SEC Form 10-Q filed by Granite Ridge Resources Inc.

5/7/26 5:30:43 PM ET

$GRNT

Oil & Gas Production

Energy

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q


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

For the quarterly period ended March 31, 2026


o			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

___________________________________

GRANITE RIDGE RESOURCES, INC.

( Exact Name of Registrant as Specified in Its Charter )

___________________________________


Delaware						88-2227812
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification Number)

5217 McKinney Ave, Suite 400 Dallas, Texas						75205
(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

Common Stock, par value $0.0001 per share

GRNT

New York Stock Exchange

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

Accelerated filer

Non-accelerated filer

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 May 4, 2026, there were 131,895,990 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, the conflict in Iran, 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;

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•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 conditions, global supply chains 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, 2025 (the "2025 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.

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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 Stockholders' 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	27
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	36
Item 4.	Controls and Procedures	37
PART II – OTHER INFORMATION		38
Item 1.	Legal Proceedings	38
Item 1A.	Risk Factors	38
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	38
Item 3.	Defaults Upon Senior Securities	38
Item 4.	Mine Safety Disclosures	38
Item 5.	Other Information	38
Item 6.	Exhibits	39
Signatures		40

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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)	March 31, 2026		December 31, 2025
ASSETS
Current assets:
Cash	$	30,056	$	14,846
Revenue receivable	90,809		74,166
Advances to operators	2,500		2,682
Prepaid and other current assets	1,400		2,251
Derivative assets - commodity derivatives	1,706		13,978
Equity investments	17,635		10,960
Total current assets	144,106		118,883
Property and equipment:
Oil and gas properties, successful efforts method	1,953,601		1,897,388
Accumulated depletion	(912,560)		(857,832)
Total property and equipment, net	1,041,041		1,039,556
Long-term assets:
Derivative assets - commodity derivatives	3,221		3,743
Other long-term assets	5,505		5,889
Total long-term assets	8,726		9,632
Total assets	$	1,193,873	$	1,168,071
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	80,178	$	76,847
Current portion of long-term debt	26,250		17,500
Derivative liabilities - commodity derivatives	42,255		24
Other liabilities	7,043		810
Total current liabilities	155,726		95,181
Long-term liabilities:
Long-term debt, net	400,022		367,832
Derivative liabilities - commodity derivatives	5,159		—
Asset retirement obligations	12,320		11,968
Deferred tax liability	73,682		87,330
Other long-term payables	1,328		—
Total long-term liabilities	492,511		467,130
Total liabilities	648,237		562,311
Stockholders' equity:
Common stock, $0.0001 par value, 431,000,000 shares authorized, 137,601,731 and 136,941,978 issued at March 31, 2026 and December 31, 2025, respectively	14		14
Additional paid-in capital	660,626		659,228
Retained earnings (accumulated deficit)	(78,778)		(17,286)
Treasury stock, at cost, 5,692,412 and 5,686,711 shares at March 31, 2026 and December 31, 2025, respectively	(36,226)		(36,196)
Total stockholders' equity	545,636		605,760
Total liabilities and stockholders' equity	$	1,193,873	$	1,168,071

The accompanying notes are an integral part of these condensed consolidated financial statements.

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GRANITE RIDGE RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

Unaudited


	Three Months Ended March 31,
(in thousands, except per share data)	2026		2025
Revenues:
Oil and natural gas sales	$	128,264	$	122,931
Operating costs and expenses:
Lease operating expenses	29,679		16,240
Production and ad valorem taxes	8,236		8,368
Depletion and accretion expense	54,979		48,445
Impairments of long-lived assets	11,174		—
General and administrative	9,080		7,463
Other, net	267		(120)
Total operating costs and expenses	113,415		80,396
Net operating income	14,849		42,535
Other income (expense):
Loss on derivatives - commodity derivatives	(72,027)		(14,857)
Interest expense, net	(10,319)		(5,015)
Gain (loss) on equity investments	6,675		(9,971)
Other income	158		—
Total other income (expense)	(75,513)		(29,843)
Income (loss) before income taxes	(60,664)		12,692
Income tax expense (benefit)	(13,633)		2,880
Net income (loss)	$	(47,031)	$	9,812

Net income (loss) per share:
Basic	$	(0.36)	$	0.07
Diluted	$	(0.36)	$	0.07
Weighted-average number of shares outstanding:
Basic	130,620		130,336
Diluted	130,620		130,401

The accompanying notes are an integral part of these condensed consolidated financial statements.

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GRANITE RIDGE RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

Unaudited


Three Months Ended March 31, 2026
	Common Stock Issued			Additional Paid-in Capital		Retained Earnings (Accumulated Deficit)		Treasury Stock			Total Stockholders' Equity
(in thousands)	Shares	Amount						Shares	Amount
As of January 1, 2026	136,942	$	14	$	659,228	$	(17,286)	(5,687)	$	(36,196)	$	605,760
Common stock issued related to stock-based compensation	660	—		—		—		—	—		—
Stock-based compensation expense	—	—		1,398		—		—	—		1,398
Purchase of treasury stock	—	—		—		—		(5)	(30)		(30)
Common stock dividend declared ($0.11 per share)	—	—		—		(14,461)		—	—		(14,461)
Net loss	—	—		—		(47,031)		—	—		(47,031)
As of March 31, 2026	137,602	$	14	$	660,626	$	(78,778)	(5,692)	$	(36,226)	$	545,636


Three Months Ended March 31, 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	136,418	14		655,472		16,047		(5,684)	(36,180)		635,353
Common stock issued related to stock-based compensation	413	—		—		—		—	—		—
Forfeitures of restricted stock	(7)	—		—		—		—	—		—
Stock-based compensation expense	—	—		653		—		—	—		653
Purchase of treasury stock	—	—		—		—		(3)	(16)		(16)
Common stock dividend declared ($0.11 per share)	—	—		—		(14,389)		—	—		(14,389)
Net income	—	—		—		9,812		—	—		9,812
As of March 31, 2025	136,824	$	14	$	656,125	$	11,470	(5,687)	$	(36,196)	$	631,413

The accompanying notes are an integral part of these condensed consolidated financial statements.

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GRANITE RIDGE RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

Unaudited


	Three Months Ended March 31,
(in thousands)	2026		2025
Operating activities:
Net income (loss)	$	(47,031)	$	9,812
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion and accretion expense	54,979		48,445
Impairments of long-lived assets	11,174		—
Unrealized loss on derivatives - commodity derivatives	60,185		14,744
Stock-based compensation expense	1,398		653
Amortization of deferred financing costs and original issue discount	1,324		378
(Gain) loss on equity investments	(6,675)		9,971
Deferred income taxes	(13,647)		2,870
Other	(5)		(161)
Increase (decrease) in cash attributable to changes in operating assets and liabilities:
Revenue receivable	(16,643)		(11,053)
Accounts payable and accrued liabilities	4,948		1,213
Prepaid and other current assets	851		(810)
Other liabilities and long-term payables	7,490		29
Net cash provided by operating activities	58,348		76,091
Investing activities:
Capital expenditures for oil and natural gas properties	(60,378)		(66,728)
Acquisition of oil and natural gas properties	(9,496)		(34,692)
Refund of advances to operators	—		1,303
Proceeds from sale of oil and natural gas properties	1,227		120
Net cash used in investing activities	(68,647)		(99,997)
Financing activities:
Proceeds from borrowing on credit facilities	40,000		45,000
Purchase of treasury shares	(30)		(16)
Payment of dividends	(14,461)		(14,389)
Net cash provided by financing activities	25,509		30,595

Net change in cash	15,210		6,689
Cash at beginning of period	14,846		9,419
Cash at end of period	$	30,056	$	16,108

Supplemental disclosure of non-cash investing activities:
Change in accrued capital expenditures included in accounts payable and accrued liabilities	$	(4,546)	$	14,118
Advances to operators applied to development of oil and natural gas properties	$	40,131	$	18,200

The accompanying notes are an integral part of these condensed consolidated financial statements.

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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 2025 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, 2025 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 disclosures have been condensed in, or omitted from, these condensed consolidated financial statements. Accordingly, these notes to the condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes included in the Company’s 2025 Form 10-K.

Certain reclassifications have been made to prior period amounts to conform to the current period presentation.

Segment Reporting

The Company operates in one reporting segment, which is oil and natural gas development, exploration and production. All of the Company's operations are conducted in the geographic area of the United States. The reporting segment generates revenue through the sale of oil and natural gas. The Company’s chief operating decision maker (“CODM”), who is the Company’s Chief Executive Officer, manages operations on a consolidated basis for purposes of evaluating operational performance and allocating resources. Net income, as reported within the Company’s condensed consolidated statements of operations, is used by the CODM to assess performance for the oil and natural gas development, exploration and production segment. Significant segment expenses are the same as those reported in the condensed consolidated statements of operations. Total assets, as reported within the Company’s condensed consolidated balance sheets, is the measure of segment assets.

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 $54.7 million and $48.2 million for the three months ended March 31, 2026 and 2025, 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. There was no proved property impairment recorded for the three months ended March 31, 2026 or 2025.

Unproved oil and natural gas properties are periodically assessed for impairment by considering future drilling and exploration plans, results of exploration activities, commodity price outlooks, planned future sales and expiration of all or a portion of the projects. The Company recorded unproved oil and gas properties impairment of $11.2 million for the three months ended March 31, 2026 in the Permian Basin as a result of changes in operator development plans. There was no unproved impairment for the three months ended March 31, 2025.

Equity Investments

The Company follows the guidance in ASC 321, Investments - Equity Securities ("ASC 321") for its investment in common stock. 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 period until the preferred stock was converted into common stock.

The Company recognized an unrealized gain of $6.7 million and unrealized loss of $10.0 million for the three months ended March 31, 2026 and 2025, respectively, included in gain (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.

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

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

the condensed consolidated statements of operations. At the end of each month when the performance obligations are 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 Appalachian Basin (Ohio). The following tables present the disaggregation of the Company’s oil and natural gas revenues by basin for the three months ended March 31, 2026 and 2025.


	Three Months Ended March 31,
(in thousands)	2026		2025
Oil	$	103,446	$	91,847
Natural gas	24,818		31,084
Total	$	128,264	$	122,931

Permian	$	87,049	$	81,644
Eagle Ford	6,569		10,984
Bakken	6,412		9,857
Haynesville	11,953		5,738
DJ	7,489		10,400
Appalachian	8,792		4,308
Total	$	128,264	$	122,931

Recently Issued and Applicable Accounting Pronouncements (Issued and Not Yet Adopted)

In November 2024, the FASB issued ASU 2024-03, Disaggregation of Income Statement Expenses ("ASU 2024-03"), which requires enhanced disclosure about specific types of expenses included in the expense captions presented on the face of the consolidated statement of operations as well as disclosures about selling expenses. ASU 2024-03 is effective for

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

annual periods beginning after December 15, 2026 and interim periods beginning after December 15, 2027. Early adoption is permitted. The Company has not early adopted the standard and is currently assessing the effect that ASU 2024-03 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.

Commodity Derivatives Collar Option Contracts and Swaps

The Company’s commodity 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.

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.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

Volume of Commodity Derivative Collar Option Contracts and Swap Activities

The following table sets forth the Company’s outstanding commodity derivative contracts as of March 31, 2026.


	2026								2027		2028
	Second Quarter		Third Quarter		Fourth Quarter		Total		Total		Total
Collar (oil)
Volume (Bbl)	1,049,430		909,612		795,038		2,754,080		1,361,645		—
Weighted-average floor price ($/Bbl)	$	61.32	$	60.53	$	59.97	$	60.67	$	54.71	$	—
Weighted-average ceiling price ($/Bbl)	$	70.65	$	69.93	$	68.53	$	69.80	$	76.81	$	—
Swaps (oil)
Volume (Bbl)	95,082		73,484		53,974		222,540		452,936		—
Weighted-average price ($/Bbl)	$	60.33	$	60.27	$	60.24	$	60.29	$	60.21	$	—
Collar (natural gas)
Volume (Mcf)	1,851,019		1,727,756		3,868,320		7,447,095		6,099,088		2,211,640
Weighted-average floor price ($/Mcf)	$	3.25	$	3.25	$	3.66	$	3.46	$	3.89	$	3.60
Weighted-average ceiling price ($/Mcf)	$	4.00	$	4.00	$	4.44	$	4.23	$	4.97	$	4.73
Swaps (natural gas)
Volume (Mcf)	4,546,849		3,961,363		1,222,218		9,730,430		9,323,814		—
Weighted-average price ($/Mcf)	$	3.73	$	3.73	$	3.73	$	3.73	$	3.60	$	—
Swaps (Waha Basis)
Volume (Mcf)	—		—		—		—		2,540,086		—
Weighted-average price ($/Mcf)	$	—	$	—	$	—	$	—	$	(1.08)	$	—

Power Capacity Contract

On December 12, 2025, the Company entered into a power capacity contract ("Power Capacity Contract") as part of its strategy to enhance the value of its natural gas production. The arrangement is intended to economically hedge exposure to weak regional gas pricing and negative basis differentials by providing participation in power market revenues derived from converting natural gas into electricity.

The counterparty is constructing a fleet of distributed power generation facilities with an aggregate capacity of 200 megawatts, which are expected to begin commercial operations in late 2026. The Company’s agreement covers a portion of the total expected capacity and has a seven-year settlement term commencing upon the first facility achieving commercial operations.

Under the arrangement, the Company is obligated to make fixed monthly payments based on operating generation capacity multiplied by its participation interest. In return, the Company receives variable payments representing its share of the facilities’ operating profit. Operating profit is generally defined as revenue from the sale of power, less gas feedstock costs and a fixed operating and maintenance charge.

The structure allows the Company to benefit when power prices are favorable relative to gas prices, helping offset periods of depressed gas realizations. Conversely, when gas prices are strong and power generation is less economical, the Company may make net payments under the arrangement but benefits from improved cash flows on its physical gas sales. Overall, the arrangement is intended to stabilize and potentially enhance cash flows by diversifying the Company’s overall commodity price exposure.

The following table summarizes the amounts reported in the condensed consolidated statements of operations related to the commodity derivative instruments for the three months ended March 31, 2026 and 2025:

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements


	Three Months Ended March 31,
(in thousands)	2026		2025
Net cash receipts from (payments on) commodity derivatives
Oil derivatives	$	(6,316)	$	(66)
Natural gas derivatives	(5,526)		(47)
Total net cash receipts from (payments on) commodity derivatives	$	(11,842)	$	(113)
Unrealized gain (loss) on commodity derivatives
Oil derivatives	$	(66,444)	$	1,354
Natural gas derivatives	4,984		(16,098)
Power capacity contract	1,275		—
Total unrealized gain (loss) on commodity derivatives	$	(60,185)	$	(14,744)
Total gain (loss) on derivatives - commodity derivatives	$	(72,027)	$	(14,857)

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 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.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

The following table presents the carrying amounts and fair values of the Company’s financial instruments as of March 31, 2026 and December 31, 2025:


	March 31, 2026				December 31, 2025
(in thousands)	Carrying Value		Fair Value		Carrying Value		Fair Value
Assets:
Derivative instruments - commodity derivatives	$	4,927	$	4,927	$	17,721	$	17,721
Equity investments	$	17,635	$	17,635	$	10,960	$	10,960

Liabilities:
Revolving credit facilities	$	90,000	$	90,000	$	50,000	$	50,000
2029 Senior Notes	$	336,272	$	347,374	$	335,332	$	348,373
Derivative instruments - commodity derivatives	$	47,414	$	47,414	$	24	$	24

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 and are classified as Level 2 in the fair value hierarchy.

2029 Senior Notes - The carrying value reported for the Senior Notes is shown net of unamortized discount and unamortized deferred financing costs. The fair value of the Senior Notes was determined utilizing a discounted cash flow approach, discounted using market rates, and is classified as Level 3 in the fair value hierarchy.

Other financial assets and liabilities — The carrying amounts of the Company’s other financial assets and liabilities, such as revenue receivable and accounts payable and accrued liabilities, approximate their fair values because of the short maturity of these instruments.

Derivative instruments - commodity derivatives - collar option contracts and swaps — The fair value of the Company’s collar option contracts and swap commodity derivative instruments are 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 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.

Derivative instruments - commodity derivatives - power capacity contract — The fair value of the Company’s power capacity contract is estimated by management using a valuation model that incorporates both observable and unobservable inputs, as well as the time value of the underlying contractual cash flows. The fair value measurement is classified within Level 3 of the fair value hierarchy because significant inputs, including hourly forward power prices over the term of the agreement, are not observable for the term of the arrangement.

The Company utilizes a Monte Carlo simulation model to estimate fair value. Key inputs include: (i) forecasted hourly forward power prices at the applicable delivery nodes of the generation facilities, (ii) forward natural gas prices, (iii) long-term power and natural gas price volatilities and correlations, (iv) expected commercial operation dates of the facilities, (v) assumed operating efficiencies of the facilities, (vi) credit-adjusted discount rates, (vii) risk-free interest rate curves, and (viii) other relevant economic assumptions.

Because the valuation incorporates significant unobservable inputs, changes in these assumptions could materially impact the estimated fair value of the arrangement.

Equity investments — The fair value of the Company’s equity investment in 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.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

As of March 31, 2025, the Company held 1,027,907 shares of Vital Energy’s common stock, for which the fair value is a Level 1 measurement. On December 15, 2025, Crescent Energy completed its previously announced merger with Vital Energy. Under the merger agreement, each issued and outstanding share of Vital Energy common stock was converted into 1.9062 shares of Crescent Energy Class A common stock. As a result of the transaction, the Company’s 685,271 outstanding shares at the time of the merger closing in Vital Energy common stock were converted into 1,306,263 shares of Crescent Class A common stock, which remained held by the Company as of March 31, 2026, 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 March 31, 2026 and December 31, 2025. The Company nets the fair value of commodity derivative instruments by counterparty in the Company’s condensed consolidated balance sheets.


	March 31, 2026
	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 – common stock	$	17,635	$	—	$	—	$	17,635	$	—	$	17,635

Assets (at fair value):
Commodity derivatives – current portion	$	—	$	9,829	$	216	$	10,045	$	(8,339)	$	1,706
Commodity derivatives – noncurrent portion	—		3,636		1,911		5,547		(2,326)		3,221
Liabilities (at fair value):
Commodity derivatives – current portion	—		(50,594)		—		(50,594)		8,339		(42,255)
Commodity derivatives – noncurrent portion	—		(7,485)		—		(7,485)		2,326		(5,159)
Net derivative instruments	$	—	$	(44,614)	$	2,127	$	(42,487)	$	—	$	(42,487)

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements


	December 31, 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 - common stock	$	10,960	$	—	$	—	$	10,960	$	—	$	10,960

Assets (at fair value):
Commodity derivatives – current portion	$	—	$	14,988	$	—	$	14,988	$	(1,010)	$	13,978
Commodity derivatives – noncurrent portion	$	—	$	4,118	$	852	$	4,970	$	(1,227)	$	3,743

Liabilities (at fair value):
Commodity derivatives – current portion	—		(1,034)		—		(1,034)		1,010		(24)
Commodity derivatives – noncurrent portion	—		(1,227)		—		(1,227)		1,227		—
Net derivative instruments	$	—	$	16,845	$	852	$	17,697	$	—	$	17,697

The following table presents the significant unobservable inputs used in the valuation of the Level 3 Power Capacity Contract as of March 31, 2026.


Significant Unobservable Inputs(1)	Range
	Low			High			Average
Hourly forward power prices per MWh(2)	$	(60.49)		$	495.48		$	63.75
Forward gas prices per mmbtu(3)	$	(3.21)		$	4.20		$	2.49
Forward power volatility	30		%	30		%	30		%
Forward gas volatility	50		%	50		%	50		%

__________________________________________

(1)The range of the inputs may be influenced by factors such as time of day, delivery period, season and location. The average represents the arithmetic average of the underlying inputs and is not weighted by the related fair value or notional amount.

(2)Based on the Electric Reliability Council of Texas ("ERCOT") West Load Zone monthly forward around the clock swap prices shaped by historical hourly nodal prices in relation to ERCOT West Load Zone.

(3)Based on the Waha forward monthly gas prices.

The following table presents the changes in fair value of the Level 3 Power Capacity Contract:


	Three Months Ended March 31,
(in thousands)	2026
Balance at beginning of period	$	852
Gain (loss) on commodity derivatives	1,275
Balance at end of period	$	2,127

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

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

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

During the three months ended March 31, 2026 and 2025, 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:


	Three Months Ended March 31,
(in thousands)	2026		2025
Permian	$	5,285	$	29,644

Bakken	307		—


Appalachian	4,549		4,718
Total	$	10,141	$	34,362

During the three months ended March 31, 2026, the Company divested proved properties for proceeds of $1.2 million, which was accounted for as a normal retirement with no gain or loss recorded on the sale. During the three months ended March 31, 2025, the Company divested of unproved properties for proceeds of $0.1 million, for which a gain on sale of $0.1 million was recorded and included in other, net in the condensed consolidated statements of operations.

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 first quarter of 2026 and 2025, the Company granted restricted stock awards, stock options, and PSUs. Stock-based compensation expense during the three months ended March 31, 2026 and 2025 was $1.4 million and $0.7 million, respectively.

Restricted Stock Awards - The Company grants service-based restricted stock awards to certain of its employees and consultants, 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. Certain PSUs granted are based upon the achievement of "financial performance" and "market performance" criteria for the Company. Such PSUs 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 the determined financial performance and market performance criteria. 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. The Company utilizes the Monte

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

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 March 31, 2026, the Company granted 86,504 PSUs with a performance period ending on December 31, 2028, half of which are related to financial performance criteria and half of which are related to market performance criteria. During the three months ended March 31, 2025, the Company granted 76,650 PSUs with a performance period ending on December 31, 2027, half of which are related to financial performance criteria and half of which are related to market performance criteria. During the three months ended March 31, 2026, the Company issued 21,515 shares of common stock as a result of the conversion of 13,287 PSUs that vested on December 31, 2025.

Certain PSUs granted are based on the Company's achievement of stock price thresholds. During 2025, the Company granted 644,330 of these PSUs to certain of its officers under the Plan. During the first quarter of 2026, the Company granted an additional 292,398 of these PSUs. Such 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 such 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% vesting 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 three months ended March 31, 2026, the Company granted 102,478 stock options with an exercise price of $5.26 per share. During the three months ended March 31, 2025, the Company granted 110,257 stock options with an exercise price of $5.61 per share.

Other Awards - During the three months ended March 31, 2026 and March 31, 2025, the Company issued 3,194 and 3,084 common shares, respectively, to a director in lieu of cash compensation.

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 three months ended March 31, 2026 is presented below:


	Restricted Stock Awards		Performance Stock Units		Stock Options
Outstanding at December 31, 2025	775,647		719,407		298,458
Awards granted (1)	635,044		378,902		102,478
Awards canceled/forfeited	—		—		—
Awards vested (2)	(305,913)		(13,287)		—

Outstanding at March 31, 2026	1,104,778		1,085,022		400,936
(1) Weighted average grant date fair value per share / unit	$	5.14	$	4.61	$	1.08
(2) Represents restricted stock vested and PSUs converted to common stock during the period. During the three months ended March 31, 2026, 68,295 stock options vested. As of March 31, 2026, there were a total of 317,234 stock options exercisable.

A summary of the Company's activity under the Plan for the restricted stock awards, PSUs and stock options for the three months ended March 31, 2025 is presented below:


	Restricted Stock Awards		Performance Stock Units		Stock Options
Outstanding at December 31, 2024	518,048		97,532		526,483
Awards granted (1)	410,751		76,650		110,257
Awards canceled/forfeited	(7,046)		—		—
Awards vested (2)	(253,220)		—		—

Outstanding at March 31, 2025	668,533		174,182		636,740
(1) Weighted average grant date fair value per share / unit	$	5.81	$	6.79	$	1.21
(2) Represents restricted stock and PSUs vested during the period. During the three months ended March 31, 2025, 212,249 stock options vested and 518,444 stock options were exercisable as of March 31, 2025.

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 months ended March 31, 2026 and 2025, the Company recorded an income tax benefit of $13.6 million and income tax expense of $2.9 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 22.5% and 22.7% for the three months ended March 31, 2026 and 2025, 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 March 31, 2026 and December 31, 2025, the Company had no unrecognized tax benefits and did not recognize any interest or penalties during those respective periods related to unrecognized tax benefits.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

8. Debt

The Company’s long-term debt is comprised of the following:


(in thousands)	March 31, 2026		December 31, 2025
Revolving credit facility	$	90,000	$	50,000
Senior unsecured notes due 2029	350,000		350,000
Total debt	440,000		400,000
Less: Unamortized debt issuance costs on senior notes	$	(1,136)	$	(1,214)
Less: Unamortized debt discount	(12,592)		(13,454)
Total debt, net	$	426,272	$	385,332
Less: Current portion of outstanding long-term debt(1)	26,250		17,500
Total long-term debt, net	$	400,022	$	367,832

______________________________________

(1)As of March 31, 2026 and December 31, 2025, the current portion of long-term debt reflects $26.3 million and $17.5 million, respectively, due on the Senior Notes over the next twelve months.

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 the earliest to occur of (A) November 5, 2029 or (B) the date that is ninety-one days prior to the stated maturity date of the unsecured senior notes issued in November 2025 if any such notes remain outstanding on such date.

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. As of March 31, 2026, the Company had a borrowing base of $375.0 million and elected commitments of $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 March 31, 2026, the Company had outstanding borrowings of $90.0 million and $0.3 million of letters of credit issued and outstanding under the Credit Agreement, resulting in availability of $284.7 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 275 to 375 basis points, depending on the percentage of the borrowing base utilized. Base rate loans bear interest at a rate per annum equal to the greatest of: (i) the U.S. prime rate as publicly announced from time to time by Bank of America, N.A.; (ii) the federal funds effective rate plus 50 basis points; (iii) the adjusted SOFR rate for a one-month interest period plus 100 basis points; and (iv) 100 basis points, plus, in the case of any base rate loan, an applicable margin ranging from 175 to 275 basis points, depending on the percentage of the borrowing base utilized.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

The Company also pays a commitment fee on unused elected commitment amounts under its facility ranging from 37.5 to 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, and

(iii)an Asset Coverage Ratio (as defined in the Credit Agreement), commencing with the fiscal quarter ending June 30, 2026, of not less than (a) for each such fiscal quarter ending prior to December 31, 2026, 1.25 to 1.00 and (b) for each such fiscal quarter ending on or after December 31, 2026, 1.50 to 1.00.

At March 31, 2026, the Company was in compliance with all covenants required by the Credit Agreement.

2029 Senior Notes

On November 5, 2025, the Company, as issuer, completed an issuance of $350.0 million aggregate principal amount of 8.875% senior unsecured notes at 96.0% of par with stated maturity on November 5, 2029 (the "2029 Senior Notes") pursuant to the Note Purchase Agreement. The Company used the net proceeds from issuance of the 2029 Senior Notes to repay certain amounts under the Credit Agreement and to pay related fees and expenses. The Note Purchase Agreement allows the ability for the Company to incur up to $100.0 million of incremental notes for purposes of acquisition financing, subject to, among other things, the willingness of holders to provide such incremental notes and a pro forma net leverage ratio not greater than 2.00 to 1.00.

Interest is due to be paid at the end of each quarter. In addition, the Company will repay quarterly 2.5% of the original principal amount of the notes issued on the closing date beginning on September 30, 2026. If quarterly scheduled repayments are missed, the coupon increases to 11.875% and the Company is restricted from making any dividend payments until all delinquent scheduled repayments have been fulfilled. The Company has $26.3 million included in current liabilities in the condensed consolidated balance sheets related to quarterly principal repayments due within the next 12 months. On or after May 5, 2027 and on or prior to May 5, 2028, the Company may, at its option, redeem, at any time some or all of the 2029 Senior Notes at 103.0% of par, as set forth in the Note Purchase Agreement, plus accrued and unpaid interest, if any. Any redemption of the 2029 Senior Notes prior to May 5, 2027 is subject to payment of a make-whole amount. After May 5, 2028, the Company may redeem some or all of the Senior Notes at 100.0% of the principal amount thereof plus accrued and unpaid interest, if any. The principal remaining outstanding at the time of maturity is required to be paid in full by the Issuer.

The 2029 Senior Notes include certain covenants, which, among other things, requires the maintenance of (i) a net leverage ratio not greater than 3.25 to 1.00 and an (ii) asset coverage ratio greater than or equal to (A) for each Fiscal Quarter ending prior to December 31, 2026, 1.25 to 1.00 and (B) for each Fiscal Quarter ending on or after December 31, 2026, 1.50 to 1.00. The 2029 Senior Notes also contain a total leverage ratio and asset coverage ratio basket for Restricted Payments (as defined in the 2029 Senior Notes), which permits Restricted Payments in the form of cash distributions so long as, subject to certain other conditions, the leverage ratio, after giving pro forma effect to such Restricted Payments, cannot exceed 1.75 to 1.00, and the asset coverage ratio, after giving effect to such Restricted Payments, must be greater than or equal to 1.50 to 1.00. Under the 2029 Senior Notes, the Company must maintain a minimum hedging requirement included within the Senior Notes for oil and natural gas based on proved developed producing projected volumes for each commodity on a rolling 18-month basis.

The Senior Notes are general unsecured obligations ranking equally in right of payment with all other senior unsecured indebtedness of the Company and are senior in right of payment to all existing and future subordinated indebtedness of the Company. The Note Purchase Agreement contains customary terms and covenants and events of default, including limitations on the Company’s ability to incur additional secured and unsecured indebtedness.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

At March 31, 2026, the Company was in compliance with all financial covenants required by the Note Purchase Agreement.

9. Equity

The Company paid dividends of $14.5 million, or $0.11 per share during the three months ended March 31, 2026. The Company paid dividends of $14.4 million, or $0.11 per share, during the three months ended March 31, 2025. Any payment of future dividends will be at the discretion of the Company’s Board of Directors.

10. Related Party Transactions

On October 24, 2022, Grey Rock Administration, LLC (the “Manager”) entered into a Management Services Agreement with Granite Ridge (the “MSA”). 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 paid the Manager an annual services fee of $10.0 million and reimbursed 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).

On December 10, 2025, the Company entered into Amendment No. 1 to the Management Services Agreement, which amended the Company's existing MSA with the Manager ("Amendment No. 1"). Amendment No. 1, among other things, (a) extended the initial term from April 30, 2028 to April 30, 2031 and (b) increased the Services Fee (as defined in the MSA) from $10.0 million to $11.75 million effective January 1, 2026, provided for annual CPI-based adjustments beginning January 1, 2027 and delegated to management the authority to increase the Services Fee up to a maximum total of $12.5 million. 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 months ended March 31, 2026 and 2025, service fees for the Company under the MSA were approximately $2.9 million and $2.5 million, respectively, and are included in general and administrative expenses within the accompanying condensed consolidated statements of operations.

On December 12, 2025, Granite Ridge Ventures, LLC, a Delaware limited liability company and wholly owned subsidiary of the Company, entered into a power capacity contract with a portfolio company of funds managed by affiliates of Grey Rock Investment Partners ("Conduit Bravo"). A third party entered into a transaction with Conduit Bravo on substantially similar terms and at a substantially similar time to this transaction.

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

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

Association Master Agreements (“ISDAs”). All collar option contracts and swap derivatives entered into are with parties that are also lenders under the Company’s Credit Agreement. The Company’s obligations under the derivative instruments, with the exception of the Power Capacity Contract, are secured pursuant to the Credit Agreement, and no additional collateral has been posted by the Company.

12. Earnings (Loss) Per Share

The Company uses the two-class method of calculating earnings (loss) 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 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 computation of diluted net income (loss) per share excludes contingently issuable shares related to certain market-based equity awards as the required market price conditions had not been satisfied as of the end of the reporting period. These awards represent 936,728 shares of common stock that may be issued if specified market price targets are achieved. Because the market conditions were not met as of March 31, 2026, the shares were not included in the diluted weighted average share count. If the market conditions are satisfied in future periods, these shares could have a dilutive effect on earnings per share.

The following table presents the basic and diluted earnings per share computations for the three months ended March 31, 2026 and 2025:


	Three Months Ended March 31,
(in thousands, except per share data)	2026		2025
Net income (loss)	$	(47,031)	$	9,812
Participating basic earnings (a)	(100)		(56)
Basic earnings attributable to common stockholders	(47,131)		9,756
Reallocation of participating earnings	—		—
Diluted earnings attributable to common stockholders	$	(47,131)	$	9,756

Weighted average common shares outstanding:
Weighted average common shares outstanding – basic	130,620		130,336
Dilutive performance stock units	—		59
Dilutive stock options	—		6
Weighted average common shares outstanding – diluted	130,620		130,401

Net income (loss) per common share:
Basic	$	(0.36)	$	0.07
Diluted	$	(0.36)	$	0.07
(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.

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

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 March 31,
	2026	2025
Number of antidilutive common shares:
Antidilutive performance stock units	105,802	102,365
Antidilutive stock options	330,340	553,240
Total antidilutive common shares	436,142	655,605

13. Subsequent Events

Dividend

The Company's Board of Directors declared a regular quarterly cash dividend of $0.11 per share for the second quarter of 2026. The dividend will be paid on June 12, 2026 to stockholders of record as of May 29, 2026.

New Commodity Derivative Contracts

Subsequent to March 31, 2026, the Company entered into the following oil and natural gas derivative contracts to hedge estimated future production.


	2026								2027		2028
	Second Quarter		Third Quarter		Fourth Quarter		Total		Total		Total
Oil Swaps (WTI / Brent CMA Diff)
Volume (Bbl)	93,092		122,886		106,127		322,105		—		—
Weighted-average price ($/Bbl)	$	(7.50)	$	(7.50)	$	(7.50)	$	(7.50)	$	—	$	—
Gas Swaps (Waha Basis)
Volume (Mcf)	—		—		2,300,200		2,300,200		3,000,600		111,100
Weighted-average price ($/Mcf)	$	—	$	—	$	(1.60)	$	(1.60)	$	(1.60)	$	(1.60)

14. Supplementary Data

Capitalized Costs


(in thousands)	March 31, 2026		December 31, 2025
Oil and natural gas properties:
Proved	$	1,847,791	$	1,788,292
Unproved	105,810		109,096
Less: accumulated depletion	(912,560)		(857,832)
Net capitalized costs for oil and natural gas properties	$	1,041,041	$	1,039,556

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GRANITE RIDGE RESOURCES, INC.

Notes to Condensed Consolidated Financial Statements

Costs Incurred for Oil and Natural Gas Producing Activities


	Three Months Ended March 31,
(in thousands)	2026		2025
Property acquisition costs:
Proved	$	589	$	13,341
Unproved	9,552		21,021
Development costs	58,296		71,402
Total costs incurred for oil and natural gas properties	$	68,437	$	105,764

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Item 2. Management’s Discussion and Analysis of Financial Condition 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, 2025 (the "2025 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 March 31, 2026 and 2025 was a discount of $(2.80) per barrel and a discount of $(2.60) per barrel, respectively. Our natural gas price differential to

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the average NYMEX price during the three months ended March 31, 2026 and 2025 was a discount of $(2.16) per Mcf and $(0.17) 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 months ended March 31, 2026 and 2025.


	Three Months Ended March 31,
	2026		2025
Average NYMEX Prices(1)
Oil (per Bbl)	$	72.74	$	71.78
Natural gas (per Mcf)	$	4.71	$	4.14
(1)Based on average NYMEX spot prices.

For the three months ended March 31, 2026, the average NYMEX oil pricing was $72.74 per barrel of oil, or 1% higher than the average NYMEX price per barrel for the three months ended March 31, 2025. Our settled derivatives decreased our realized oil price per barrel by $4.27 for the three months ended March 31, 2026 and decreased our realized oil price per barrel by $0.05 for the three months ended March 31, 2025. For the three months ended March 31, 2026, our average realized oil price per barrel after reflecting settled derivatives was $65.67 compared to $69.13 for the three months ended March 31, 2025.

For the three months ended March 31, 2026, the average NYMEX natural gas pricing was $4.71 per Mcf, or 14% higher than the average NYMEX price per Mcf for the three months ended March 31, 2025. Our settled derivatives decreased our realized natural gas price per Mcf by $0.57 for the three months ended March 31, 2026 and decreased our realized natural gas price per Mcf by $0.01 for the three months ended March 31, 2025. For the three months ended March 31, 2026, our average realized natural gas price per Mcf after reflecting settled derivatives was $1.98 compared to $3.96 for the three months ended March 31, 2025.

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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 acquisitions and divestitures, the historical information presented below should not be interpreted as being indicative of future results.


	Three months ended March 31,
	2026		2025
Net Sales (in thousands):
Oil sales	$	103,446	$	91,847
Natural gas and related product sales	24,818		31,084
Total revenues	128,264		122,931

Net Production:
Oil (MBbl)	1,479		1,328
Natural gas (MMcf)	9,738		7,826
Total (MBoe)(1)	3,102		2,632
Average Daily Production:
Oil (Bbl)	16,433		14,752
Natural gas (Mcf)	108,200		86,960
Total (Boe)(1)	34,467		29,245

Average Sales Prices:
Oil (per Bbl)	$	69.94	$	69.18
Effect of loss on settled oil derivatives on average price (per Bbl)	(4.27)		(0.05)
Oil net of settled oil derivatives (per Bbl)(2)	65.67		69.13

Natural gas sales (per Mcf)	$	2.55	$	3.97
Effect of loss on settled natural gas derivatives on average price (per Mcf)	(0.57)		(0.01)
Natural gas sales net of settled natural gas derivatives (per Mcf)(2)	1.98		3.96

Realized price on a Boe basis excluding settled commodity derivatives	$	41.35	$	46.71
Effect of loss on settled commodity derivatives on average price (per Boe)	(3.82)		(0.04)
Realized price on a Boe basis including settled commodity derivatives(2)	37.53		46.67

Operating Expenses (in thousands):
Lease operating expenses	$	29,679	$	16,240
Production and ad valorem taxes	8,236		8,368
Depletion and accretion expense	54,979		48,445
General and administrative	9,080		7,463
Costs and Expenses (per Boe):
Lease operating expenses	$	9.57	$	6.17
Production and ad valorem taxes	2.66		3.18
Depletion and accretion	17.72		18.41
General and administrative	2.93		2.84

Net Producing Wells at Period-End:	245.55		211.63
(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 March 31, 2026 increased 4% from the same period in 2025. Oil revenues for the three months ended March 31, 2026 increased by 13% compared to the same period in 2025, driven by an 11% increase in production and a 1% increase in realized prices, excluding the effect of settled derivatives. Natural gas revenues decreased by 20% for the three months ended March 31, 2026 compared to the same period in 2025, driven by a 36% decrease in realized natural gas prices, excluding the effect of settled commodity derivatives, partially offset by a 24% 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 during the period increased from 211.63 net wells on March 31, 2025 to 245.55 net wells on March 31, 2026.

Lease Operating Expenses

Lease operating expenses were $29.7 million ($9.57 per Boe) for the three months ended March 31, 2026, an increase of 83% from $16.2 million ($6.17 per Boe) during the same period in 2025. The increase in lease operating expenses per Boe was primarily due to increased saltwater disposal costs as a result of higher water cuts and flowback operations, surface equipment rentals, and contract labor.

Production and Ad Valorem Taxes

We generally pay production taxes based on realized oil and natural gas sales. Production taxes were $6.1 million ($1.96 per Boe) for the three months ended March 31, 2026 compared to $6.6 million ($2.49 per Boe) during the same period in 2025. As a percentage of oil and natural gas sales, our production taxes were 5% during the three months ended March 31, 2026 and 2025.

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 increased by $0.3 million during the three months ended March 31, 2026 as compared to the same period in 2025, primarily due to additional wells drilled and completed and new wells acquired.

Depletion and Accretion

Depletion and accretion was $55.0 million ($17.72 per Boe) for the three months ended March 31, 2026, an increase of 13% from $48.4 million ($18.41 per Boe) during the same period in 2025. The increase in depletion and accretion expense was primarily due to the increase in depletion expense resulting from an increase in production between the two periods.

Impairment of Unproved Properties

For the three months ended March 31, 2026, we recognized impairment expense of $11.2 million on unproved properties in the Permian Basin as a result of a change in operator development plans.

General and Administrative

The following table provides components of our general and administrative expenses for the three months ended March 31, 2026 and 2025:


	Three months ended March 31,
(in thousands)	2026		2025
General and administrative expenses	$	7,682	$	6,810
Non-cash stock-based compensation	1,398		653
Total general and administrative expenses	$	9,080	$	7,463

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Total general and administrative expenses were $9.1 million ($2.93 per Boe) for the three months ended March 31, 2026, an increase of 22% from $7.5 million ($2.84 per Boe) during the same period in 2025. The increase was primarily due to increased stock-based compensation and management fee expenses during the three months ended March 31, 2026 as compared to the same period in 2025.

Gain/(Loss) on Derivatives – Commodity Derivatives

The following table summarizes the amounts reported as gain (loss) on derivatives - commodity derivatives in the condensed consolidated statements of operations for the three months ended March 31, 2026, and 2025:


	Three Months Ended March 31,
(in thousands)	2026		2025
Net cash receipts from (payments on) commodity derivatives
Oil derivatives	$	(6,316)	$	(66)
Natural gas derivatives	(5,526)		(47)
Total net cash receipts from (payments on) commodity derivatives	$	(11,842)	$	(113)
Unrealized gain (loss) on commodity derivatives
Oil derivatives	$	(66,444)	$	1,354
Natural gas derivatives	4,984		(16,098)
Power capacity contract	1,275		—
Total unrealized gain (loss) on commodity derivatives	$	(60,185)	$	(14,744)
Total gain (loss) on derivatives - commodity derivatives	$	(72,027)	$	(14,857)

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.

Interest Expense

Interest expense was $10.3 million for the three months ended March 31, 2026 compared to $5.0 million for the three months ended March 31, 2025. The increase in interest expense during the three months ended March 31, 2026 as compared to 2025 was primarily due to the issuance of $350.0 million aggregate principal amount of 8.875% senior unsecured notes in November 2025 that was outstanding during the entirety of the three months ended March 31, 2026.

Gain/(Loss) on Equity Investments

We recorded a gain of $6.7 million for the three months ended March 31, 2026 compared to a loss of $10.0 million for the three months ended March 31, 2025 resulting from the change in fair value of common stock held by the Company during the periods.

Income Tax Expense

We recorded income tax benefit of $13.6 million for the three months ended March 31, 2026 compared to income tax expense of $2.9 million for the three months ended March 31, 2025. 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, credit facility borrowings, and the issuance of senior notes. 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.

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As of March 31, 2026, we had $350.0 million of principal debt outstanding on 8.875% senior unsecured notes and $90.0 million of debt outstanding under our senior secured revolving credit agreement. We had $314.8 million of liquidity as of March 31, 2026, consisting of $284.7 million of committed borrowing availability under the Credit Agreement and $30.1 million of cash on hand.

With our cash on hand, cash flow from operations, senior unsecured notes 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.

Common Stock Dividends

We paid dividends of $14.5 million, or $0.11 per share, and $14.4 million, or $0.11 per share, during the first quarter of 2026 and 2025, 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 for the three months ended March 31, 2026 and 2025:


	Three Months Ended March 31,
(in thousands)	2026		2025
Net cash provided by operating activities	$	58,348	$	76,091
Net cash used in investing activities	(68,647)		(99,997)
Net cash provided by financing activities	25,509		30,595
Net change in cash	$	15,210	$	6,689

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 $17.7 million decrease in operating cash flows during the three months ended March 31, 2026 as compared to the same period in 2025 was primarily due to the increase in realized loss on derivatives during the three months ended March 31, 2026 as compared to the same period in 2025.

Our net cash provided by operating activities included a reduction of $3.4 million and a reduction of $10.6 million for the three months ended March 31, 2026 and 2025, 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 three months ended March 31, 2026, our net cash used in investing activities was $68.6 million, which consisted primarily of $60.4 million of capital expenditures for oil and natural gas properties and $9.5 million of acquisitions of oil and natural gas properties, partially offset by proceeds from sale of oil and natural gas properties of $1.2 million.

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For the three months ended March 31, 2025, our net cash used in investing activities was $100.0 million, which consisted primarily of $66.7 million of capital expenditures for oil and natural gas properties and $34.7 million of acquisitions of oil and natural gas properties.

Cash Flows from Financing Activities

For the three months ended March 31, 2026, our net cash provided by financing activities was $25.5 million, primarily due to $40.0 million of borrowings under our Credit Agreement, partially offset by $14.5 million of dividends paid on our common stock.

For the three months ended March 31, 2025, our net cash provided by financing activities was $30.6 million, primarily due to $45.0 million of borrowings under our Credit Agreement, partially offset by $14.4 million of dividends paid on our common stock.

Granite Ridge Credit Agreement

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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, and

At March 31, 2026, the Company was in compliance with all covenants required by the Credit Agreement.

2029 Senior Notes

On November 5, 2025, the Company, as issuer, completed an issuance of $350.0 million aggregate principal amount of 8.875% senior unsecured notes at 96.0% of par with stated maturity on November 5, 2029 pursuant to the Note Purchase Agreement. The Company used the net proceeds from issuance of the 2029 Senior Notes to repay certain amounts under the Credit Agreement and to pay related fees and expenses. The Note Purchase Agreement allows the ability for the Company to incur up to $100.0 million of incremental notes for purposes of acquisition financing, subject to, among other things, the willingness of holders to provide such incremental notes and a pro forma net leverage ratio not greater than 2.00 to 1.00.

Interest is due to be paid at the end of each quarter. In addition, the Company will repay quarterly 2.5% of the original principal amount of the notes issued on the closing date beginning on September 30, 2026. If quarterly scheduled repayments are missed, the coupon increases to 11.875% and the Company is restricted from making any dividend payments until all delinquent scheduled repayments have been fulfilled. The Company has $26.3 million included in current liabilities in the consolidated balance sheets related to quarterly principal repayments due within the next 12 months. On or after May 5, 2027 and on or prior to May 5, 2028, the Company may, at its option, redeem, at any time some or all of the 2029 Senior Notes at 103.0% of par, as set forth in the Note Purchase Agreement, plus accrued and unpaid interest, if any. Any redemption of the 2029 Senior Notes prior to May 5, 2027 is subject to payment of a make-whole amount. After May 5, 2028, the Company may redeem some or all of the Senior Notes at 100.0% of the principal amount thereof plus accrued and unpaid interest, if any. The principal remaining outstanding at the time of maturity is required to be paid in full by the Issuer.

The 2029 Senior Notes include certain covenants, which, among other things, requires the maintenance of (i) a net leverage ratio not greater than 3.25 to 1.00 and an (ii) asset coverage ratio greater than or equal to (A) for each Fiscal Quarter ending prior to December 31, 2026, 1.25 to 1.00 and (B) for each Fiscal Quarter ending on or after December 31, 2026, 1.50 to 1.00. The 2029 Senior Notes also contain a total leverage ratio and asset coverage ratio basket for Restricted Payments (as defined in the 2029 Senior Notes), which permits Restricted Payments in the form of cash distributions so long as, subject to certain other conditions, the leverage ratio, after giving pro forma effect to such Restricted Payments, cannot exceed 1.75 to 1.00, and the asset coverage ratio, after giving effect to such Restricted Payments, must be greater than or equal to 1.50 to 1.00. Under the 2029 Senior Notes, the Company must maintain a minimum hedging requirement included within the Senior Notes for oil and natural gas based on our proved developed producing projected volumes for each commodity on a rolling 18-month basis.

At March 31, 2026, the Company was in compliance with all financial covenants required by the Note Purchase Agreement.

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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, joint development agreements, and an annual service fee to the Manager. Since December 31, 2025, there have been no material changes in our contractual obligations, other than (i) the $40.0 million increase in long-term debt due to borrowings under the Credit Agreement and (ii) increase in contractually obligated fees under our joint development agreements.

The Company enters into joint development agreements that outline the terms for the joint evaluation, acquisition, exploration, development, and production of hydrocarbons from jointly owned interests subject to such agreements. These agreements designate a third party as the operator of all jointly owned interests in the applicable development area, while Granite Ridge retains the right to manage and control acquisition costs and strategy, development costs, timing and rig schedules, well design and other development operations in exchange for a fee. The aggregate minimum financial commitment amount over the noncancellable term of these joint development agreements is $15.5 million, which is due over the next two years.

Planned Capital Expenditures

For 2026, we are budgeting approximately $345 million to $385 million in total planned capital expenditures, including approximately $45 million to $55 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 March 31, 2026 and 2025 totaled $58.3 million and $71.4 million, respectively. Our capital expenditures for the three months ended March 31, 2026 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 months ended March 31, 2026 and 2025:


	Three Months Ended March 31,
(in thousands)	2026		2025
Property acquisition costs:
Proved	$	589	$	13,341
Unproved	9,552		21,021
Total property acquisition costs	$	10,141	$	34,362

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

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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.

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 three months ended March 31, 2026. 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 2025 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 three months ended March 31, 2026, a 10% increase in average commodity prices would have decreased the fair value of our collar option and swap commodity derivatives by $39.1 million. We may incur significant

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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 March 31, 2026, our exposure to interest rate changes related primarily to the borrowings under the Credit Agreement as the 2029 Senior Notes bear a fixed interest rate. The interest we pay on these borrowings is set periodically based upon market rates. We had total indebtedness of $90.0 million outstanding under our Credit Agreement at March 31, 2026. The impact of a 100 basis point increase in interest rates on this amount of debt would result in increased annual interest expense of approximately $0.9 million.

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 March 31, 2026.

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 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 March 31, 2026, an evaluation was performed under the supervision and with the participation of management, including our Chief Executive Officer and 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 Chief Financial Officer have concluded that as of March 31, 2026, 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 first quarter of 2026 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings

The Company was not a party to any material legal proceedings during the three months ended March 31, 2026. 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

There have been no material changes in our risk factors from those described in our 2025 Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities

The following table sets forth our share repurchase activity for each period presented:


Period	Total number of shares purchased (1)	Average price paid per share	Total number of shares purchased as part of publicly announced plans	Approximate dollar value of shares that may yet be purchased under the plans or programs (in millions)
January 1, 2026 - January 31, 2026	—	$—	—	$—
February 1, 2026 - February 28, 2026	—	$—	—	$—
March 1, 2026 - March 31, 2026	5,701	$5.25	—	$—
(1)Represents shares that were forfeited for payment of taxes upon vesting of previously awarded restricted stock pursuant to the Granite Ridge Resources, Inc. 2022 Omnibus Incentive Plan.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

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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#						Amendment No. 1 to the Employment Agreement, dated as of March 4, 2026, by and between Granite Ridge Resources, Inc. and Tyler Farquharson.
10.2#						Amendment No.1 to the Change of Control Termination Agreement, dated as of March 4, 2026, by and between Granite Ridge Resources, Inc. and Kimberly A. Weimer.
31.1*						Certification of the Company’s Chief Executive Officer Pursuant to Section 302 of the Sarbanes Oxley Act of 2002 (18 U.S.C. Section 7241).
31.2*						Certification of the Company’s Chief Financial Officer Pursuant to Section 302 of the Sarbanes Oxley Act of 2002 (18 U.S.C. Section 7241).
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 (18 U.S.C. Section 1350).
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

# Indicates management contract or compensatory plan arrangement.

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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.


May 7, 2026	By:	/s/ TYLER S. FARQUHARSON
		Name:	Tyler S. Farquharson
		Title:	President and Chief Executive Officer


May 7, 2026	By:	/s/ R. KYLE KETTLER
		Name:	R. Kyle Kettler
		Title:	Chief Financial Officer


May 7, 2026	By:	/s/ KIMBERLY A. WEIMER
		Name:	Kimberly A. Weimer
		Title:	Chief Accounting Officer

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Date	Price Target	Rating	Analyst
2/21/2025		Overweight → Equal Weight	CapitalOne
6/14/2024	$7.00	Neutral	BofA Securities
5/15/2024	$8.80	Buy	ROTH MKM
11/7/2023	$9.00	Buy	BofA Securities
9/27/2023	$8.00	Overweight	Stephens

SEC Form 10-Q filed by Granite Ridge Resources Inc.

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Chief Financial Officer Kettler Ronald Kyle bought $30,480 worth of shares (6,000 units at $5.08), increasing direct ownership by 5% to 129,276 units (SEC Form 4)

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Director Mccartney John bought $17,430 worth of shares (3,000 units at $5.81), increasing direct ownership by 2% to 139,143 units (SEC Form 4)

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