What changed in this filing

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Item 2. Management’s Discussion and Analysis

2026-08-06 compared with 2026-05-07 · 52 added, 47 removed, 124 unchanged (44% of the section changed)

6 unchanged sentences

• Critical Accounting Policies and Estimates.

The financial information with respect to the three months ended March 31, 2026 and 2025, discussed below, is unaudited.

The financial information with respect to the three and six months ended June 30, 2026 and 2025, discussed below, is unaudited.

In the opinion of management, this information contains all adjustments, which consist only of normal recurring adjustments unless otherwise disclosed, necessary to state fairly the accompanying unaudited condensed consolidated financial statements.

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Mid-Continent region (“Mid-Con”).

The charts below show production by product and percent revenues for the three months ended March 31, 2026 and 2025:

Total MBoe production for the three months ended March 31, 2026 was comprised of approximately 21.1% oil, 49.7% natural gas and 29.2% NGL compared to 16.8% oil, 48.9% natural gas and 34.3% NGL in the first quarter of 2025.

The charts below show production by product and percent revenues for the three and six months ended June 30, 2026 and 2025:

Total MBoe production for the three months ended June 30, 2026 was comprised of approximately 18.3% oil, 49.6% natural gas and 32.1% NGL compared to 16.7% oil, 49.4% natural gas and 33.9% NGL in the second quarter of 2025.

Total MBoe production for the six months ended June 30, 2026 was comprised of approximately 19.6% oil, 49.7% natural gas and 30.7% NGL compared to 16.7% oil, 49.2% natural gas and 34.1% NGL in the first half of 2025.

Recent Events

• On June 26, 2026, the Company entered into a purchase and sale agreement for the acquisition of certain producing assets and leasehold interests in the Cherokee Play of the Mid-Continent region for $65.0 million, subject to customary purchase price adjustments, and three contingent earn-out payments of $2.0 million each, based on exceeding the average daily spot price for West Texas Intermediate crude oil at certain price thresholds beginning July 1, 2026 and ending December 31, 2027.

The Company expects to fund the acquisition with cash on hand.

The acquisition is expected to close during the third quarter of 2026 and will be effective May 1, 2026.

We remain committed to growing the value of our asset base in a safe, responsible and efficient manner, while prudently allocating capital to high-return, growth projects.

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Three-month periods ended

March 31, 2026 December 31, 2025 September 30, 2025 June 30, 2025 March 31, 2025

June 30, 2026 March 31, 2026 December 31, 2025 September 30, 2025 June 30, 2025

NYMEX Oil (per Bbl) $ 95.65 $ 72.74 $ 59.62 $ 65.78 $ 64.57

1 unchanged sentence

In order to reduce our exposure to price fluctuations, from time to time we may enter into commodity derivative contracts for a portion of our anticipated future oil, natural gas and NGL production as discussed in “Item 3.

Quantitative and Qualitative Disclosures About Market Risk.” During periods where the strike prices for our commodity derivative contracts are below market prices at the time of settlement, we may not fully benefit from increases in the market price of oil and natural gas.

Conversely, during periods of declining oil and natural gas market prices, our commodity derivative contracts may partially offset declining revenues and cash flows to the extent strike prices for our contracts are above market prices at the time of settlement.

Conversely, during periods of declining oil, natural gas and NGL market prices, our commodity derivative contracts may partially offset declining revenues and cash flows to the extent strike prices for our contracts are above market prices at the time of settlement.

See “Note 3 — Derivatives” to the accompanying unaudited condensed consolidated financial statements included in this Quarterly Report for additional information regarding our commodity derivatives.

Consolidated revenues are presented in the table below (in thousands):

Three Months Ended March 31,

2026 2025 Change

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 Change 2026 2025 Change

Oil $ 31,327 $ 16,956 $ 14,371 $ 56,398 $ 35,836 $ 20,562

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Our production and pricing information is shown in the table below:

Three Months Ended March 31,

2026 2025 Change

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 Change 2026 2025 Change

Production data

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Variances in oil, natural gas and NGL revenues attributable to changes in the average prices received for our production and total production volumes sold are shown in the table below (in thousands):

Three Months Ended March 31, 2026

Q1 2025 oil, natural gas and NGL revenues $ 42,604

Three Months Ended June 30, 2026 Six Months Ended June 30, 2026

2025 oil, natural gas and NGL revenues $ 34,531 $ 77,135

Change due to production volumes 6,948 12,779

Change due to average prices 9,638 10,980

Q1 2026 oil, natural gas and NGL revenues $ 49,777

2026 oil, natural gas and NGL revenues $ 51,117 $ 100,894

Operating Expenses

Operating expenses consisted of the following (in thousands):

Three Months Ended March 31,

2026 2025 Change

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 Change 2026 2025 Change

Lease operating expenses $ 10,302 $ 6,556 $ 3,746 $ 21,089 $ 17,473 $ 3,616

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Production, ad valorem, and other taxes (% of oil, natural gas and NGL revenue) 6.3 % 6.2 % 0.1 % 6.2 % 6.8 % (0.6) %

Lease operating expenses for the three months ended March 31, 2026 were consistent with the three months ended March 31, 2025.

The decrease in lease operating expenses per Boe was primarily driven by continued efficient operations and an increase in production volumes due to our ongoing drilling program in the Cherokee Play.

Production, ad valorem, and other taxes for the three months ended March 31, 2026 were consistent with the three months ended March 31, 2025.

The decrease in production, ad valorem, and other taxes per Boe was primarily due to a decrease in ad valorem taxes.

The increase in depreciation and depletion for oil and natural gas properties for the three months ended March 31, 2026 versus the same period in 2025 was primarily the result of an increase in sales volumes and our depletion rate.

Lease operating expenses for the three and six months ended June 30, 2026 increased in total and per BOE compared to the three and six months ended June 30, 2025 primarily due to a $2.1 million one-time non-cash adjustment during the three and six months ended June 30, 2025 of an operating accrual dating back to the Company’s emergence from bankruptcy (see Note 1—Basis of Presentation to the accompanying unaudited condensed consolidated financial statements included in Item 1 of this Quarterly Report for further information).

Production, ad valorem, and other taxes for the three and six months ended June 30, 2026 increased in total compared with the three and six months ended June 30, 2025 primarily due to higher average commodity prices, sales volumes, and related revenues.

Production, ad valorem, and other taxes per BOE increased for the three and six months ended June 30, 2026 compared with the three and six months ended June 30, 2025 primarily due to higher average commodity prices.

The increase in depreciation and depletion for oil and natural gas properties for the three and six months ended June 30, 2026 versus the same period in 2025 was primarily the result of an increase in sales volumes and our depletion rate.

A ceiling limitation calculation is performed at the end of each quarter.

1 unchanged sentence

Calculation of the full cost ceiling test is based on, among other factors, trailing twelve-month first-day-of-the-month index prices (“SEC prices”) as adjusted for price differentials and other contractual arrangements.

The SEC prices utilized in the calculation of proved reserves included in the full cost ceiling test at March 31, 2026 were $63.31 per barrel of oil and $3.72 per MMBtu of natural gas, before price differential adjustments.

The SEC prices utilized in the calculation of proved reserves included in the full cost ceiling test at June 30, 2026 were $71.90 per barrel of oil and $3.64 per MMBtu of natural gas, before price differential adjustments.

The ceiling limitation was not exceeded;

therefore, no full cost ceiling limitation impairments were recorded during the three months ended March 31, 2026 or 2025.

therefore, no full cost ceiling limitation impairments were recorded during the three or six months ended June 30, 2026 or 2025.

Full cost pool ceiling limitation impairments have no impact to our cash flow or liquidity.

Based on the SEC prices over the trailing ten months ended April 30, 2026, as well as two months of NYMEX strip pricing for May and June of 2026 as of April 30, 2026, we estimate the SEC prices utilized in the July 1, 2026 full cost ceiling test may be $72.15 per barrel of oil and $3.59 per MMBtu of natural gas (the "estimated second quarter prices").

Applying these estimated second quarter prices, and holding all other inputs constant to those used in the calculation of our March 31, 2026 ceiling test, we expect that no full cost ceiling limitation impairment is indicated for the second quarter of 2026.

Based on the SEC prices over the trailing ten months ended July 31, 2026, as well as two months of NYMEX strip pricing for August and September of 2026 as of July 30, 2026, we estimate the SEC prices utilized in the September 30, 2026 full cost ceiling test may be $75.25 per barrel of oil and $3.62 per MMBtu of natural gas (the "estimated third quarter prices").

Applying these estimated third quarter prices, and holding all other inputs constant to those used in the calculation of our June 30, 2026 ceiling test, we expect that no full cost ceiling limitation impairment is indicated for the third quarter of 2026.

Any actual full cost ceiling limitation impairment recognized in future quarters may fluctuate significantly from projected amounts based on the outcome of numerous other factors such as declines in the actual trailing twelve-month SEC prices, lower NGL pricing, changes in estimated future development costs and operating expenses, and other adjustments to our levels of proved reserves.

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Other operating expenses consisted of the following (in thousands):

Three Months Ended March 31,

2026 2025 Change

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 Change 2026 2025 Change

General and administrative $ 3,769 $ 3,028 $ 741 $ 6,757 $ 6,881 $ (124)

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Total other operating expenses $ (470) $ (2,619) $ 2,149 $ 6,200 $ 3,761 $ 2,439

General and administrative expenses decreased for the three months ended March 31, 2026 versus the same periods in 2026 primarily as a result of a decrease in personnel and other costs.

General and administrative expenses increased for the three months ended June 30, 2026 versus the same period in 2025 primarily as a result of increased professional fees and other costs.

General and administrative expenses for the six months ended June 30, 2026 were consistent with the same period in 2025.

The following table summarizes derivative activity (in thousands):

Three Months Ended March 31,

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 2026 2025

(Gain) loss on derivative contracts $ (4,222) $ (6,059) $ (696) $ (3,572)

1 unchanged sentence

Our derivative contracts were not designated as accounting hedges and, as a result, changes in their fair values were recorded each quarter as a component of operating expenses.

Internally, management has historically viewed the settlement of commodity derivative contracts at contractual maturity as adjustments to the price received for oil, natural gas and NGL production to determine “effective prices.” In general, cash is received on settlement of contracts due to lower oil and natural gas prices at the time of settlement, compared to the contract price for our commodity derivative contracts;

Internally, management has historically viewed the settlement of commodity derivative contracts at contractual maturity as adjustments to the price received for oil, natural gas and NGL production to determine “effective prices.” In general, cash is received on settlement of contracts due to lower oil, natural gas and NGL prices at the time of settlement, compared to the contract price for our commodity derivative contracts;

and, cash is paid on settlement of contracts due to higher oil, natural gas and NGL prices at the time of settlement, compared to the contract price for our commodity derivative contracts.

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Other Income (Expense)

Our other income (expense) are presented in the table below (in thousands):

Three Months Ended March 31,

Our other income (expense) is presented in the table below (in thousands):

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 2026 2025

Other income (expense)

Interest income (expense), net $ 735 $ 1,027 $ 1,549 $ 1,887

Other income (expense), net 1 (3) 1 (3)

Total other income $ 736 $ 1,024 $ 1,550 $ 1,884

Interest income, net during the three month periods ended March 31, 2026 and 2025 is primarily comprised of interest income on cash deposits.

Interest income, net during the three and six month periods ended June 30, 2026 and 2025 is primarily comprised of interest income on cash deposits.

Liquidity and Capital Resources

As of March 31, 2026, our cash and cash equivalents, including restricted cash, was $104.1 million.

As of June 30, 2026, our cash and cash equivalents, including restricted cash, was $114.7 million.

We expect our cash on hand and cash from operations to be adequate to meet our short and long-term liquidity needs.

We had no outstanding term or revolving debt obligations as of March 31, 2026.

We had no outstanding term or revolving debt obligations as of June 30, 2026.

Working Capital and Sources and Uses of Cash

Our principal sources of liquidity for the next year include cash flows from operations and cash on hand.

Decreases in accounts payable and accrued expenses are the primary driver of the increase in working capital to $83.5 million at March 31, 2026 compared to $79.8 million at December 31, 2025.

Decreases in accounts payable and accrued expenses are the primary driver of the increase in working capital to $93.9 million at June 30, 2026 compared to $79.8 million at December 31, 2025.

Our cash flows from operations are substantially dependent on current and future prices for oil, natural gas and NGL, which historically have been, and may continue to be, volatile.

1 unchanged sentence

Our cash flows are presented in the following table and discussed below (in thousands):

Three Months Ended March 31,

Six Months Ended June 30,

Cash flows provided by operating activities $ 62,195 $ 43,181

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Cash flows used in financing activities (15,504) (14,748)

(4,493) (9,478)

Net (decrease) increase in cash and cash equivalents and restricted cash $ (8,249) $ 1,598

__________________

(1) Includes $3.9 million and $4.1 million in dividend payments for the three months ended March 31, 2026 and 2025, respectively.

Net increase (decrease) in cash and cash equivalents and restricted cash $ 2,347 $ 4,688

Cash Flows from Operating Activities

The decrease in cash flows from operations for the three months ended March 31, 2026 compared to the same period in 2025 is primarily due to working capital changes partially offset by an increase in revenues from higher average commodity prices and higher sales volumes from our development program in the Cherokee Play of the Mid-Con.

The increase in cash flows from operations for the six months ended June 30, 2026 compared to the same period in 2025 is primarily due to an increase in revenues from higher average oil and NGL prices and higher sales volumes from our development program in the Cherokee Play of the Mid-Con.

Cash Flows from Investing Activities

Capital expenditures and acquisitions of oil and gas properties are summarized below (in thousands):

Three Months Ended March 31,

Six Months Ended June 30,

Capital Expenditures

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Cash Flows from Financing Activities

Cash used in financing activities for the three months ended March 31, 2026 consisted of $3.9 million in cash dividends, finance lease payments of $0.2 million, and $0.4 million of cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise.

Since 2023, the Company has paid cash dividends totaling $173.6 million and 0.1 million in shares issued in lieu of cash dividends under the Dividend Reinvestment Program, which represents $3.50 per share in special dividends and $1.22 per share in quarterly dividends for a total of $4.72 per share in total dividends.

Cash used in financing activities for the three months ended March 31, 2025 consisted primarily of $5.0 million in repurchases of common stock, $4.1 million in cash dividends, $0.1 million of cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise, and finance lease payments of $0.2 million.

Cash used in financing activities for the six months ended June 30, 2026 consisted of $14.5 million in cash dividends, $0.5 million of cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise, and finance lease payments of $0.4 million.

Since 2023, the Company has paid cash dividends totaling $184.2 million and issued 0.2 million shares in lieu of cash dividends under the Dividend Reinvestment Program, which represents $3.70 per share in special dividends and $1.35 per share in quarterly dividends for a total of $5.05 per share in total dividends.

Cash used in financing activities for the six months ended June 30, 2025 consisted primarily of $8.2 million in cash dividends, $5.9 million in repurchases of common stock, finance lease payments of $0.4 million, and $0.2 million of cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise.

Net exercises of stock awards allows the holder of a stock award to tender back to us a number of shares at fair value upon the vesting of such stock award that equals the employee payroll tax obligation due.

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Contractual Obligations and Off-Balance Sheet Arrangements

At March 31, 2026 our contractual obligations included asset retirement obligations, leases and other individually insignificant obligations.

At June 30, 2026, our contractual obligations included asset retirement obligations, leases and other individually insignificant obligations.

Additionally, we have certain financial instruments representing potential commitments that were incurred in the normal course of business to support our operations, including surety bonds.

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For a discussion of recent accounting pronouncements, newly adopted and recent accounting pronouncements not yet adopted, see “ Note 1—Basis of Presentation ” to the accompanying unaudited condensed consolidated financial statements included in Item 1 of this Quarterly Report.

We did not have any material changes in critical accounting policies, estimates, judgments and assumptions during the first three months of 2026.

We did not have any material changes in critical accounting policies, estimates, judgments and assumptions during the first six months of 2026.

Compared sentence by sentence after normalising whitespace, quotation marks, case and digits, so re-formatting and restated figures do not read as changed language. Wording changes appear as one removal and one addition. The current filing and the prior one are authoritative.

What changed 10-Q

Item 2. Management’s Discussion and Analysis