomy Extension Schema Document | |||||||
| 101.CAL* | Inline XBRL Taxonomy Extension Calculation Linkbase Document | |||||||
| 101.DEF* | Inline XBRL Taxonomy Extension Definition Document | |||||||
| 101.LAB* | Inline XBRL Taxonomy Extension Label Linkbase Document | |||||||
| 101.PRE* | Inline XBRL Taxonomy Extension Presentation Linkbase Document | |||||||
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document) | |||||||
__________________________________________
* Filed herewith
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| GRANITE RIDGE RESOURCES, INC. | |||||||||||
August 7, 2025 | By: | /s/ TYLER S. FARQUHARSON | |||||||||
| Name: | Tyler S. Farquharson | ||||||||||
| Title: | President and Chief Executive Officer | ||||||||||
August 7, 2025 | By: | /s/ KIMBERLY A. WEIMER | |||||||||
| Name: | Kimberly A. Weimer | ||||||||||
| Title: | Interim Chief Financial Officer and Chief Accounting Officer | ||||||||||
36
Source:
Granite Ridge Resources Inc
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United States
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