Form 10-Q - Quarterly report [Sections 13 or 15(d)]

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q


☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2023
OR
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to

Commission File Number: 001-35467

Battalion Oil Corporation

(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction of
incorporation or organization)

1311
(Primary Standard Industrial
Classification Code Number)

20-0700684
(I.R.S. Employer
Identification Number)

3505 West Sam Houston Parkway North, Suite 300, Houston, TX 77043

(Address of principal executive offices)

(832) 538-0300

(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§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 ⌧ No ◻

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

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. ◻

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

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	BATL	NYSE American

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities made under a plan confirmed by a court. Yes ⌧ No ◻

At August 17, 2023, 16,456,563 shares of the Registrant’s Common Stock were outstanding.

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TABLE OF CONTENTS

		PAGE
PART I	FINANCIAL INFORMATION
ITEM 1.	Condensed Consolidated Financial Statements (Unaudited)	5
	Condensed Consolidated Statements of Operations (Unaudited) for the Three and Six Months Ended June 30, 2023 and 2022	5
	Condensed Consolidated Balance Sheets (Unaudited) as of June 30, 2023 and December 31, 2022	6
	Condensed Consolidated Statements of Stockholders’ Equity (Unaudited) for the Three and Six Months Ended June 30, 2023 and the Year Ended December 31, 2022	7
	Condensed Consolidated Statements of Cash Flows (Unaudited) for the Six Months Ended June 30, 2023 and 2022	9
	Notes to Unaudited Condensed Consolidated Financial Statements	10
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	26
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	35
ITEM 4.	Controls and Procedures	35

PART II	OTHER INFORMATION
ITEM 1.	Legal Proceedings	36
ITEM 1A.	Risk Factors	36
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	36
ITEM 3.	Defaults Upon Senior Securities	36
ITEM 4.	Mine Safety Disclosures	36
ITEM 5.	Other Information	36
ITEM 6.	Exhibits	37
Signatures		38

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Special note regarding forward-looking statements

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of the federal securities laws. All statements, other than statements of historical facts, are forward looking statements and may concern, among other things, planned capital expenditures, potential increases in oil and natural gas production, potential costs to be incurred, future cash flows and borrowings, our financial position, business strategy and other plans and objectives for future operations. These forward-looking statements may be identified by their use of terms and phrases such as “may,” “expect,” “estimate,” “project,” “plan,” “objective,” “believe,” “predict,” “intend,” “achievable,” “anticipate,” “will,” “continue,” “potential,” “should,” “could” and similar terms and phrases. Although we believe that the expectations reflected in forward-looking statements are reasonable, they do involve assumptions, risks and uncertainties. Actual results could differ materially from those anticipated in these forward-looking statements. Readers should consider carefully the risks described under the “Risk Factors” section of our previously filed Annual Report on Form 10-K for the fiscal year ended December 31, 2022, as well as the other disclosures contained herein and therein, which describe factors that could cause our actual results to differ from those anticipated in forward-looking statements, which include, but are not limited to, the following factors:

●

volatility in prices for oil, natural gas and natural gas liquids;

●

our ability to generate sufficient cash flow from operations, borrowings or other sources to enable us to fund our operations, satisfy our obligations and develop our undeveloped acreage positions;

●

contractual limitations that affect our management’s discretion in managing our business, including covenants that, among other things, limit our ability to incur debt, make investments and pay cash dividends;

●

our indebtedness, which may increase in the future, and higher levels of indebtedness can make us more vulnerable to economic downturns and adverse developments in our business;

●

our ability to replace our oil and natural gas reserves and production;

●

the presence or recoverability of estimated oil and natural gas reserves attributable to our properties and the actual future production rates and associated costs of producing those oil and natural gas reserves;

●

our ability to successfully develop our inventory of undeveloped acreage;

●

the cost and availability of goods and services, such as drilling rigs, fracture stimulation services and tubulars, which may be subject to inflation caused by labor shortages, supply shortages and increased demand, and other inflationary pressures

●

our ability to secure adequate sour gas treating and/or sour gas take-away capacity, including the acid gas treatment facility for our Monument Draw area to handle production volumes and achieve anticipated reductions in the future costs of treating sour gas;

●

drilling and operating risks, including accidents, equipment failures, fires, and leaks of toxic or hazardous materials, such as hydrogen sulfide (H₂S), which can result in injury, loss of life, pollution, property damage and suspension of operations;

●

senior management’s ability to execute our plans to meet our goals;

●

access to and availability of water, sand and other treatment materials to carry out fracture stimulations in our completion operations;

●

the possibility that our industry may be subject to future regulatory or legislative actions (including additional taxes and changes in environmental regulations);

●

access to adequate gathering systems, processing and treating facilities and transportation take-away capacity to move our production to marketing outlets to sell our production at market prices;

●

the potential for production decline rates for our wells to be greater than we expect;

●

competition, including competition for acreage in our resource play;

●

environmental risks, such as accidental spills of toxic or hazardous materials, and the potential for environmental liabilities;

●

exploration and development risks;

●

our ability to retain key members of senior management, the board of directors and key technical employees;

●

social unrest, political instability or armed conflict in major oil and natural gas producing regions outside the United States, such as the conflict between Ukraine and Russia, and acts of terrorism or sabotage;

●

general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business, may be less favorable than expected, including the possibility that economic conditions

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in the United States will worsen and that capital markets are disrupted, which could adversely affect demand for oil and natural gas and make it difficult to access capital;

●

impacts and potential risks related to actual or anticipated pandemics, such as the novel coronavirus (COVID-19) pandemic, including how it has and may continue to impact our operations, financial results, liquidity, contractors, customers, employees and vendors;

●

other economic, competitive, governmental, regulatory, legislative, including federal and state regulations and laws, geopolitical and technological factors that may negatively impact our business, operations or oil and natural gas prices;

●

our insurance coverage may not adequately cover all losses that we may sustain; and

●

title to the properties in which we have an interest may be impaired by title defects.

All forward-looking statements are expressly qualified in their entirety by the cautionary statements in this paragraph and elsewhere in this document. Other than as required under the securities laws, we do not assume a duty to update these forward-looking statements, whether as a result of new information, subsequent events or circumstances, changes in expectations or otherwise.

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PART I. FINANCIAL INFORMATION

Item 1. Condensed Consolidated Financial Statements (Unaudited)

BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

(In thousands, except per share amounts)


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
Operating revenues:
Oil, natural gas and natural gas liquids sales:
Oil	$	46,168	$	73,944	$	100,383	$	136,468
Natural gas		2,060		14,759		4,960		23,640
Natural gas liquids		5,657		12,587		12,815		22,590
Total oil, natural gas and natural gas liquids sales		53,885		101,290		118,158		182,698
Other		387		221		1,256		415
Total operating revenues		54,272		101,511		119,414		183,113

Operating expenses:
Production:
Lease operating		11,365		11,909		23,056		23,433
Workover and other		2,634		1,383		3,969		2,248
Taxes other than income		3,180		5,372		6,370		10,323
Gathering and other		16,828		15,869		33,345		31,124
General and administrative		5,243		4,588		10,380		9,573
Depletion, depreciation and accretion		14,713		12,601		30,861		22,821
Total operating expenses		53,963		51,722		107,981		99,522
Income (loss) from operations		309		49,789		11,433		83,591

Other income (expenses):
Net gain (loss) on derivative contracts		4,473		(31,910)		23,946		(155,768)
Interest expense and other		(9,530)		(4,832)		(17,316)		(7,520)
Total other income (expenses)		(5,057)		(36,742)		6,630		(163,288)
Income (loss) before income taxes		(4,748)		13,047		18,063		(79,697)
Income tax benefit (provision)		—		—		—		—
Net income (loss)	$	(4,748)	$	13,047	$	18,063	$	(79,697)

Net income (loss) per share of common stock:
Basic	$	(0.35)	$	0.80	$	0.87	$	(4.88)
Diluted	$	(0.35)	$	0.79	$	0.86	$	(4.88)
Weighted average common shares outstanding:
Basic		16,457		16,338		16,425		16,320
Diluted		16,457		16,510		16,520		16,320

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

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BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

(In thousands, except share and per share amounts)


	June 30, 2023		December 31, 2022
Current assets:
Cash and cash equivalents	$	18,514	$	32,726
Accounts receivable, net		23,518		37,974
Assets from derivative contracts		9,611		16,244
Restricted cash		90		90
Prepaids and other		1,049		1,131
Total current assets		52,782		88,165
Oil and natural gas properties (full cost method):
Evaluated		727,347		713,585
Unevaluated		62,649		62,621
Gross oil and natural gas properties		789,996		776,206
Less - accumulated depletion		(420,964)		(390,796)
Net oil and natural gas properties		369,032		385,410
Other operating property and equipment:
Other operating property and equipment		4,674		4,434
Less - accumulated depreciation		(1,486)		(1,209)
Net other operating property and equipment		3,188		3,225
Other noncurrent assets:
Assets from derivative contracts		5,299		5,379
Operating lease right of use assets		162		352
Other assets		2,778		2,827
Total assets	$	433,241	$	485,358

Current liabilities:
Accounts payable and accrued liabilities	$	48,897	$	100,095
Liabilities from derivative contracts		15,480		29,286
Current portion of long-term debt		42,606		35,067
Operating lease liabilities		162		352
Asset retirement obligations		111		225
Total current liabilities		107,256		165,025
Long-term debt, net		164,055		182,676
Other noncurrent liabilities:
Liabilities from derivative contracts		17,406		33,649
Asset retirement obligations		15,741		15,244
Other		3,432		4,136
Commitments and contingencies (Note 9)
Temporary equity:
Series A redeemable convertible preferred stock: 25,000 shares of $.0001		26,030		—
par value authorized, issued and outstanding as of June 30, 2023
Stockholders' equity:
Common stock: 100,000,000 shares of $0.0001 par value authorized;
16,456,563 and 16,344,815 shares issued and outstanding as of
June 30, 2023 and December 31, 2022, respectively		2		2
Additional paid-in capital		331,201		334,571
Retained earnings (accumulated deficit)		(231,882)		(249,945)
Total stockholders' equity		99,321		84,628
Total liabilities, temporary equity and stockholders' equity	$	433,241	$	485,358

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

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BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (Unaudited)

(In thousands)


						Retained
				Additional		Earnings
	Common Stock			Paid-In		(Accumulated		Stockholders'
	Shares	Amount		Capital		Deficit)		Equity
Balances at December 31, 2022	16,345	$	2	$	334,571	$	(249,945)	$	84,628
Net income (loss)	—		—		—		22,811		22,811
Deemed dividends for Series A preferred stock	—		—		(1,492)		—		(1,492)
Long-term incentive plan vestings	159		—		—		—		—
Tax withholding on vesting of restricted stock units	(47)		—		(454)		—		(454)
Stock-based compensation	—		—		327		—		327
Balances at March 31, 2023	16,457		2		332,952		(227,134)		105,820
Net income (loss)	—		—		—		(4,748)		(4,748)
Deemed dividends for Series A preferred stock	—		—		(997)		—		(997)
Stock-based compensation	—		—		(754)		—		(754)
Balances at June 30, 2023	16,457		2		331,201		(231,882)		99,321

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

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BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (Unaudited)

(In thousands)


						Retained
				Additional		Earnings
	Common Stock			Paid-In		(Accumulated		Stockholders'
	Shares	Amount		Capital		Deficit)		Equity
Balances at December 31, 2021	16,274	$	2	$	332,187	$	(268,484)	$	63,705
Net income (loss)	—		—		—		(92,744)		(92,744)
Long-term incentive plan vestings	89		—		—		—		—
Tax withholding on vesting of restricted stock units	(26)		—		(461)		—		(461)
Stock-based compensation and other	—		—		452		—		452
Balances at March 31, 2022	16,337		2		332,178		(361,228)		(29,048)
Net income (loss)	—		—		—		13,047		13,047
Long-term incentive plan vestings	1		—		—		—		—
Tax withholding on vesting of restricted stock units	—		—		(6)		—		(6)
Stock-based compensation and other	—		—		594		—		594
Balances at June 30, 2022	16,338		2		332,766		(348,181)		(15,413)
Net income (loss)	—		—		—		105,888		105,888
Long-term incentive plan vestings	8		—		—		—		—
Tax withholding on vesting of restricted stock units	(2)		—		(25)		—		(25)
Stock-based compensation and other	—		—		893		—		893
Balances at September 30, 2022	16,344		2		333,634		(242,293)		91,343
Net income (loss)	—		—		—		(7,652)		(7,652)
Stock-based compensation and other	1		—		937		—		937
Balances at December 31, 2022	16,345	$	2	$	334,571	$	(249,945)	$	84,628

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

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BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(In thousands)


	Six Months Ended
	June 30,
	2023		2022
Cash flows from operating activities:
Net income (loss)	$	18,063	$	(79,697)
Adjustments to reconcile net income (loss) to net cash
provided by (used in) operating activities:
Depletion, depreciation and accretion		30,861		22,821
Stock-based compensation, net		(545)		857
Unrealized loss (gain) on derivative contracts		(23,336)		78,201
Amortization/accretion of financing related costs		3,843		1,807
Reorganization items		—		(744)
Accrued settlements on derivative contracts		(929)		14,652
Change in fair value of embedded derivative liability		(704)		(2,595)
Other income (expense)		53		(96)
Change in assets and liabilities:
Accounts receivable		15,965		(12,596)
Prepaids and other		81		438
Accounts payable and accrued liabilities		(34,703)		5,285
Net cash provided by (used in) operating activities		8,649		28,333

Cash flows from investing activities:
Oil and natural gas capital expenditures		(32,633)		(51,377)
Proceeds received from sale of oil and natural gas assets		1,189		—
Other operating property and equipment capital expenditures		(284)		(705)
Proceeds received from sale of other operating property and equipment		—		96
Other		(11)		—
Net cash provided by (used in) investing activities		(31,739)		(51,986)

Cash flows from financing activities:
Proceeds from borrowings		—		20,000
Repayments of borrowings		(15,043)		(85)
Payment of deferred debt financing costs		—		(379)
Proceeds from issuance of preferred stock		24,375		—
Other		(454)		(467)
Net cash provided by (used in) financing activities		8,878		19,069

Net increase (decrease) in cash, cash equivalents and restricted cash		(14,212)		(4,584)

Cash, cash equivalents and restricted cash at beginning of period		32,816		48,359
Cash, cash equivalents and restricted cash at end of period	$	18,604	$	43,775

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

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. FINANCIAL STATEMENT PRESENTATION

Basis of Presentation and Principles of Consolidation

Battalion is an independent energy company focused on the acquisition, production, exploration and development of onshore liquids-rich oil and natural gas assets in the United States. The consolidated financial statements include the accounts of all majority-owned, controlled subsidiaries. The Company operates in one segment which focuses on oil and natural gas acquisition, production, exploration and development. Allocation of capital is made across the Company’s entire portfolio without regard to operating area. All intercompany accounts and transactions have been eliminated.

These unaudited condensed consolidated financial statements reflect, in the opinion of the Company’s management, all adjustments, consisting of normal and recurring adjustments, necessary to present fairly the financial position as of, and the results of operations for, the periods presented. Interim period results are not necessarily indicative of results of operations or cash flows for the full year and accordingly, certain information normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States, has been condensed or omitted. During interim periods, Battalion follows the accounting policies disclosed in its Annual Report on Form 10-K, as filed with the United States Securities and Exchange Commission (SEC) on March 30, 2023. Please refer to the notes in the Annual Report on Form 10-K for the year ended December 31, 2022 when reviewing interim financial results. The Company has evaluated events or transactions through the date of issuance of these unaudited condensed consolidated financial statements.

Liquidity and Cash Requirements

The accompanying unaudited Condensed Consolidated Financial Statements are prepared in accordance with GAAP applicable to a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business.

Our ability to execute our operating strategy is dependent on our ability to maintain adequate liquidity and continue to access capital, as needed. Our current business estimates and forecasts indicate that we will require additional liquidity to continue our operations and meet our debt covenant requirements for the next 12 months from the issuance of these condensed consolidated financial statements. In response to these events and conditions, we have continued to execute on a plan to reduce operating and capital costs to improve cash flow, including recent reductions in headcount to align with planned drilling activity. The Company also has obtained a support letter from its three largest current related party investors to purchase additional preferred equity securities in an amount up to $38 million. The Company has provided notice to the investors of its intent to draw the $38 million in the third quarter of 2023 to enable the Company to meet its obligations as they become due through at least one year beyond the issuance of these financial statements. Management believes that based upon its operational forecasts, cash and cash equivalents on hand, cost reduction measures, and the additional $38 million in additional preferred equity expected to close in the third quarter of 2023, it is probable the Company will have sufficient liquidity to fund its operations, meet its continuous drilling obligations and debt payment requirements and maintain compliance with our future debt covenants, as described in Note 5, “Debt,” for the next 12 months from the issuance of these condensed consolidated financial statements.

Risk and Uncertainties

Supply chain issues. In periods of increasing commodity prices, the Company is at risk for supply chain issues, including, but not limited to, labor shortages, pipe restrictions and potential delays in obtaining frac and/or drilling related equipment that could impact our business. During these periods, the costs and delivery times of rigs, equipment and supplies may also be substantially greater. The unavailability or high cost of drilling rigs and/or frac crews, pressure pumping equipment, tubulars and other supplies, and of qualified personnel can materially and adversely affect our operations and profitability.

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Commodity Prices. Our financial results depend upon many factors, but are largely driven by the volume of our oil and natural gas production and the price that we receive for that production. Demand for oil and natural gas may be adversely impacted by macro-economic events, such as economic effects of rising interest rates, tightening monetary policies, as well as the price and availability of alternatives or other factors, while supply fluctuates based on controls imposed by oil exporting countries, social, labor and political unrest, armed conflict, terrorist attacks, weather conditions and other factors. As a consequence, the Company is unable to predict whether oil and natural gas prices will remain at current levels or will be adversely impacted by these or other factors. When commodity prices decline significantly, our ability to finance our capital budget and operations may be adversely impacted to the extent we have not hedged our production, and we may also be required to record non-cash impairment charges as further described in Note 4, “Oil and Natural Gas Properties”.

For further information regarding the actual and potential impacts of the supply chain issues and the potential impact of declines in commodity prices on the Company, see “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2022.

Use of Estimates

The preparation of the Company’s unaudited condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States requires the Company’s management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities, if any, at the date of the unaudited condensed consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Estimates and assumptions that, in the opinion of management of the Company, are significant include oil and natural gas revenue accruals, capital and operating expense accruals, oil and natural gas reserves, depletion relating to oil and natural gas properties, asset retirement obligations, and fair value estimates. The Company bases its estimates and judgments on historical experience and on various other assumptions and information believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be predicted with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the Company’s operating environment changes. Actual results may differ from the estimates and assumptions used in the preparation of the Company’s unaudited condensed consolidated financial statements.

Cash, Cash Equivalents and Restricted Cash

The Company considers all highly liquid short-term investments with a maturity of three months or less at the time of purchase to be cash equivalents. These investments are carried at cost, which approximates fair value. Amounts in the unaudited condensed consolidated balance sheets included in “Cash and cash equivalents” and “Restricted cash” reconcile to the Company’s unaudited condensed statements of cash flows as follows:


	June 30, 2023		December 31, 2022

Cash and cash equivalents	$	18,514	$	32,726
Restricted cash		90		90
Total cash, cash equivalents and restricted cash	$	18,604	$	32,816

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Restricted cash consists of funds to collateralize lines of credit.

Accounts Receivable and Allowance for Doubtful Accounts

The Company’s accounts receivable are primarily receivables from joint interest owners and oil and natural gas purchasers. Accounts receivable are recorded at the amount due, less an allowance for doubtful accounts, when applicable. Payment of our accounts receivable is typically received within 30-60 days. The Company’s historical credit losses have been de minimis and are expected to remain so in the future assuming no substantial changes to the business or creditworthiness of the Company’s counterparties.

Concentrations of Credit Risk

The Company’s primary concentrations of credit risk are the risks of uncollectible accounts receivable and of nonperformance by counterparties under the Company’s derivative contracts. Each reporting period, the Company assesses the recoverability of material receivables using historical data, current market conditions and reasonable and supportable forecasts of future economic conditions to determine expected collectability of its material receivables.

The Company’s exposure to credit risk under its derivative contracts is varied among major financial institutions with investment grade credit ratings, where it has master netting agreements which provide for offsetting of amounts payable or receivable between the Company and the counterparty. To manage counterparty risk associated with derivative contracts, the Company selects and monitors counterparties based on an assessment of their financial strength and/or credit ratings. At June 30, 2023, the Company’s derivative counterparties include two major financial institutions, both of which are secured lenders under the Amended Term Loan Agreement.

Recently Issued Accounting Pronouncements

In the first quarter of 2023, the Company early adopted Accounting Standards Update (“ASU”) ASU 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40) (“ASU 2020-06)”. The update simplifies the accounting for convertible debt instruments and convertible preferred stock by reducing the number of accounting models and limiting the number of embedded conversion features separately recognized from the primary contract. The guidance also includes targeted improvements to the disclosures for convertible instruments and earnings per share. The adoption of ASU 2020-06 did not have an impact on the Company’s financial statements.

2. LEASES

The Company leases equipment and office space pursuant to operating leases. We determine if an arrangement is or contains a lease at inception and combine lease and nonlease components, when fixed, for all lease contracts. Nonlease components include common area maintenance charges on office leases and, when applicable, services associated with equipment leases. Operating leases with a lease term greater than 12 months where the Company is the lessee are included in “Operating lease right of use assets” and “Operating lease liabilities” on the consolidated balance sheets and recorded based on the present value of the future minimum lease payments over the lease term. As most of the Company’s leases do not provide an implicit rate, the Company uses its incremental borrowing rate based on the information available at the commencement date to determine the present value of lease payments. The Company does not recognize right of use assets and lease liabilities for short-term leases that have a lease term of 12 months or less, but rather recognizes the lease payments associated with its short-term leases when incurred.

Payments due under the lease contracts include fixed payments plus, in some instances, variable payments. Variable lease payments, if applicable, associated with the Company’s leases are recognized when the event, activity, or

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circumstance in the lease agreement on which those payments are assessed occurs. Variable lease payments, when applicable, are presented as "Gathering and other” or "General and administrative” in the consolidated statements of operations in the same line item as the expense arising from the fixed lease payments on the operating leases.

The “Operating lease right of use assets” outstanding on the unaudited condensed consolidated balance sheets as of June 30, 2023 and December 31, 2022 have an initial lease term of 2.3 years. Payments due under the lease contracts include fixed payments plus, in some instances, variable payments. The table below summarizes the Company’s leases for the six months ended June 30, 2023 and 2022 (in thousands, except term and discount rate):


	Six Months Ended
	June 30,
	2023			2022
Lease cost
Operating lease costs	$	196		$	196
Short-term lease costs		375			4,003
Variable lease costs		—			—
Total lease costs	$	571		$	4,199

Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	196
Right-of-use assets obtained in exchange for new operating lease liabilities		—			—
Weighted-average remaining lease term - operating leases		0.4	years		1.4	years
Weighted-average discount rate - operating leases		4.29	%		4.29	%

Future minimum lease payments associated with the Company’s non-cancellable operating leases for office space as of June 30, 2023 are presented in the table below (in thousands):


	June 30, 2023
Remaining period in 2023	$	163
Thereafter		—
Total operating lease payments		163
Less: discount to present value		1
Total operating lease liabilities		162
Less: current operating lease liabilities		162
Noncurrent operating lease liabilities	$	—

3. OPERATING REVENUES

Substantially all of the Company’s revenues are derived from single basin operations, the Delaware Basin in Pecos, Reeves, Ward and Winkler Counties, Texas. Revenue is presented disaggregated in the statement of operations by major product, and depicts how the nature, timing, and uncertainty of revenue and cash flows are affected by economic factors in the Company’s single basin operations.

Revenue is recognized when the following five steps are completed: (1) identify the contract with the customer, (2) identify the performance obligation (promise) in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, (5) recognize revenue when the reporting organization satisfies a performance obligation. Revenues from the sale of crude oil, natural gas and natural gas liquids are recognized, at a point in time, when a performance obligation is satisfied by the transfer of control of each unit (e.g.

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barrel of oil, Mcf of gas) of commodity to the customer. Revenue is measured based on contract consideration allocated to each unit of commodity and excludes amounts collected on behalf of third parties. Taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction that are collected by the Company from a customer are excluded from revenue.

Since the Company’s performance obligations have been satisfied and an unconditional right to consideration exists as of the balance sheet date, the Company recognized amounts due from contracts with customers of $19.9 million and $34.0 million as of June 30, 2023 and December 31, 2022, respectively, as “Accounts receivable, net” on the unaudited condensed consolidated balance sheets. The Company utilizes the practical expedient exempting the disclosure of the transaction price of unsatisfied performance obligations for (i) contracts with an original expected duration of one year or less and (ii) contracts where variable consideration is allocated entirely to a wholly unsatisfied performance obligation (each unit of product typically represents a separate performance obligation, and therefore, future volumes under the Company’s long-term contracts are wholly unsatisfied).

For additional information regarding our operating revenues, refer to our Annual Report on Form 10-K for the year ended December 31, 2022.

4. OIL AND NATURAL GAS PROPERTIES

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and development of oil and natural gas reserves (including such costs as leasehold acquisition costs, geological expenditures, treating equipment and gathering support facilities costs, dry hole costs, tangible and intangible development costs and direct internal costs) are capitalized as the cost of oil and natural gas properties when incurred. To the extent capitalized costs of evaluated oil and natural gas properties, net of accumulated depletion, exceed the discounted future net revenues of proved oil and natural gas reserves, net of deferred taxes, such excess capitalized costs are charged to expense.

Additionally, the Company assesses all properties classified as unevaluated property on a quarterly basis for possible impairment. The Company assesses properties on an individual basis or as a group, if properties are individually insignificant. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate impairment, the cumulative drilling costs incurred to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost pool and are then subject to depletion and the full cost ceiling test limitation.

At June 30, 2023, and June 30, 2022, using first-day-of-the-month average West Texas Intermediate (WTI) crude oil spot prices and Henry Hub natural gas prices for the respective prior 12-month periods, the Company’s net book value of oil and natural gas properties at June 30, 2023 and June 30, 2022, did not exceed the ceiling test value of the Company’s reserves. Oil and natural gas prices utilized for the ceiling test calculations as of June 30, 2023 and June 30, 2022 were $83.23/bbl and $85.82/bbl of oil, respectively and $4.76/MMBtu and $5.13/MMBtu per MMBtu for natural gas, respectively.

Changes in commodity prices, production rates, levels of reserves, future development costs, transfers of unevaluated properties to the full cost pool, capital spending, and other factors will determine the Company’s ceiling test calculation and impairment analyses in future periods. Additionally, since oil and natural gas prices are inherently volatile, sustained lower commodity prices over a period of time could result in non-cash impairment charges of our oil and natural gas properties under our full cost ceiling test calculation which would result in a negative impact to our earnings and financial position.

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5. DEBT

As of June 30, 2023 and December 31, 2022, the Company’s debt consisted of the following (in thousands):


	June 30, 2023		December 31, 2022
Term loan credit facility	$	220,000	$	235,000
Other		265		190
Total debt (Face Value)		220,265		235,190
Less:
Current portion of long-term debt⁽¹⁾		(42,606)		(35,067)
Other⁽²⁾		(13,604)		(17,447)
Long-Term Debt, net	$	164,055	$	182,676

(1)	Amounts primarily reflect amortization payments under the Amended Term Loan Agreement due within one year.

(2)

Amounts primarily reflect unamortized debt issuance costs of approximately $9.9 million and $13.0 million at June 30, 2023 and December 31, 2022, respectively, but also includes remaining amounts to be accreted associated with the embedded derivative separately presented and further described in Note 6, “Fair Value Measurements”.

Term Loan Credit Facility

On November 24, 2021, the Company and its wholly owned subsidiary, Halcón Holdings, LLC (Borrower) entered into an Amended and Restated Senior Secured Credit Agreement (Term Loan Agreement) with Macquarie Bank Limited, as administrative agent, and certain other financial institutions party thereto, as lenders. On November 14, 2022, the Company paid approximately $2.4 million and entered into a further Amended Credit Agreement (the “Amended Term Loan Agreement”) with its lenders which modified certain provisions of its original Term Loan Agreement including, but not limited to, its Current Ratio financial covenant, interest rate benchmark, and prepayment premiums, all as further described below.

As of June 30, 2023, we had $220.3 million of indebtedness outstanding and approximately $1.4 million of letters of credit outstanding under the Amended Term Loan Agreement. Subsequent to June 30, 2023, the letters of credit were cancelled. We currently have $5.0 million available for the issuance of letters of credit. The maturity date of the Amended Term Loan Agreement is November 24, 2025. We have a variable interest rate on our borrowings based on the Secured Overnight Financing Rate (SOFR) plus 0.15% and increased the applicable margin on borrowings by 0.50%, such that borrowings under the Amended Term Loan Agreement bear interest at a rate per annum equal to the SOFR benchmark rate plus 7.65%. The weighted average interest rate on our borrowings for the quarter ended June 30, 2023 was approximately 12.6%.

The Company may elect, at its option, to prepay any borrowing outstanding under the Amended Term Loan Agreement subject to the following prepayment premiums:


Period (after applicable borrowing date⁽¹⁾)			Premium
Months 0-12			Make-whole amount equal to 12 months of interest plus 2.00%
Months 13-24			2.00%
Months 25-36			1.00%
Months 37-48			0.00%

(1)

Applicable borrowing dates are November 2021 for the original $200 million borrowed and April and November 2022 for the $20 million and $15 million in delayed draw borrowings, respectively.

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The Company may be required to make mandatory prepayments under the Amended Term Loan Agreement in connection with the incurrence of non-permitted debt, certain asset sales, or with cash on hand in excess of certain maximum levels beginning in 2023. For each fiscal quarter after January 1, 2023, the Company is required to make mandatory prepayments when the Consolidated Cash Balance, as defined in the Amended Term Loan Agreement, exceeds $20.0 million. Until December 31, 2024, the forecasted capital expenditures for the succeeding fiscal quarter on the approved plan of development (“APOD”) wells (i.e. oil and gas wells located within a specified boundary as set by our Amended Term Loan Agreement) are excluded for purposes of determining the Consolidated Cash Balance.

The Company is required to make scheduled remaining amortization payments in the aggregate amount of $105.0 million from the fiscal quarter ending September 30, 2023 through the fiscal quarter ending September 30, 2025. Amounts outstanding under the Amended Term Loan Agreement are guaranteed by certain of the Borrower’s direct and indirect subsidiaries and secured by substantially all of the assets of the Borrower and such direct and indirect subsidiaries, and by the equity interests of the Borrower held by the Company. As part of the Amended Term Loan Agreement there are certain restrictions on the transfer of assets, including cash, to Battalion from the guarantor subsidiaries.

The Amended Term Loan Agreement also contains certain financial covenants (as defined), including the maintenance of the following ratios:

●

Asset Coverage Ratio of not less than 1.80 to 1.00 as of June 30, 2023 and the last day of each fiscal quarter thereafter

●

Total Net Leverage Ratio of not greater than 2.50 to 1.00 as of June 30, 2023, and each fiscal quarter thereafter, and

●

Current Ratio of not less than 1.00 to 1.00, determined as of the last day of any fiscal quarter period, as of June 30, 2023 and for each fiscal quarter thereafter.

As of June 30, 2023, the Company was in compliance with the financial covenants under the Amended Term Loan Agreement.

The Amended Term Loan Agreement also contains an APOD for the Company’s Monument Draw acreage through the drilling and completion of certain wells. The Amended Term Loan Agreement contains a proved developed producing production test and an APOD economic test which the Company must maintain compliance with otherwise, subject to any available remedies or waivers, the Company is required to immediately cease making expenditures in respect of the APOD other than any expenditures deemed necessary by the Company in respect of no more than six additional APOD wells.

The Amended Term Loan Agreement also contains certain events of default, including non-payment; breaches of representations and warranties; non-compliance with covenants or other agreements; cross-default to material indebtedness; judgments; change of control; and voluntary and involuntary bankruptcy.

In conjunction with entering into the original Term Loan Agreement in November 2021, the Company agreed to pay a premium to the lenders upon a future change of control event in which a majority of the board of directors or the Chief Executive Officer or the Principal Financial Officer positions do not remain held by the same persons as before the change of control event (Change of Control Call Option). The premium is reduced over time through the payment of interest and certain fees. The Change of Control Call Option is accounted for as an embedded derivative not clearly and closely related to the host debt instrument. Accordingly, the Company recorded the initial fair value separately on the unaudited condensed consolidated balance sheet within “Other noncurrent liabilities” and records changes in the fair value of the embedded derivative each reporting period in “Interest expense and other” on the unaudited consolidated statements of operations. Refer to Note 6, “Fair Value Measurements,” for a discussion of the valuation approach used,

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the significant inputs to the valuation, and for a reconciliation of the change in fair value of the Change of Control Call Option.

6. FAIR VALUE MEASUREMENTS

The Company’s determination of fair value incorporates not only the credit standing of the counterparties involved in transactions with the Company resulting in receivables on the Company’s unaudited condensed consolidated balance sheets, but also the impact of the Company’s nonperformance risk on its own liabilities. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company separates the fair value of its financial instruments using a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy assigns the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Level 2 measurements are inputs that are observable for assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1. The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based on the observability of those inputs.

A financial instrument’s level within the fair value hierarchy is 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 fair value assets and liabilities and their placement within the fair value hierarchy levels. There were no transfers between fair value hierarchy levels for any period presented. The following tables set forth by level within the fair value hierarchy the Company’s financial assets and liabilities associated with commodity-based derivative contracts that were accounted for at fair value as of June 30, 2023 and December 31, 2022 (in thousands):


	June 30, 2023
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	14,910	$	—	$	14,910

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	32,886	$	—	$	32,886


	December 31, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	21,623	$	—	$	21,623

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	62,935	$	—	$	62,935

Derivative contracts listed above as Level 2 include fixed-price swaps, collars, basis swaps and WTI NYMEX rolls that are carried at fair value. The Company records the net change in the fair value of these positions in “Net gain (loss) on derivative contracts” in the Company’s unaudited condensed consolidated statements of operations. The Level 2 observable data includes the forward curves for commodity prices based on quoted market prices and implied volatility factors related to changes in the forward curves. See Note 7, “Derivative and Hedging Activities,” for additional discussion of derivatives.

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The Company’s derivative contracts are with major financial institutions with investment grade credit ratings which are believed to have minimal credit risk. As such, the Company is exposed to credit risk to the extent of nonperformance by the counterparties in the derivative contracts; however, the Company does not anticipate such nonperformance.

As discussed in Note 5, “Debt,” the Company reflects the fair value of the Change of Control Call Option separately on the unaudited condensed consolidated balance sheets and changes to the fair value of the embedded derivative each reporting period in “Interest expense and other” on the unaudited consolidated statements of operations. The valuation of the Change of Control Call Option includes significant inputs such as the timing and probability of discrete potential exit scenarios, forward interest rate curves, and discount rates based on implied and market yields. The following table sets forth a reconciliation of the changes in fair value of the Change of Control Call Option classified as Level 3 in the fair value hierarchy (in thousands):


	Change of Control
	Call Option
Balance at December 31, 2022	$	4,136
Change in fair value		(704)
Balance at June 30, 2023	$	3,432

Estimated fair value amounts have been determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, cash equivalents and restricted cash, accounts receivable, and accounts payable approximates their carrying value due to their short-term nature. The estimated fair value of borrowings under the Company’s Amended Term Loan Agreement approximates carrying value because the interest rates approximate current market rates.

The Company follows the provisions of ASC 820, for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. These provisions apply to the Company’s initial recognition of asset retirement obligations for which fair value is used. The asset retirement obligation estimates are derived from historical costs and management’s expectation of future cost environments; and therefore, the Company has designated these liabilities as Level 3. See Note 8, “Asset Retirement Obligations,” for a reconciliation of the beginning and ending balances of the liability for the Company’s asset retirement obligations.

7. DERIVATIVE AND HEDGING ACTIVITIES

The Company is exposed to commodity price risks relating to its ongoing business operations. In accordance with the Company’s policy and the requirements under the Term Loan Agreement, it generally hedges a substantial, but varying, portion of anticipated oil and natural gas production for future periods. Derivatives are carried at fair value on the unaudited condensed consolidated balance sheets as assets or liabilities, with the changes in the fair value included in the unaudited condensed consolidated statements of operations for the period in which the change occurs. The Company has elected not to designate any of its derivative contracts for hedge accounting. Accordingly, the Company records the net change in the mark-to-market valuation of these derivative contracts, as well as all payments and receipts on settled derivative contracts, in “Net gain (loss) on derivative contracts” on the unaudited condensed consolidated statements of operations. The Company’s hedge policies and objectives may change significantly as its operational profile changes. The Company does not enter into derivative contracts for speculative trading purposes.

It is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial or commodity hedging institutions deemed by management as competent and competitive market makers. As of June 30, 2023, the Company did not post collateral under any of its derivative contracts as they are secured under the Company’s Term Loan Agreement.

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The Company’s crude oil, and natural gas derivative positions at any point in time may consist of fixed-price swaps, costless put/call collars, basis swaps and WTI NYMEX rolls further described as follows:

●

Fixed-price swaps are designed so that the Company receives or makes payments based on a differential between fixed and variable prices for crude oil and natural gas.

●

Costless collars consist of a sold call, which establishes a maximum price the Company will receive for the volumes under contract and a purchased put that establishes a minimum price and are generally utilized less frequently by the Company than fixed-price swaps.

●

Basis swaps effectively lock in a price differential between regional prices (i.e. Midland) where the product is sold and the relevant pricing index under which the oil production is hedged (i.e. Cushing).

●

WTI NYMEX roll agreements account for pricing adjustments to the trade month versus the delivery month for contract pricing.

The following table summarizes the location and fair value amounts of all commodity derivative contracts in the unaudited condensed consolidated balance sheets as of June 30, 2023 and December 31, 2022 (in thousands):


Balance sheet location	June 30, 2023		December 31, 2022		Balance sheet location	June 30, 2023		December 31, 2022
Current assets	$	9,611	$	16,244	Current liabilities	$	(15,480)	$	(29,286)
Other noncurrent assets		5,299		5,379	Other noncurrent liabilities		(17,406)		(33,649)
	$	14,910	$	21,623		$	(32,886)	$	(62,935)

The following table summarizes the location and amounts of the Company’s realized and unrealized gains and losses on derivative contracts in the Company’s unaudited condensed consolidated statements of operations (in thousands):


	Location of net gain (loss)	Three Months Ended				Six Months Ended
	on derivative contracts on	June 30,				June 30,
Type	Statement of Operations	2023		2022		2023		2022
Commodity derivative contracts:
Unrealized gain (loss)	Other income (expenses)	$	2,332	$	12,837	$	23,336	$	(78,201)
Realized gain (loss)	Other income (expenses)		2,141		(44,747)		610		(77,567)
Total net gain (loss)		$	4,473	$	(31,910)	$	23,946	$	(155,768)

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At June 30, 2023, the Company had the following open crude oil and natural gas derivative contracts:


Instrument		2023		2024		2025		2026		2027
Crude oil:
Fixed-price swap:
Total volumes (Bbls)		1,115,335		1,805,885		1,240,171		936,741		198,000
Weighted average price	$	67.36	$	63.69	$	61.18	$	63.56	$	59.64
Basis swap:
Total volumes (Bbls)		1,047,536		1,801,951		1,240,171		936,741		198,000
Weighted average price	$	0.40	$	0.27	$	0.18	$	(0.01)	$	0.40
WTI NYMEX roll:
Total volumes (Bbls)		1,097,510		1,784,914		1,240,171		936,741		198,000
Weighted average price	$	0.51	$	0.27	$	0.12	$	(0.03)	$	—
Natural gas:
Fixed-price swap:
Total volumes (MMBtu)		2,925,851		4,423,784		3,687,113		1,979,033		—
Weighted average price	$	3.71	$	3.54	$	3.35	$	4.00	$	—
Two-way collar:
Total volumes (MMBtu)		1,082,869		2,610,639		1,651,321		2,063,812		900,000
Weighted average price (call)	$	5.21	$	5.08	$	5.12	$	5.26	$	5.75
Weighted average price (put)	$	3.76	$	3.67	$	3.72	$	3.70	$	4.25
Basis swap:
Total volumes (MMBtu)		4,008,720		7,034,372		5,319,878		4,042,845		900,000
Weighted average price	$	(0.89)	$	(0.87)	$	(0.67)	$	(0.77)	$	(0.78)

The Company presents the fair value of its derivative contracts at the gross amounts in the unaudited condensed consolidated balance sheets. The following table shows the potential effects of master netting arrangements on the fair value of the Company’s derivative contracts at June 30, 2023 and December 31, 2022 (in thousands):


	Derivative Assets				Derivative Liabilities
Offsetting of Derivative Assets and Liabilities	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022

Gross Amounts - Consolidated Balance Sheet	$	14,910	$	21,623	$	(32,886)	$	(62,935)
Amounts Not Offset - Consolidated Balance Sheet		(11,762)		(20,997)		11,762		20,997
Net Amount	$	3,148	$	626	$	(21,124)	$	(41,938)

The Company enters into an International Swap Dealers Association Master Agreement (ISDA) with each counterparty prior to a derivative contract with such counterparty. The ISDA is a standard contract that governs all derivative contracts entered into between the Company and the respective counterparty. The ISDA allows for offsetting of amounts payable or receivable between the Company and the counterparty, at the election of both parties, for transactions that occur on the same date and in the same currency.

8. ASSET RETIREMENT OBLIGATIONS

The Company records an asset retirement obligation (ARO) on oil and natural gas properties when it can reasonably estimate the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon costs. The Company records the ARO liability on the unaudited condensed consolidated balance sheets and capitalizes the cost in “Oil and natural gas properties” during the period in which the obligation is incurred. The Company records the accretion of its ARO liabilities in “Depletion, depreciation and accretion” expense in the unaudited condensed consolidated statements of operations. The additional capitalized costs are depreciated on a unit-of-production basis.

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The Company recorded the following activity related to its ARO liability (in thousands):


Liability for asset retirement obligations as of December 31, 2022	$	15,469
Accretion expense		372
Liabilities incurred during the period		11
Liability for asset retirement obligations as of June 30, 2023		15,852

9. COMMITMENTS AND CONTINGENCIES

Commitments

In May 2022, the Company entered into a joint venture agreement to develop a strategic acid gas treatment and carbon sequestration facility and entered into a gas treating agreement. The Company has a minimum volume commitment of 20,000 Mcf per day under the gas treating agreement, with certain rollover rights and start-up flexibility, for an initial term of five years from the in-service date of the facility. Under the gas treating agreement, the Company will pay a treating rate that begins at $1.65/Mcf and varies based on volumes delivered to the facility. At an initial treated volume of 12,000 Mcf/d, the commitment would be approximately $7.3 million for the first 12 months of the agreement. For additional information on this joint venture, see Note 13, “Additional Financial Information”.

The Company has entered into various long-term gathering, transportation and sales contracts with respect to its oil and natural gas production from the Delaware Basin in West Texas. As of June 30, 2023, the Company had in place multiple long-term crude oil and natural gas contracts in this area and the sales prices under these contracts are based on posted market rates. Under the terms of these contracts, the Company has committed a substantial portion of its production from this area for periods ranging from one to twenty years from the date of first production.

Contingencies

In addition to the matter described below, from time to time, the Company may be a plaintiff or defendant in a pending or threatened legal proceeding arising in the normal course of its business. While the outcome and impact of currently pending legal proceedings cannot be determined, the Company’s management and legal counsel believe that the resolution of these proceedings through settlement or adverse judgment will not have a material effect on the Company’s unaudited condensed consolidated operating results, financial position or cash flows.

Surface owners of properties in Louisiana, where the Company formerly operated, often file lawsuits or assert claims against oil and gas companies claiming that operators and working interest owners are liable for environmental damages arising from operations conducted on the leased properties. These damages are frequently measured by the cost to restore the leased properties to their original condition. Currently and in the past, the Company has been party to such matters in Louisiana. With regard to pending matters, the overall exposure is not currently determinable. The Company intends to vigorously oppose these claims.

10. REDEEMABLE CONVERTIBLE PREFERRED STOCK

Overview. On March 28, 2023, we received $24.4 million in proceeds (net of $0.6 million in original issue discount) from the sale of 25,000 shares of Series A Redeemable Convertible Preferred Stock (the “preferred stock”) in a private placement to certain funds managed by Luminus Management, LLC, Oaktree Capital Management, LP, and LSP Investment Advisors, LLC, our largest three existing shareholders (“Holders”). Each of these three largest stockholders has an employee that has been elected to and serves on our board of directors, comprised of six members. The issuance of preferred stock was approved by our board of directors upon recommendation by a special committee of disinterested directors that was established to evaluate the proposed terms of the preferred stock.

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For accounting purposes, upon issuance of the preferred stock on March 28, 2023, we recorded $23.5 million ($25.0 million net of original issue discount and accrued offering costs) as mezzanine equity (temporary equity) on the condensed consolidated balance sheets because it is not mandatorily redeemable but does contain a redemption feature at the option of the preferred holders that is considered not solely within the company’s control. Due to the redeemable nature of the preferred stock as further discussed below, at March 31, 2023, we recorded a non-cash deemed dividend of approximately $1.5 million to increase the carrying value of the preferred stock to its redemption amount of approximately $25 million.

On June 30, 2023, the Company paid-in-kind (PIK) its dividend on the preferred stock for $1.0 million. As of June 30, 2023, the carrying value of the preferred stock equals its redemption amount, inclusive of PIK dividends of approximately $26.0 million.

Voting Rights. Holders of preferred stock have no voting rights with respect to the shares of preferred stock.

Dividends. Holders of preferred stock are entitled to receive cumulative dividends at a fixed rate of 14.5% per annum on the Liquidation Preference ($1,000 per share, or $25.0 million, increased for any PIK accruals), compounding and accruing quarterly in arrears. Dividends may be paid in cash or, if not declared and paid in cash, the amount of any such dividend shall automatically accrue (a “PIK Accrual”) at a fixed rate of 16.0% per annum on the Liquidation Preference and be added to the Liquidation Preference. Currently, the Company’s Amended Term Loan Agreement prohibits the payment of cash dividends. Additionally, while the Company has not declared or paid dividends on its common stock since its inception, holders of preferred stock will be entitled to participate in any dividends or permitted distributions to holders of common stock on an as-converted basis should they occur.

Conversion Features. In addition to the conversion rights noted in “Redemption Features (Change of Control)” below, Holders of preferred stock may convert their shares into common stock at a conversion ratio (the “Conversion Ratio”) equal to the then applicable Liquidation Preference at the time of conversion divided by the then applicable Conversion Price (initially equal to an 18% premium to the volume weighted average price of common stock for the 20 trading days immediately preceding the closing date). Additionally, the Company has the right, at its option, to convert outstanding shares of preferred stock into common stock at the Conversion Ratio should the Company meet certain calculated valuation metrics which when divided by the number of outstanding shares of common stock equals or exceeds 130% of the Conversion Price.

Redemption Features (Issuer). The Company has the option to redeem the preferred stock in cash for an amount per share of Preferred Stock equal to (the “Redemption Price”):

●

at any time prior to 120 days following the closing date, 100% of the Liquidation Preference at such time;

●

at any time on or after 120 days following the closing date but prior to the 180 days following the closing date, 102% of the Liquidation Preference at such time;

●

at any time on or after 180 days following the closing date but on or prior to the first anniversary of the closing date, 105% of the Liquidation Preference at such time;

●

at any time after the first anniversary of the closing date but on or prior to the second anniversary of the closing date, 108% of the Liquidation Preference at such time; and

●

at any time after the second anniversary of the closing date, 120% of the Liquidation Preference at such time.

Redemption Features (Change of Control). In the event of a change of control, holders have the right to receive:

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

●

at any time on or prior to 150 days following the issuance date, and at the election of the Company, a cash payment equal to the Liquidation Preference or equity consideration equal to the 107.5% of the Liquidation Preference, or

●

at any time after the one hundred fiftieth (150th) day following the issuance date, the Company shall offer each Holder a cash payment equal to the Redemption Price. Holders shall also have the ability to elect conversion into common stock at the Conversion Ratio. Until (i) a termination of or certain amendments to the Amended Term Loan Agreement or (ii) one year past the maturity date of the Amended Term Loan Agreement, an election of the cash payment option by holders in a change of control scenario is not permitted.

11. STOCKHOLDERS’ EQUITY

Incentive Plans

The Company’s board of directors adopted the 2020 Long-Term Incentive Plan (the Plan), as amended in 2021, in which an aggregate of approximately 1.8 million shares of the Company’s common stock were available for grant pursuant to awards under the Plan. As of June 30, 2023, a maximum of 0.6 million of the Company’s common stock remained reserved for issuance under the Plan. For the six months ended June 30, 2023 and 2022, the Company recognized expense of ($0.5) million and $0.9 million, respectively, related to stock-based-compensation awards granted to employees and directors, including grants of stock options and restricted stock. The negative amount recognized in the six months ended June 30, 2023 is due to forfeitures of stock options and restricted stock related to the departure of the prior CEO. Stock-based compensation expense is recorded as a component of "General and administrative" on the unaudited condensed consolidated statements of operations.

Restricted Stock

From time to time, the Company grants shares of restricted stock units (RSUs) under the Plan to employees of the Company. Under the Plan, employee RSUs will vest and convert to shares in equal amounts typically over a three or four year vesting period from the date of the grant, depending on award, or when the performance or market conditions occur as described further described in our Annual Report on Form 10-K for the year ended December 31, 2022.

During the six months ended June 30, 2023, the Company granted less than 0.1 million shares of RSUs at a weighted average grant date fair value of $10.68 per share. At June 30, 2023, the Company had $1.3 million of unrecognized compensation expense related to non-vested RSU awards to be recognized over a weighted average period of less than 1 year.

Stock Options

From time to time, the Company has granted stock options under the Plan covering shares of common stock to employees of the Company. Stock options, when exercised, are settled through the payment of the exercise price in exchange for new shares of stock underlying the option. Awards granted under the Plan typically vest over a four year period at a rate of one-fourth on the annual anniversary date of the grant and expire seven years from the date of grant. No stock options have been granted during 2022. At June 30, 2023, the Company had less than $0.1 million of unrecognized compensation expense related to non-vested stock options to be recognized over a weighted-average period of less than 1 year.

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

12. EARNINGS PER SHARE

The following represents the calculation of earnings (loss) per share (in thousands, except per share amounts):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
Basic:
Net income (loss)	$	(4,748)	$	13,047	$	18,063	$	(79,697)
Less: Preferred stock dividend		(997)		—		(2,489)		—
Less: Undistributed earnings allocable to preferred shareholders		—		—		(1,301)		—
Net income (loss) available to common stockholders	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Basic net income (loss) per share of common stock	$	(0.35)	$	0.80	$	0.87	$	(4.88)

Diluted:
Net income (loss) available to common stockholders basic	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Reallocation of undistributed earnings		—		—		7		—
Net income (loss) available to common stockholders diluted	$	(5,745)	$	13,047	$	14,280	$	(79,697)

Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Common stock equivalent shares representing shares issuable upon:
Exercise of warrants and stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		Anti-dilutive		172		95		Anti-dilutive
Weighted average diluted number of common shares outstanding diluted		16,457		16,510		16,520		16,320
Diluted net income (loss) per share of common stock	$	(0.35)	$	0.79	$	0.86	$	(4.88)

We compute earnings per share in accordance with ASC Topic 260, Earnings per Share ("ASC 260"), which requires earnings per share for each class of stock (common stock and participating preferred stock) to be calculated using the two-class method which allocates earnings for the reporting period between common shareholders and other security holders based on their respective participation rights in undistributed earnings. Diluted EPS was calculated using the two-class method, as this computation was more dilutive than the calculation using the if-converted method. For additional information on our Series A redeemable convertible preferred stock, which is considered a participating security, see Note 10, “Redeemable Convertible Preferred Stock”.

For the three and six months ended June 30, 2023, common stock equivalents, including options and restricted stock units, totaling 0.6 million and 0.5 million, respectively were anti-dilutive and not included in the computation of diluted earnings per share of common stock. For the three and six months ended June 30, 2022, common stock equivalents, including warrants, options and restricted stock units, totaling 7.4 million and 7.7 million, respectively, were not included in the computation of diluted earnings per share of common stock because the effect would have been anti-dilutive.

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

13. ADDITIONAL FINANCIAL STATEMENT INFORMATION

Certain balance sheet amounts are comprised of the following (in thousands):


	June 30, 2023		December 31, 2022
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	19,853	$	33,980
Joint interest accounts		1,779		3,201
Other		1,886		793
	$	23,518	$	37,974
Prepaids and other:
Prepaids	$	509	$	715
Funds in escrow		343		341
Other		197		75
	$	1,049	$	1,131
Other assets (Non-current):
Investment in unconsolidated affiliate⁽¹⁾	$	1,477	$	1,561
Oil, natural gas and natural gas liquids revenues		24		—
Funds in escrow		538		527
Other		739		739
	$	2,778	$	2,827
Accounts payable and accrued liabilities:
Trade payables	$	17,884	$	42,919
Accrued oil and natural gas capital costs		1,928		19,911
Revenues and royalties payable		20,392		26,759
Accrued interest expense		104		160
Accrued employee compensation		1,190		2,300
Accrued lease operating expenses		7,388		8,005
Other		11		41
	$	48,897	$	100,095

(1)

In May 2022, we entered into a joint venture with Caracara Services, LLC (“Caracara”) to develop an acid gas treatment facility to remove hydrogen sulfide and carbon dioxide from our produced natural gas. Caracara will provide all necessary capital for the construction of the treatment facility. We contributed certain full cost pool assets to the related party joint venture in a non-cash exchange for a retained 5% equity interest in BAT, an unconsolidated subsidiary. For accounting purposes, since we do not control the key activities (e.g. operating and maintaining the facility) which most significantly impact economic performance nor do we have the obligation to absorb losses or the right to receive benefits that could potentially be significant, we are not the primary beneficiary of BAT. Accordingly, we account for our investment in BAT (a related party) using the equity method of accounting based on our ability to exercise significant influence, but not control, over the key activities of the joint venture. For more information related to this joint venture, see Note 9, “Commitments and Contingencies”.

(2)

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion is intended to assist in understanding our results of operations for the three and six months ended June 30, 2023 and 2022 and should be read in conjunction with our unaudited condensed consolidated financial statements and the notes thereto included in this Quarterly Report on Form 10-Q and with the consolidated financial statements, notes and management’s discussion and analysis of financial condition and results of operations included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022. The results presented in this Form 10-Q are not necessarily indicative of future operating results.

Statements in this discussion may be forward-looking. These forward-looking statements involve risks and uncertainties, including those discussed below, which could cause actual results to differ from those expressed. For more information, see “Special note regarding forward-looking statements.”

Overview

We are an independent energy company focused on the acquisition, production, exploration and development of onshore liquids-rich oil and natural gas assets in the United States. Our properties and drilling activities are currently focused in the Delaware Basin, where we have an extensive drilling inventory that we believe offers attractive long-term economics.

Our financial results depend upon many factors, but are largely driven by the volume of our oil and natural gas production and the price that we receive for that production. Our production volumes will decline as reserves are depleted unless we expend capital in successful development and exploration activities or acquire properties with existing production. The amount we realize for our production depends predominantly upon commodity prices, which are affected by changes in market demand and supply, as impacted by overall economic activity, attempts by foreign oil and gas producers to control the global supply, weather, transportation take-away capacity constraints, inventory storage levels, basis differentials and other factors. Accordingly, finding, developing and producing oil and natural gas reserves at economical costs are critical to our long-term success.

When commodity prices decline significantly our ability to finance our capital budget and operations may be adversely impacted. While we use derivative instruments to provide partial protection against declines in oil and natural gas prices, the total volumes we hedge are less than our expected production, vary from period to period based on our view of current and future market conditions, remain consistent with the requirements in effect under our Amended Term Loan Agreement and extend, on a rolling basis, for the next four years. These limitations result in our liquidity being susceptible to commodity price declines. Additionally, while intended to reduce the effects of volatile commodity prices, derivative transactions may limit our potential gains and increase our potential losses if commodity prices were to rise substantially over the price established by the hedge. Our hedge policies and objectives may change significantly as our operational profile changes and/or commodities prices change. We do not enter into derivative contracts for speculative trading purposes.

Recent Developments

Preferred Stock Equity Issuance. On March 28, 2023, we sold, in a private placement, an aggregate of 25,000 shares of Series A Convertible Preferred Stock (the “preferred stock”) to certain funds managed by Luminus Management, LLC, Oaktree Capital Management, LP, and LSP Investment Advisors, LLC, who represent our largest three existing shareholders. We received $24.4 million in proceeds, net of $0.6 million in original issue discount. The issuance of preferred stock was approved by our board of directors upon recommendation by a special committee of disinterested directors that was established to evaluate the proposed terms of the preferred stock. Holders have no voting rights with respect to the shares of preferred stock. The preferred stock is entitled to annual dividends, paid either in cash at a fixed rate of 14.5% annually or accrued (“PIK accrual”) at a fixed rate of 16.0% annually at the option of the Company. Currently, the Company’s Amended Term Loan Agreement prohibits the payment of cash dividends. PIK dividends will be cumulative, compound and accrue quarterly in arrears and will be added to the Liquidation Preference.

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Shares of preferred stock are convertible, subject to conversion ratios and prices stipulated in the agreement, at any time by the holders and by Battalion after meeting certain other agreement requirements. Battalion also has the right to redeem the preferred stock in cash at an amount equal to between 100-120% of the Liquidation Preference

($1,000 per share, or $25.0 million, increased for any PIK accruals) determined according to the redemption date. Additionally, in the event of a change of control, holders have the right to receive, (i) at any time on or prior to 150 days following the closing date, and at the election of the Company, a cash payment equal to the Liquidation Preference or equity consideration equal to the 107.5% of the Liquidation Preference, or (ii) at any time after 150 days following the closing date, a cash payment equal to between 100-120% of the Liquidation Preference determined by the redemption date or conversion into common stock. Until (i) a termination of or certain amendments to the Amended Term Loan Agreement or (ii) one year past the maturity date of the Amended Term Loan Agreement, an election of the cash payment option by holders in a change of control scenario is not permitted. For additional information, see Note 10, “Redeemable Convertible Preferred Stock”.

H2S Treating Joint Venture. In May 2022, we entered into a joint venture agreement with Caracara Services, LLC (“Caracara”) to develop a strategic acid gas treatment and carbon sequestration facility (the “Facility”) in Winkler County, Texas. The joint venture, operating as Brazos Amine Treater, LLC (“BAT”), has also entered into a Gas Treating Agreement (“GTA”) with us for gas production from our Monument Draw area. In exchange for contributing to the joint venture a wellbore with an approved permit for the injection of acid gas and surface land, we retained a 5% equity interest in BAT, an unconsolidated subsidiary. Caracara provided all necessary capital for the construction of the Facility, which is expected to have an initial capacity of approximately 30 MMcf per day, and a design capacity to treat up to 10% combined concentrations for H2S and CO2. During commissioning and initial operations, it was determined that additional pressure was required to initiate gas injection. To correct this issue, a positive displacement pump was ordered and is currently onsite and being installed. The Facility’s injection well also experienced pressure communication between the tubing and annular space after an injection procedure. The Company has commenced workover operations to remediate this issue and is exploring alternatives in the event such efforts prove inadequate. The Company’s current forecast assumes the Acid Gas Injection (“AGI”) facility will be processing 20,000 mcf gas per day in October 2023. It is possible that the existing remedial well work could extend past this estimate. Any delays in commissioning past October 2023 will result in higher processing fees than currently forecast until such time the facility comes online.

Under the GTA, we will pay a treating rate that varies based on volumes delivered to the Facility for a term that will last 20 years from the in-service date of the Facility and have a minimum volume commitment of 20 MMcf per day, with certain rollover rights and start-up flexibility, for an initial term of five years from the in service date of the Facility, which can be extended up to seven years under certain conditions. Once in service, the GTA has a tiered-rate structure which is expected to drive a greater than 50 percent reduction in treating fees. Our current estimates of facility in-service dates and future treating fee reductions are subject to various operational and other risk factors, some of which are beyond our control, which could impact the timing and extent of these estimates.

Capital Resources and Liquidity

Overview. Our ability to execute our operating strategy is dependent on our ability to maintain adequate liquidity and access additional capital, as needed. Our future capital resources and liquidity depend, in part, on our success in developing our leasehold interests, growing our reserves and production and finding additional reserves. Sufficient levels of available cash are required to fund capital expenditures necessary to offset inherent declines in our production and proven reserves. As of June 30, 2023, we had $18.5 million of cash and cash equivalents, no additional borrowing capacity under the Amended Term Loan and $20 million of debt repayments due during the remainder of 2023 and a total of $105 million due through September 2025.

In November 2022, we were required to seek an amendment to our Term Loan to alleviate Current Ratio covenant compliance requirements through the first quarter of 2023 as a result of reduced commodity prices, higher interest rates, and the high capital costs experienced in our 2022 drilling program, which are by nature difficult to predict and subject to factors outside the Company’s control. In the first quarter of 2023, commodity prices, cost conditions and interest rates continued to deteriorate, which further constrained our liquidity. As a result, we projected near-term future covenant (Current Ratio) breaches beginning with the first quarter of 2023, coupled with inadequate liquidity resources

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available to fully fund all of our upcoming obligations, including debt repayments and interest, capital expenditures and operating costs. In the absence of additional liquidity from other sources with agreeable economic terms, we obtained $24.4 million of additional preferred equity funding from our three largest existing shareholders.

Changes to our current business estimates and forecasts, based primarily on recent reductions in commodity prices and modifications to our planned drilling schedule to achieve better overall well economics, indicate that we will require additional liquidity to continue our operations and meet our debt covenant requirements for the next 12 months from the issuance of these condensed consolidated financial statements. In response to these events and conditions, we have continued to execute on a plan to reduce operating and capital costs to improve cash flow, including a reduction in headcount in April 2023 to align with planned drilling activity. The Company also has obtained a support letter from its three largest current investors to purchase up to $38 million of additional preferred equity securities. The Company has provided notice to the investors of its intent to draw the $38 million in the third quarter of 2023 to enable the Company to meet its obligations as they become due through at least one year beyond the issuance of these financial statements. Management believes that based upon its operational forecasts, cash and cash equivalents on hand, cost reduction measures, and the additional $38 million in additional preferred equity expected to close in the third quarter of 2023, it is probable the Company will have sufficient liquidity to fund its operations, meet its debt requirements and maintain compliance with our future debt covenants as described in Note 5, “Debt,” for the next 12 months from the issuance of these condensed consolidated financial statements. We will, however, continue to pursue alternative liquidity sources which could include entering into other financing arrangements (e.g. future equity raises), a sale of a portion of our non-core assets, seeking capital partners for our drilling program, pursuing strategic merger opportunities or joint ventures, or pursuing additional general and administrative or other cost reduction opportunities. The Company’s estimates and forecasts are based upon assumptions that may prove to be incorrect due to many factors that are currently unknown, such as prevailing economic conditions, many of which are beyond our control. In the event the assumptions underlying our estimates and forecasts prove to be incorrect, our operating plans, capital requirements, and covenant compliance may be adversely impacted.

We continuously monitor changes in market conditions and will continue to adapt our operational and capital plans as necessary to strive to maintain sufficient liquidity, meet our drilling requirements, and selectively develop or expand our acreage position, while meeting our debt obligations and maintaining compliance with our restrictive covenants. The Company has been, and continues to, explore strategic transactions to address these concerns, while also looking at opportunities to significantly reduce expenses in the near term. In this regard, the Company continues to consider whether it is advisable to continue to bear the ongoing costs of the listing of its common stock on the NYSE American and of being a reporting Company under the Securities Exchange Act of 1934. The Company believes that it currently qualifies to suspend these obligations should it elect to do so. While such a determination has not yet been made, the Company expects that the cost savings, particularly over the longer term, would be significant. Accordingly, the Company will continue to consider the matter while it simultaneously pursues strategic and financial alternatives that may render it unnecessary. However, there can be no assurance that, absent additional capital, reducing costs or other material favorable developments, the Company will not experience liquidity and covenant compliance issues in the future.

Other Risks and Uncertainties. Our ability to complete transactions and maintain or increase our liquidity is subject to a number of variables, including our level of oil and natural gas production, proved reserves and commodity prices, the amount and cost of our indebtedness, as well as various economic and market conditions that have historically affected the oil and natural gas industry. Even if we are otherwise successful in growing our proved reserves and production, if oil and natural gas prices decline for a sustained period of time, our ability to fund our capital expenditures, complete acquisitions, reduce debt, meet our financial obligations and become profitable may be materially impacted.

Additionally, particularly in periods of increasing commodity prices, we continue to be at risk to supply chain issues, including, but not limited to, labor shortages, pipe restrictions and potential delays in obtaining frac and/or drilling related equipment that could impact our business. During these periods, the costs and delivery times of rigs, equipment and supplies may also be substantially greater. The unavailability or high cost of drilling rigs and/or frac crews, pressure pumping equipment, tubulars and other supplies, and of qualified personnel can materially and adversely affect our operations and profitability.

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Lastly, actual or anticipated declines in domestic or foreign economic activity or growth rates, regional or worldwide increases in tariffs or other trade restrictions, turmoil affecting the U.S. or global financial system and markets and a severe economic contraction either regionally or worldwide, resulting from international conflicts, efforts to contain the COVID-19 pandemic or other factors, could materially affect our business and financial condition and impact our ability to finance operations by worsening the actual or anticipated future drop in worldwide oil demand, negatively impacting the price received for oil and natural gas production or adversely impacting our ability to comply with covenants in our Amended Term Loan Agreement. Negative economic conditions could also adversely affect the collectability of our trade receivables or performance by our vendors and suppliers or cause our commodity hedging arrangements to be ineffective if our counterparties are unable to perform their obligations. All of the foregoing may adversely affect our business, financial condition, results of operations, cash flows and, potentially, compliance with the covenants contained in our Amended Term Loan Agreement.

Debt Obligations. On November 24, 2021, we and our wholly owned subsidiary, Halcón Holdings, LLC (Borrower) entered into the Term Loan Agreement with Macquarie Bank Limited, as administrative agent, and certain other financial institutions party thereto, as lenders.

On November 14, 2022, the Company paid approximately $2.4 million and entered into a further Amended Credit Agreement (the “Amended Term Loan Agreement”) with its lenders which modified certain provisions of its original Term Loan Agreement including, but not limited to, its Current Ratio financial covenant, interest rate benchmark, and prepayment premiums, all as further described below.

As of June 30, 2023, we had $220.3 million of indebtedness outstanding and approximately $1.4 million of letters of credit outstanding under the Amended Term Loan Agreement. We currently have $5.0 million available for the issuance of letters of credit. The maturity date of the Amended Term Loan Agreement is November 24, 2025. We have a variable interest rate on our borrowings based on the Secured Overnight Financing Rate (SOFR) plus 0.15% and increased the applicable margin on borrowings by 0.50%, such that borrowings under the Amended Term Loan Agreement bear interest at a rate per annum equal to the SOFR benchmark rate plus 7.65%. The weighted average interest rate on our borrowings for the quarter ended June 30, 2023 was approximately 12.6%.

Our Amended Term Loan Agreement contains a mandatory repayment schedule ($10 million due at the end of each of the third and fourth quarter in 2023 and first quarter of 2024, $12.5 million at the end of the quarter ended September 30, 2024, and in the aggregate, $105.0 million due from the fiscal quarter ending June 30, 2023 through the fiscal quarter ending September 30, 2025). Amounts outstanding under the Amended Term Loan Agreement are guaranteed by certain of the Borrower’s direct and indirect subsidiaries and secured by a security interest in substantially all of the assets of the Borrower and such direct and indirect subsidiaries, and all of the equity interests of the Borrower held by us. As part of the Amended Term Loan Agreement there are certain restrictions on the transfer of assets, including cash, to Battalion from the guarantor subsidiaries.

The Company may elect, at its option, to prepay any borrowing outstanding under the Amended Term Loan Agreement subject to the following prepayment premiums:


Period (after applicable borrowing date⁽¹⁾)			Premium
Months 0-12			Make-whole amount equal to 12 months of interest plus 2.00%
Months 13-24			2.00%
Months 25-36			1.00%
Months 37-48			0.00%

(1)

Applicable borrowing dates are November 2021 for the original $200 million borrowed and April and November 2022 for the $20 million and $15 million in delayed draw borrowings, respectively.

We may be required to make mandatory prepayments of the loans under the Amended Term Loan Agreement in connection with the incurrence of non-permitted debt, certain asset sales, or with cash on hand in excess of certain maximum levels beginning in 2023. For each fiscal quarter after January 1, 2023, we are required to make mandatory prepayments when our Consolidated Cash Balance, as defined in the Amended Term Loan Agreement, exceeds $20.0

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million. Until December 31, 2024, the forecasted APOD capital expenditures for the succeeding fiscal quarter are excluded for purposes of determining the Consolidated Cash Balance.

The Amended Term Loan Agreement also contains certain financial covenants (as defined), including the maintenance of the following ratios:

●

Asset Coverage Ratio of not less than 1.80 to 1.00 as of June 30, 2023 and each fiscal quarter thereafter

●

Total Net Leverage Ratio of not greater than 2.50 to 1.00 as of June 30, 2023, and each fiscal quarter thereafter, and

●

Current Ratio of not less than 1.00 to 1.00, determined as of the last day of any fiscal quarter period, as of June 30, 2023 and for each fiscal quarter thereafter.

As of June 30, 2023, the Company was in compliance with the financial covenants under the Term Loan Agreement.

The Amended Term Loan Agreement also contains an APOD for our Monument Draw acreage through the drilling and completion of certain wells. The Amended Term Loan Agreement contains a proved developed producing production test and an APOD economic test which we must maintain compliance with otherwise, subject to any available remedies or waivers, we are required to immediately cease making expenditures in respect of the approved plan of development other than any expenditures deemed necessary by us in respect of no more than six additional approved plan of development wells.

Changes in the level and timing of our production, drilling and completion costs, the cost and availability of transportation for our production and other factors varying from our expectations can affect our ability to comply with the covenants under our Amended Term Loan Agreement. As a consequence, we endeavor to anticipate potential covenant compliance issues and work with our lenders under our Amended Term Loan Agreement to address any such issues ahead of time.

While we have been largely been successful in obtaining modifications of our covenants as needed, as evidenced most recently by the amendment of our Term Loan Agreement in November 2022 which reduced the Current Ratio covenant as of September 30, 2022 and each successive quarter through the quarter ended June 30, 2023, there can be no assurance that we will be successful in the future. In the event we are not successful in obtaining future modifications or amendments to our covenants, if needed, there is no assurance that we will be successful in implementing alternatives that allow us to maintain compliance with our covenants or that we will be successful in obtaining alternative financing that provides us with the liquidity that we need to operate our business. Even if successful, alternative sources of financing could prove more expensive than borrowings under our Amended Term Loan Agreement.

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Cash Flow

Net increase (decrease) in cash and cash equivalents is summarized as follows (in thousands):


	Six Months Ended
	June 30,
	2023		2022

Cash flows provided by (used in) operating activities	$	8,649	$	28,333
Cash flows provided by (used in) investing activities		(31,739)		(51,986)
Cash flows provided by (used in) financing activities		8,878		19,069
Net increase (decrease) in cash, cash equivalents and restricted cash	$	(14,212)	$	(4,584)

Operating Activities. Net cash flows provided by operating activities for the six months ended June 30, 2023 and 2022, respectively were $8.6 million and $28.3 million. Items impacting operating cash flows were (i) lower total operating revenues resulting from an approximate $24.83 per Boe decrease in average realized prices (excluding the impact of hedging arrangements) for the six months ended June 30, 2023 compared to the six months ended June 30, 2022, partially offset by increased production in the first half of 2023 as well as the impact of settled derivative contracts period over period, (ii) increased operating and interest costs in 2023 and (iii) changes in working capital.

Investing Activities. Net cash flows used in investing activities for the six months ended June 30, 2023 and 2022 were approximately $31.7 million and $52.0 million, respectively, primarily for drilling and completion activities.

During the six months ended June 30, 2023, we spent $32.6 million on oil and natural gas capital expenditures, of which $28.1 million related to drilling and completion costs and $3.8 million related to the development of our treating equipment and gathering support infrastructure. During the first half of 2023, our cash capital expenditures included amounts related to the drilling and completion activities that occurred in the fourth quarter of 2022. In the first six months of 2023, we ran one operated rig in the Delaware Basin and completed and put online one operated well. We also received $1.2 million in proceeds from the sale of oil and natural gas assets that were deemed to be unnecessary for future operations.

During the six months ended June 30, 2022, we spent $51.4 million on oil and natural gas capital expenditures, of which $45.7 million related to drilling and completion costs and $3.8 million related to the development of our treating equipment and gathering support infrastructure.

Financing Activities. Net cash flows provided by financing activities for the six months ended June 30, 2023 and 2022 were $8.9 million and $19.1 million, respectively. During the six months ended June 30, 2023, we received $24.4 million from our Series A preferred stock equity issuance and repaid $15.0 million under our Amended Term Loan Agreement. During the six months ended June 30, 2022, we borrowed $20.0 million under the first delayed draw of the Tern Loan Agreement.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations are based upon the unaudited condensed consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. Preparation of these unaudited condensed consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. There have been no material changes to our critical accounting policies from those described in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022.

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Results of Operations

We reported a net loss of $4.7 million and net income of $18.1 million the three and six months ended June 30, 2023 and net income of $13.0 million and a net loss of $79.7 million for the June 30, 2022, respectively. The table included below sets forth financial information for the periods presented.


	Three Months Ended				Six Months Ended
	June 30,				June 30,
In thousands (except per unit and per Boe amounts)	2023		2022		2023		2022
Net income (loss)	$	(4,748)	$	13,047	$	18,063	$	(79,697)
Operating revenues:
Oil		46,168		73,944		100,383		136,468
Natural gas		2,060		14,759		4,960		23,640
Natural gas liquids		5,657		12,587		12,815		22,590
Other		387		221		1,256		415
Operating expenses:
Production:
Lease operating		11,365		11,909		23,056		23,433
Workover and other		2,634		1,383		3,969		2,248
Taxes other than income		3,180		5,372		6,370		10,323
Gathering and other		16,828		15,869		33,345		31,124
General and administrative:
General and administrative		6,015		4,115		10,925		8,716
Stock-based compensation		(772)		473		(545)		857
Depletion, depreciation and accretion:
Depletion – Full cost		14,361		12,414		30,168		22,481
Depreciation – Other		166		76		321		120
Accretion expense		186		111		372		220
Other income (expenses):
Net gain (loss) on derivative contracts		4,473		(31,910)		23,946		(155,768)
Interest expense and other		(9,530)		(4,832)		(17,316)		(7,520)

Production:
Oil – MBbls		636		674		1,366		1,344
Natural Gas - MMcf		2,155		2,355		4,562		4,670
Natural gas liquids – MBbls		302		303		629		576
Total MBoe⁽¹⁾		1,297		1,369		2,755		2,698
Average daily production – Boe⁽¹⁾		14,253		15,044		15,221		14,906

Average price per unit ⁽²⁾:
Oil price - Bbl	$	72.59	$	109.71	$	73.49	$	101.54
Natural gas price - Mcf		0.96		6.27		1.09		5.06
Natural gas liquids price - Bbl		18.73		41.54		20.37		39.22
Total per Boe⁽¹⁾		41.55		73.99		42.89		67.72

Average cost per Boe:
Production:
Lease operating	$	8.76	$	8.70	$	8.37	$	8.69
Workover and other		2.03		1.01		1.44		0.83
Taxes other than income		2.45		3.92		2.31		3.83
Gathering and other		12.97		11.59		12.10		11.54
General and administrative:
General and administrative		4.64		3.01		3.97		3.23
Stock-based compensation		(0.60)		0.35		(0.20)		0.32
Depletion		11.07		9.07		10.95		8.33

(1)	Determined using a ratio of six Mcf of natural gas to one barrel of oil, condensate, or NGLs based on approximate energy equivalency. This is an energy content correlation and does not reflect the value or price relationship between the commodities.

(2)	Amounts exclude the impact of cash paid/received on settled contracts as we did not elect to apply hedge accounting.

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Operating Revenues. Oil, natural gas and natural gas liquids revenues were $53.9 million and $118.2 million for the three and six months ended June 30, 2023, respectively. Oil, natural gas and natural gas liquids revenues were $101.3 million and $182.7 million for the three and six months ended June 30, 2022, respectively. The decrease in revenues is primarily attributable to a decrease in our average realized prices partially offset by higher production volumes for the six months ended in June 30, 2023 compared to the same period in 2022. Average realized prices (excluding the effects of hedging arrangements) decreased approximately $32.44 and $24.83, respectively, for the three and six months ended June 30, 2023 when compared with the same periods in 2022. The amount we realize for our production depends predominantly upon commodity prices, which are affected by changes in market demand and supply, as impacted by overall economic activity, weather, transportation take-away capacity constraints, inventory storage levels, quality of production, basis differentials and other factors.

Production averaged 14,253 Boe/d and 15,221 Boe/d for the three and six months ended June 30, 2023, respectively. Production averaged 15,044 Boe/d and 14,906 Boe/d for the three and six months ended June 30, 2022, respectively. Production was lower for the three months ended June 30, 2023 compared with the same period in 2022 primarily due to natural production declines on producing wells, which more than offset the additional production from the one operated well we brought online in the first half of 2023. Production was higher for the six months ended June 30, 2023 compared to the prior year largely due to putting additional operated wells online in the second half of 2022, partially offset by natural production declines on producing wells.

Lease Operating Expenses. Lease operating expenses were $11.4 million and $23.1 million for the three and six months ended June 30, 2023, respectively. Lease operating expenses were $11.9 million and $23.4 million for the three and six months ended June 30, 2022, respectively. On a per unit basis, lease operating expenses were $8.76 per Boe and $8.37 per Boe for the three and six months ended June 30, 2023, respectively. On a per unit basis, lease operating expenses were $8.70 per Boe and $8.69 per Boe for the three and six months ended June 30, 2022, respectively. The increase in lease operating expenses per Boe for the three months ended June 30, 2023 compared to the prior year resulted primarily from high flare volumes due to midstream disruptions causing sales Boe per day to be lower, while the per unit cost decrease for the six months ended June 30, 2023 compared to the prior year was primarily due to renegotiated contracts for chemicals and labor resulting in lower daily burn rates.

Workover and Other Expenses. Workover and other expenses were $2.6 million and $4.0 million for the three and six months ended June 30, 2023, respectively. Workover and other expenses were $1.4 million and $2.2 million for the three and six months ended June 30, 2022, respectively. On a per unit basis, workover and other expenses were $2.03 per Boe and $1.44 per Boe for the three and six months ended June 30, 2023, respectively. On a per unit basis, workover and other expenses were $1.01 per Boe and $0.83 per Boe for the three and six months ended June 30, 2022, respectively. The increased workover and other expenses in 2023 relate to more significant workover projects undertaken in the current year as well as continued inflationary and market increases in service and material costs in 2023.

Taxes Other than Income. Taxes other than income were $3.2 million and $6.4 million for the three and six months ended June 30, 2023, respectively. Taxes other than income were $5.4 million and $10.3 million for the three and six months ended June 30, 2022, respectively. Severance taxes are based on realized prices and volumes at the wellhead, while ad valorem taxes are tied to the annual valuation of our properties. As revenues or volumes from oil and natural gas sales increase or decrease, severance taxes on these sales also increase or decrease. On a per unit basis, taxes other than income were $2.45 per Boe and $2.31 per Boe for the three and six months ended June 30, 2023, respectively. On a per unit basis, taxes other than income were $3.92 per Boe and $3.83 per Boe for the three and six months ended June 30, 2022, respectively. The decrease in taxes other income was largely driven by the reduced commodity pricing experienced in 2023 in addition to lower volumes for the three months ended June 30, 2023, compared to the prior year period.

Gathering and Other Expenses. Gathering and other expenses were $16.8 million and $33.3 million for the three and six months ended June 30, 2023, respectively. Gathering and other expenses were $15.9 million and $31.1 million for the three and six months ended June 30, 2022, respectively. Gathering and other expenses include gathering fees paid to third parties on our oil and natural gas production and operating expenses of our gathering support infrastructure. Our gathering and other expenses are primarily driven by the amount and location of natural gas production, the concentration of H2S in our sour gas produced, and the amounts paid to treat our sour gas volumes, either through our own hydrogen sulfide treating plant or through third parties. On a per unit basis, gathering and other expenses were

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$12.97 per Boe and $12.10 per Boe for the three and six months ended June 30, 2023, respectively, and $11.59 per Boe and $11.54 per Boe for the three and six months ended June 30, 2022, respectively. The increases in gathering and other expenses are primarily related to increased production of higher acid natural gas in our Monument Draw area in 2023 requiring H2S treatment, compared to 2022, as well as inflationary impacts on costs associated with our own hydrogen sulfide treating plant.

General and Administrative Expense. General and administrative expense was $6.0 million and $10.9 million for the three and six months ended June 30, 2023, respectively. General and administrative expense was $4.1 million and $8.7 million for the three and six months ended June 30, 2022, respectively. On a per unit basis, however, general and administrative expenses were $4.64 per Boe and $3.97 per Boe for the three and six months ended June 30, 2023, respectively, and were $3.01 per Boe and $3.23 per Boe for the three and six months ended June 30, 2022, respectively. The increase in general and administrative expense for the three and six months ended June 30, 2023 compared with prior year periods is primarily associated with an increase in professional fees, partially offset by a decrease in payroll and benefits in connection with the headcount reduction.

Depletion, Depreciation, and Amortization Expense. Depletion for oil and natural gas properties is calculated using the unit of production method, which depletes the capitalized costs of evaluated properties plus future development costs based on the ratio of production for the current period to total reserve volumes of evaluated properties as of the beginning of the period.

Depletion expense was $14.4 million and $30.2 million for the three and six months ended June 30, 2023, respectively. Depletion expense was $12.4 million and $22.5 million for the three and six months ended June 30, 2022, respectively. On a per unit basis, depletion expense was $11.07 per Boe and $10.95 per Boe for the three and six months ended June 30, 2023, respectively. On a per unit basis, depletion expense was $9.07 per Boe and $8.33 per Boe for the three and six months ended June 30, 2022, respectively. The increase in our depletion rate is primarily due to increased future development costs (tied to market and inflationary increases) associated with proved reserve additions relative to the change in proved reserves.

Net gain (loss) on derivative contracts. We enter into derivative commodity instruments to hedge our exposure to price fluctuations on our anticipated oil, natural gas and natural gas liquids production. Consistent with prior years, we have elected not to designate any positions as cash flow hedges for accounting purposes, and accordingly, we recorded the net change in the mark-to-market value of these derivative contracts in the unaudited condensed consolidated statements of operations.

For the three and six months ended June 30, 2023, respectively, we recorded net derivative gains of $4.5 million and $23.9 million ($2.4 million net gain on unsettled contracts and $2.1 million net realized gain on settled contracts for the three months ended June 30, 2023, and $23.3 million net gain on unsettled contracts and $0.6 million net realized gain on settled contracts for the six months ended June 30, 2023).

For the three and six months ended June 30, 2022, respectively, we recorded net derivative losses of $31.9 million and $155.8 million ($12.8 million net gain on unsettled contracts and $44.7 million net realized loss on settled contracts three months ended June 30, 2022, and $78.2 million net loss on unsettled contracts and $77.6 million net realized loss on settled contracts for the six months ended June 30, 2022).

At June 30, 2023, we had a $14.9 million derivative asset ($9.6 million current) and a $32.9 million derivative liability ($15.5 million current).

Interest Expense and Other. Interest expense and other was $9.5 million and $17.3 million for the three and six months ended June 30, 2023, respectively. Interest expense and other was $4.8 million and $7.5 million for the three and six months ended June 30, 2022, respectively. Interest expense and other primarily increased in the current year periods due to increased interest rates, an increased average debt balance due to the additional borrowings in April and November of 2022, and amortization/accretion of financing related costs since November 2022 associated with our Amended Term Loan Agreement. Our weighted average interest rate was approximately 12.6% for the quarter ended June 30, 2023. For the third quarter of 2023, our interest rate will be approximately 12.9% on outstanding borrowings.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Derivative Instruments and Hedging Activity

We are exposed to various risks, including energy commodity price risk, such as price differentials between the NYMEX commodity price and the index price at the location where our production is sold. When oil and natural gas prices decline significantly, our ability to finance our capital budget and operations may be adversely impacted. We expect energy prices to remain volatile and unpredictable, therefore we have designed a risk management policy which provides for the use of derivative instruments to provide partial protection against declines in oil and natural gas prices by reducing the risk of price volatility and the affect it could have on our operations. The types of derivative instruments that we typically utilize include fixed-price swaps, costless collars, basis swaps and WTI NYMEX rolls. The total volumes that we hedge through the use of our derivative instruments varies from period to period; however, our requirement under our Term Loan Agreement is to hedge approximately 50% to 85% of our anticipated oil and natural gas production, in varying percentages by year, on a rolling basis for the next four years. Our hedge policies and objectives may change significantly as our operational profile and contractual obligations change but remain consistent with the requirements in effect under our Term Loan Agreement. We do not enter into derivative contracts for speculative trading purposes.

We are exposed to market risk on our open derivative contracts related to potential non-performance by our counterparties. It is our policy to enter into derivative contracts only with counterparties that are creditworthy institutions deemed by management as competitive market makers. As of June 30, 2023, we did not post collateral under any of our derivative contracts as they are secured under our Term Loan Agreement. We account for our derivative activities on the balance sheet as either an asset or liability measured at fair value. See Item 1. Condensed Consolidated Financial Statements (Unaudited)—Note 7, “Derivative and Hedging Activities,” for more details.

Fair Market Value of Financial Instruments

The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information, involve uncertainties, and cannot be determined with precision. The estimated fair value of cash, cash equivalents and restricted cash, accounts receivable and accounts payable approximates their carrying value due to their short-term nature. See Item 1. Condensed Consolidated Financial Statements (Unaudited)—Note 6, “Fair Value Measurements,” for additional information.

Interest Rate Sensitivity

We are also exposed to market risk related to adverse changes in interest rates. Our interest rate risk exposure results primarily from fluctuations in short-term rates, which are SOFR (and previously, LIBOR) based and may result in reductions of earnings or cash flows due to increases in the interest rates we pay on these obligations.

At June 30, 2023, the principal amount of our term loan debt was $220.0 million, of which substantially all bears interest at floating and variable interest rates that are tied to SOFR. Fluctuations in market interest rates will cause our annual interest costs to fluctuate. At June 30, 2023, the weighted average interest rate on our variable rate debt was 12.6% per year. If the balance of our variable interest rate debt at June 30, 2023 were to remain constant, a 10% change in market interest rates would impact our cash flows by approximately $2.9 million per year.

ITEM 4. CONTROLS AND PROCEDURES

Under the supervision and with the participation of our management, including our Chief Executive Officer and our Principal Financial Officer, we evaluated the design and operation of our disclosure controls and procedures (as defined in rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, or the Exchange Act) as of June 30, 2023. On the basis of this review, our management, including our Chief Executive Officer and Principal Financial Officer,

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concluded that our disclosure controls and procedures are designed, and are effective, to give reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and to ensure that information required to be disclosed in the reports filed or submitted under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Principal Financial Officer, in a manner that allows timely decisions regarding required disclosure.

We did not have any change in our internal controls over financial reporting during the three or six months ended June 30, 2023 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Information regarding legal proceedings to which we are a party is set forth in Item 1. Condensed Consolidated Financial Statements (Unaudited)—Note 9, “Commitments and Contingencies,” which is incorporated herein by reference.

ITEM 1A. RISK FACTORS

There have been no changes to the risk factors described in our Annual Report on Form 10-K for the fiscal year ended December 31, 2022.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

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ITEM 6. EXHIBITS

The following documents are included as exhibits to this Quarterly Report on Form 10-Q. Those exhibits incorporated by reference are so indicated by the information supplied with respect thereto. Those exhibits which are not incorporated by reference are attached hereto.


3.1		Amended and Restated Certificate of Incorporation of Battalion Oil Corporation dated October 8, 2019, as amended by the Certificate of Amendment, dated January 21, 2020 (Incorporated by reference to Exhibit 3.1 of our Annual Report on Form 10-K filed March 25, 2020).
3.1.1		Certificate of Designations of Series A Redeemable Convertible Preferred Stock dated effective March 24, 2023 (Incorporated by reference to Exhibit 3.1.1 of our Annual Report on Form 10-K filed March 30, 2023).
3.2		Seventh Amended and Restated Bylaws of Battalion Oil Corporation (Incorporated by reference to Exhibit 3.2 of our Current Report on Form 8-K filed January 27, 2020).
10.1		Amended and Restated Senior Secured Credit Agreement dated as of November 24, 2021, by and among Battalion Oil Corporation, as holdings, Halcón Holdings LLC, as borrower, the subsidiary guarantors party thereto, Macquarie Bank Limited, as administrative agent, and the lenders party thereto (Incorporated by reference to Exhibit 10.1 of our Current Report on Form 8-K filed November 29, 2021).
10.1.1		Second Amendment to Amended and Restated Senior Secured Credit Agreement dated as of November 14, 2022, by and among Halcón Holdings, LLC, as borrower, Macquarie Bank Limited, as administrative agent and the lenders party hereto, the guarantors party hereto and Battalion Oil Corporation, as holdings (Incorporated by reference to Exhibit 10.1.1 of our Quarterly Report on Form 10-Q filed November 14, 2022).
10.2		Purchase Agreement, dated March 28, 2023, by and among Battalion Oil Corporation and each of the purchasers set forth on Schedule A thereto (Incorporated by reference to Exhibit 10.8 of our Annual Report on Form 10-K filed March 30, 2023).
31	*	Sarbanes-Oxley Section 302 certification of Principal Executive Officer and Principal Financial Officer
32	*	Sarbanes-Oxley Section 906 certification of Principal Executive Officer and Principal Financial Officer
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)

^*	Attached hereto.

^†	Indicates management contract or compensatory plan or 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.


	BATTALION OIL CORPORATION


August 21, 2023	By:	/s/ MATTHEW B. STEELE
	Name:	Matthew B. Steele
	Title:	Chief Executive Officer (Principal Executive Officer and Principal Financial Officer)

Exhibit 31

CERTIFICATIONS FOR FORM 10-Q

I, Matthew B. Steele, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Battalion Oil Corporation;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under my supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under my supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report my conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

(d)

Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.	I have disclosed, based on my most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

on
	BATTALION OIL CORPORATION
August 21, 2023	By:	/s/ Matthew B. Steele
	Name:	Matthew B. Steele
	Title:	Chief Executive Officer (Principal Executive Officer and Principal Financial Officer)

Exhibit 32

Certification Pursuant to

Section 906 of the Sarbanes-Oxley Act of 2002

(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), Matthew B. Steele, Chief Executive Officer of Battalion Oil Corporation (the “Company”), hereby certifies that, to the best of his knowledge:

(1)

The Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2023 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


	/s/ Matthew B. Steele
August 21, 2023	Matthew B. Steele Chief Executive Officer (Principal Executive Officer and Principal Financial Officer)

This certification accompanies this Form 10-Q and shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, or otherwise subject to the liability of that Section.

A signed original of this written statement required by Section 906 has been provided to, and will be retained by, the Company and furnished to the Securities and Exchange Commission or its staff upon request.

Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Jun. 30, 2023	Aug. 17, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Jun. 30, 2023
Entity Tax Identification Number	20-0700684
Entity Registrant Name	Battalion Oil Corp
Entity Incorporation, State or Country Code	DE
Entity File Number	001-35467
Entity Address, Address Line One	3505 West Sam Houston Parkway North
Entity Address, Address Line Two	Suite 300
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77043
City Area Code	832
Local Phone Number	538-0300
Title of 12(b) Security	Common Stock, par value $0.0001
Trading Symbol	BATL
Security Exchange Name	NYSEAMER
Amendment Flag	false
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		16,456,563
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001282648
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 53,885	$ 101,290	$ 118,158	$ 182,698
Other	387	221	1,256	415
Total operating revenues	54,272	101,511	119,414	183,113
Production:
Lease operating	11,365	11,909	23,056	23,433
Workover and other	2,634	1,383	3,969	2,248
Taxes other than income	3,180	5,372	6,370	10,323
Gathering and other	16,828	15,869	33,345	31,124
General and administrative	5,243	4,588	10,380	9,573
Depletion, depreciation and accretion	14,713	12,601	30,861	22,821
Total operating expenses	53,963	51,722	107,981	99,522
Income (loss) from operations	309	49,789	11,433	83,591
Other income (expenses):
Net gain (loss) on derivative contracts	4,473	(31,910)	23,946	(155,768)
Interest expense and other	(9,530)	(4,832)	(17,316)	(7,520)
Total other income (expenses)	(5,057)	(36,742)	6,630	(163,288)
Income (loss) before income taxes	(4,748)	13,047	18,063	(79,697)
Income tax benefit (provision)
Net income (loss)	$ (4,748)	$ 13,047	$ 18,063	$ (79,697)
Net income (loss) per share of common stock:
Basic (in dollars per share)	$ (0.35)	$ 0.80	$ 0.87	$ (4.88)
Diluted (in dollars per share)	$ (0.35)	$ 0.79	$ 0.86	$ (4.88)
Weighted average common shares outstanding:
Basic (in shares)	16,457	16,338	16,425	16,320
Diluted (in shares)	16,457	16,510	16,520	16,320
Oil
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 46,168	$ 73,944	$ 100,383	$ 136,468
Natural gas
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	2,060	14,759	4,960	23,640
NGLs
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 5,657	$ 12,587	$ 12,815	$ 22,590

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 18,514	$ 32,726
Accounts receivable, net	23,518	37,974
Assets from derivative contracts	9,611	16,244
Restricted cash	90	90
Prepaids and other	1,049	1,131
Total current assets	52,782	88,165
Oil and natural gas properties (full cost method):
Subject to depletion	727,347	713,585
Unevaluated	62,649	62,621
Gross oil and natural gas properties	789,996	776,206
Less - accumulated depletion	(420,964)	(390,796)
Net oil and natural gas properties	369,032	385,410
Other operating property and equipment:
Other operating property and equipment	4,674	4,434
Less - accumulated depreciation	(1,486)	(1,209)
Net other operating property and equipment	3,188	3,225
Other noncurrent assets:
Assets from derivative contracts	5,299	5,379
Operating lease right of use assets	162	352
Other assets	2,778	2,827
Total assets	433,241	485,358
Current liabilities:
Accounts payable and accrued liabilities	48,897	100,095
Liabilities from derivative contracts	15,480	29,286
Current portion of long-term debt	42,606	35,067
Operating lease liabilities	162	352
Asset retirement obligations	111	225
Total current liabilities	107,256	165,025
Long-term debt, net	164,055	182,676
Other noncurrent liabilities:
Liabilities from derivative contracts	17,406	33,649
Asset retirement obligations	15,741	15,244
Other	3,432	4,136
Commitments and contingencies (Note 9)
Temporary equity:
Series A redeemable convertible preferred stock: 25,000 shares of $.0001 par value authorized, issued and outstanding as of June 30, 2023	26,030
Stockholders' equity:
Common stock: 100,000,000 shares of $0.0001 par value authorized; 16,456,563 and 16,344,815 shares issued and outstanding as of June 30, 2023 and December 31, 2022, respectively	2	2
Additional paid-in capital	331,201	334,571
Retained earnings (accumulated deficit)	(231,882)	(249,945)
Total stockholders' equity	99,321	84,628
Total liabilities, temporary equity and stockholders' equity	$ 433,241	$ 485,358

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Jun. 30, 2023	Dec. 31, 2022
Stockholders' equity:
Preferred stock, par value (in dollars per share)	$ 0.0001
Preferred stock, shares authorized	25,000
Preferred stock, shares issued	25,000
Preferred stock, shares outstanding	25,000
Common stock, shares authorized	100,000,000	100,000,000
Common stock, par value (in dollars per share)	$ 0.0001	$ 0.0001
Common stock, shares issued	16,456,563	16,344,815
Common stock, shares outstanding	16,456,563	16,344,815

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS EQUITY - USD ($) shares in Thousands, $ in Thousands	Common Stock	Additional Paid-In Capital	Retained Earnings (Accumulated Deficit)	Total
Balances at Dec. 31, 2021	$ 2	$ 332,187	$ (268,484)	$ 63,705
Balances (in shares) at Dec. 31, 2021	16,274
Increase (Decrease) in Stockholders' Equity
Net income (loss)			(92,744)	(92,744)
Tax withholding on vesting of restricted stock units		(461)		(461)
Tax withholding on vesting of restricted stock units (in shares)	(26)
Stock-based compensation		452		452
Balances at Mar. 31, 2022	$ 2	332,178	(361,228)	(29,048)
Balances (in shares) at Mar. 31, 2022	16,337
Balances at Dec. 31, 2021	$ 2	332,187	(268,484)	63,705
Balances (in shares) at Dec. 31, 2021	16,274
Increase (Decrease) in Stockholders' Equity
Net income (loss)				(79,697)
Long-term incentive plan vestings (in shares)	89
Balances at Jun. 30, 2022	$ 2	332,766	(348,181)	(15,413)
Balances (in shares) at Jun. 30, 2022	16,338
Balances at Mar. 31, 2022	$ 2	332,178	(361,228)	(29,048)
Balances (in shares) at Mar. 31, 2022	16,337
Increase (Decrease) in Stockholders' Equity
Net income (loss)			13,047	13,047
Long-term incentive plan vestings (in shares)	1
Reduction in shares to cover individuals' tax withholding		(6)		(6)
Stock-based compensation		594		594
Balances at Jun. 30, 2022	$ 2	332,766	(348,181)	(15,413)
Balances (in shares) at Jun. 30, 2022	16,338
Increase (Decrease) in Stockholders' Equity
Net income (loss)			105,888	105,888
Long-term incentive plan vestings (in shares)	8
Reduction in shares to cover individuals' tax withholding		(25)		(25)
Reduction in shares to cover individuals' tax withholding (in shares)	(2)
Stock-based compensation		893		893
Balances at Sep. 30, 2022	$ 2	333,634	(242,293)	91,343
Balances (in shares) at Sep. 30, 2022	16,344
Increase (Decrease) in Stockholders' Equity
Net income (loss)			(7,652)	(7,652)
Stock-based compensation	$ 1	937		937
Balances at Dec. 31, 2022	$ 2	334,571	(249,945)	84,628
Balances (in shares) at Dec. 31, 2022	16,345
Increase (Decrease) in Stockholders' Equity
Net income (loss)			22,811	22,811
Deemed dividends for Series A preferred stock		(1,492)		(1,492)
Tax withholding on vesting of restricted stock units		(454)		(454)
Tax withholding on vesting of restricted stock units (in shares)	(47)
Stock-based compensation		327		327
Balances at Mar. 31, 2023	$ 2	332,952	(227,134)	105,820
Balances (in shares) at Mar. 31, 2023	16,457
Balances at Dec. 31, 2022	$ 2	334,571	(249,945)	84,628
Balances (in shares) at Dec. 31, 2022	16,345
Increase (Decrease) in Stockholders' Equity
Net income (loss)				18,063
Deemed dividends for Series A preferred stock				(1,500)
Long-term incentive plan vestings (in shares)	159
Balances at Jun. 30, 2023	$ 2	331,201	(231,882)	99,321
Balances (in shares) at Jun. 30, 2023	16,457
Balances at Mar. 31, 2023	$ 2	332,952	(227,134)	105,820
Balances (in shares) at Mar. 31, 2023	16,457
Increase (Decrease) in Stockholders' Equity
Net income (loss)			(4,748)	(4,748)
Equity issuance costs		(997)		(997)
Stock-based compensation		(754)		(754)
Balances at Jun. 30, 2023	$ 2	$ 331,201	$ (231,882)	$ 99,321
Balances (in shares) at Jun. 30, 2023	16,457

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash flows from operating activities:
Net income (loss)	$ 18,063	$ (79,697)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depletion, depreciation and accretion	30,861	22,821
Stock-based compensation, net	(545)	857
Unrealized loss (gain) on derivative contracts	(23,336)	78,201
Amortization of deferred loan costs	3,843	1,807
Reorganization items		(744)
Accrued settlements on derivative contracts	(929)	14,652
Change in fair value of embedded derivative liability	(704)	(2,595)
Other expense (income)	53	(96)
Change in assets and liabilities:
Accounts receivable	15,965	(12,596)
Prepaids and other	81	438
Accounts payable and accrued liabilities	(34,703)	5,285
Net cash provided by (used in) operating activities	8,649	28,333
Cash flows from investing activities:
Oil and natural gas capital expenditures	(32,633)	(51,377)
Proceeds received from sale of oil and natural gas assets	1,189
Other operating property and equipment capital expenditures	(284)	(705)
Proceeds received from sale of other operating property and equipment		96
Other	(11)
Net cash provided by (used in) investing activities	(31,739)	(51,986)
Cash flows from financing activities:
Proceeds from borrowings		20,000
Repayments of borrowings	(15,043)	(85)
Payment of deferred debt financing costs		(379)
Proceeds from issuance of preferred stock	24,375
Other	(454)	(467)
Net cash provided by (used in) financing activities	8,878	19,069
Net increase (decrease) in cash, cash equivalents and restricted cash	(14,212)	(4,584)
Cash, cash equivalents and restricted cash at beginning of period	32,816	48,359
Cash, cash equivalents and restricted cash at end of period	$ 18,604	$ 43,775

FINANCIAL STATEMENT PRESENTATION

6 Months Ended

Jun. 30, 2023

FINANCIAL STATEMENT PRESENTATION

FINANCIAL STATEMENT PRESENTATION

1. FINANCIAL STATEMENT PRESENTATION

Basis of Presentation and Principles of Consolidation

Liquidity and Cash Requirements

Risk and Uncertainties

Use of Estimates

Cash, Cash Equivalents and Restricted Cash


	June 30, 2023		December 31, 2022

Cash and cash equivalents	$	18,514	$	32,726
Restricted cash		90		90
Total cash, cash equivalents and restricted cash	$	18,604	$	32,816

Restricted cash consists of funds to collateralize lines of credit.

Accounts Receivable and Allowance for Doubtful Accounts

Concentrations of Credit Risk

Recently Issued Accounting Pronouncements

LEASES

6 Months Ended

Jun. 30, 2023

LEASES

LEASES

2. LEASES


	Six Months Ended
	June 30,
	2023			2022
Lease cost
Operating lease costs	$	196		$	196
Short-term lease costs		375			4,003
Variable lease costs		—			—
Total lease costs	$	571		$	4,199

Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	196
Right-of-use assets obtained in exchange for new operating lease liabilities		—			—
Weighted-average remaining lease term - operating leases		0.4	years		1.4	years
Weighted-average discount rate - operating leases		4.29	%		4.29	%

Future minimum lease payments associated with the Company’s non-cancellable operating leases for office space as of June 30, 2023 are presented in the table below (in thousands):


	June 30, 2023
Remaining period in 2023	$	163
Thereafter		—
Total operating lease payments		163
Less: discount to present value		1
Total operating lease liabilities		162
Less: current operating lease liabilities		162
Noncurrent operating lease liabilities	$	—

OPERATING REVENUES

6 Months Ended

Jun. 30, 2023

OPERATING REVENUES

OPERATING REVENUES

3. OPERATING REVENUES

For additional information regarding our operating revenues, refer to our Annual Report on Form 10-K for the year ended December 31, 2022.

OIL AND NATURAL GAS PROPERTIES

6 Months Ended

Jun. 30, 2023

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES

4. OIL AND NATURAL GAS PROPERTIES

DEBT

6 Months Ended

Jun. 30, 2023

DEBT

DEBT

5. DEBT

As of June 30, 2023 and December 31, 2022, the Company’s debt consisted of the following (in thousands):


	June 30, 2023		December 31, 2022
Term loan credit facility	$	220,000	$	235,000
Other		265		190
Total debt (Face Value)		220,265		235,190
Less:
Current portion of long-term debt⁽¹⁾		(42,606)		(35,067)
Other⁽²⁾		(13,604)		(17,447)
Long-Term Debt, net	$	164,055	$	182,676

(1)	Amounts primarily reflect amortization payments under the Amended Term Loan Agreement due within one year.

(2)

Term Loan Credit Facility

The Company may elect, at its option, to prepay any borrowing outstanding under the Amended Term Loan Agreement subject to the following prepayment premiums:


Period (after applicable borrowing date⁽¹⁾)			Premium
Months 0-12			Make-whole amount equal to 12 months of interest plus 2.00%
Months 13-24			2.00%
Months 25-36			1.00%
Months 37-48			0.00%

(1)

The Amended Term Loan Agreement also contains certain financial covenants (as defined), including the maintenance of the following ratios:

●

Asset Coverage Ratio of not less than 1.80 to 1.00 as of June 30, 2023 and the last day of each fiscal quarter thereafter

●

Total Net Leverage Ratio of not greater than 2.50 to 1.00 as of June 30, 2023, and each fiscal quarter thereafter, and

●

Current Ratio of not less than 1.00 to 1.00, determined as of the last day of any fiscal quarter period, as of June 30, 2023 and for each fiscal quarter thereafter.

As of June 30, 2023, the Company was in compliance with the financial covenants under the Amended Term Loan Agreement.

the significant inputs to the valuation, and for a reconciliation of the change in fair value of the Change of Control Call Option.

FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2023

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

6. FAIR VALUE MEASUREMENTS


	June 30, 2023
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	14,910	$	—	$	14,910

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	32,886	$	—	$	32,886


	December 31, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	21,623	$	—	$	21,623

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	62,935	$	—	$	62,935


	Change of Control
	Call Option
Balance at December 31, 2022	$	4,136
Change in fair value		(704)
Balance at June 30, 2023	$	3,432

DERIVATIVE AND HEDGING ACTIVITIES

6 Months Ended

Jun. 30, 2023

DERIVATIVE AND HEDGING ACTIVITIES

DERIVATIVE AND HEDGING ACTIVITIES

7. DERIVATIVE AND HEDGING ACTIVITIES

●

Fixed-price swaps are designed so that the Company receives or makes payments based on a differential between fixed and variable prices for crude oil and natural gas.

●

WTI NYMEX roll agreements account for pricing adjustments to the trade month versus the delivery month for contract pricing.


Balance sheet location	June 30, 2023		December 31, 2022		Balance sheet location	June 30, 2023		December 31, 2022
Current assets	$	9,611	$	16,244	Current liabilities	$	(15,480)	$	(29,286)
Other noncurrent assets		5,299		5,379	Other noncurrent liabilities		(17,406)		(33,649)
	$	14,910	$	21,623		$	(32,886)	$	(62,935)


	Location of net gain (loss)	Three Months Ended				Six Months Ended
	on derivative contracts on	June 30,				June 30,
Type	Statement of Operations	2023		2022		2023		2022
Commodity derivative contracts:
Unrealized gain (loss)	Other income (expenses)	$	2,332	$	12,837	$	23,336	$	(78,201)
Realized gain (loss)	Other income (expenses)		2,141		(44,747)		610		(77,567)
Total net gain (loss)		$	4,473	$	(31,910)	$	23,946	$	(155,768)

At June 30, 2023, the Company had the following open crude oil and natural gas derivative contracts:


Instrument		2023		2024		2025		2026		2027
Crude oil:
Fixed-price swap:
Total volumes (Bbls)		1,115,335		1,805,885		1,240,171		936,741		198,000
Weighted average price	$	67.36	$	63.69	$	61.18	$	63.56	$	59.64
Basis swap:
Total volumes (Bbls)		1,047,536		1,801,951		1,240,171		936,741		198,000
Weighted average price	$	0.40	$	0.27	$	0.18	$	(0.01)	$	0.40
WTI NYMEX roll:
Total volumes (Bbls)		1,097,510		1,784,914		1,240,171		936,741		198,000
Weighted average price	$	0.51	$	0.27	$	0.12	$	(0.03)	$	—
Natural gas:
Fixed-price swap:
Total volumes (MMBtu)		2,925,851		4,423,784		3,687,113		1,979,033		—
Weighted average price	$	3.71	$	3.54	$	3.35	$	4.00	$	—
Two-way collar:
Total volumes (MMBtu)		1,082,869		2,610,639		1,651,321		2,063,812		900,000
Weighted average price (call)	$	5.21	$	5.08	$	5.12	$	5.26	$	5.75
Weighted average price (put)	$	3.76	$	3.67	$	3.72	$	3.70	$	4.25
Basis swap:
Total volumes (MMBtu)		4,008,720		7,034,372		5,319,878		4,042,845		900,000
Weighted average price	$	(0.89)	$	(0.87)	$	(0.67)	$	(0.77)	$	(0.78)


	Derivative Assets				Derivative Liabilities
Offsetting of Derivative Assets and Liabilities	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022

Gross Amounts - Consolidated Balance Sheet	$	14,910	$	21,623	$	(32,886)	$	(62,935)
Amounts Not Offset - Consolidated Balance Sheet		(11,762)		(20,997)		11,762		20,997
Net Amount	$	3,148	$	626	$	(21,124)	$	(41,938)

ASSET RETIREMENT OBLIGATIONS

6 Months Ended

Jun. 30, 2023

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS

8. ASSET RETIREMENT OBLIGATIONS

The Company recorded the following activity related to its ARO liability (in thousands):


Liability for asset retirement obligations as of December 31, 2022	$	15,469
Accretion expense		372
Liabilities incurred during the period		11
Liability for asset retirement obligations as of June 30, 2023		15,852

COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2023

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

9. COMMITMENTS AND CONTINGENCIES

Commitments

Contingencies

REDEEMABLE CONVERTIBLE PREFERRED STOCK

6 Months Ended

Jun. 30, 2023

Redeemable Convertible Preferred Stock [Abstract]

REDEEMABLE CONVERTIBLE PREFERRED STOCK

10. REDEEMABLE CONVERTIBLE PREFERRED STOCK

Voting Rights. Holders of preferred stock have no voting rights with respect to the shares of preferred stock.

Redemption Features (Issuer). The Company has the option to redeem the preferred stock in cash for an amount per share of Preferred Stock equal to (the “Redemption Price”):

●

at any time prior to 120 days following the closing date, 100% of the Liquidation Preference at such time;

●

at any time on or after 120 days following the closing date but prior to the 180 days following the closing date, 102% of the Liquidation Preference at such time;

●

at any time on or after 180 days following the closing date but on or prior to the first anniversary of the closing date, 105% of the Liquidation Preference at such time;

●

at any time after the first anniversary of the closing date but on or prior to the second anniversary of the closing date, 108% of the Liquidation Preference at such time; and

●

at any time after the second anniversary of the closing date, 120% of the Liquidation Preference at such time.

Redemption Features (Change of Control). In the event of a change of control, holders have the right to receive:

●

STOCKHOLDERS' EQUITY

6 Months Ended

Jun. 30, 2023

STOCKHOLDERS' EQUITY

STOCKHOLDERS' EQUITY

11. STOCKHOLDERS’ EQUITY

Incentive Plans

Restricted Stock

Stock Options

EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2023

EARNINGS PER SHARE

EARNINGS PER SHARE

12. EARNINGS PER SHARE

The following represents the calculation of earnings (loss) per share (in thousands, except per share amounts):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
Basic:
Net income (loss)	$	(4,748)	$	13,047	$	18,063	$	(79,697)
Less: Preferred stock dividend		(997)		—		(2,489)		—
Less: Undistributed earnings allocable to preferred shareholders		—		—		(1,301)		—
Net income (loss) available to common stockholders	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Basic net income (loss) per share of common stock	$	(0.35)	$	0.80	$	0.87	$	(4.88)

Diluted:
Net income (loss) available to common stockholders basic	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Reallocation of undistributed earnings		—		—		7		—
Net income (loss) available to common stockholders diluted	$	(5,745)	$	13,047	$	14,280	$	(79,697)

Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Common stock equivalent shares representing shares issuable upon:
Exercise of warrants and stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		Anti-dilutive		172		95		Anti-dilutive
Weighted average diluted number of common shares outstanding diluted		16,457		16,510		16,520		16,320
Diluted net income (loss) per share of common stock	$	(0.35)	$	0.79	$	0.86	$	(4.88)

ADDITIONAL FINANCIAL STATEMENT INFORMATION

6 Months Ended

Jun. 30, 2023

ADDITIONAL FINANCIAL STATEMENT INFORMATION

ADDITIONAL FINANCIAL STATEMENT INFORMATION

13. ADDITIONAL FINANCIAL STATEMENT INFORMATION

Certain balance sheet amounts are comprised of the following (in thousands):


	June 30, 2023		December 31, 2022
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	19,853	$	33,980
Joint interest accounts		1,779		3,201
Other		1,886		793
	$	23,518	$	37,974
Prepaids and other:
Prepaids	$	509	$	715
Funds in escrow		343		341
Other		197		75
	$	1,049	$	1,131
Other assets (Non-current):
Investment in unconsolidated affiliate⁽¹⁾	$	1,477	$	1,561
Oil, natural gas and natural gas liquids revenues		24		—
Funds in escrow		538		527
Other		739		739
	$	2,778	$	2,827
Accounts payable and accrued liabilities:
Trade payables	$	17,884	$	42,919
Accrued oil and natural gas capital costs		1,928		19,911
Revenues and royalties payable		20,392		26,759
Accrued interest expense		104		160
Accrued employee compensation		1,190		2,300
Accrued lease operating expenses		7,388		8,005
Other		11		41
	$	48,897	$	100,095

(1)

FINANCIAL STATEMENT PRESENTATION (Policies)

6 Months Ended

Jun. 30, 2023

FINANCIAL STATEMENT PRESENTATION

Basis of Presentation and Principles of Consolidation

Basis of Presentation and Principles of Consolidation

Liquidity and Cash Requirements

Liquidity and Cash Requirements

Use of Estimates

Use of Estimates

Risk and Uncertainties

Risk and Uncertainties

Cash, Cash Equivalents and Restricted Cash

Cash, Cash Equivalents and Restricted Cash


	June 30, 2023		December 31, 2022

Cash and cash equivalents	$	18,514	$	32,726
Restricted cash		90		90
Total cash, cash equivalents and restricted cash	$	18,604	$	32,816

Restricted cash consists of funds to collateralize lines of credit.

Accounts Receivable and Allowance for Doubtful Accounts

Accounts Receivable and Allowance for Doubtful Accounts

Concentrations of Credit Risk

Concentrations of Credit Risk

Recently Issued Accounting Pronouncements

Recently Issued Accounting Pronouncements

FINANCIAL STATEMENT PRESENTATION (Tables)

6 Months Ended

Jun. 30, 2023

FINANCIAL STATEMENT PRESENTATION

Schedule Of Cash, Cash Equivalents And Restricted Cash


	June 30, 2023		December 31, 2022

Cash and cash equivalents	$	18,514	$	32,726
Restricted cash		90		90
Total cash, cash equivalents and restricted cash	$	18,604	$	32,816

LEASES (Tables)

6 Months Ended

Jun. 30, 2023

LEASES

Schedule of Company's leases

The table below summarizes the Company’s leases for the six months ended June 30, 2023 and 2022 (in thousands, except term and discount rate):


	Six Months Ended
	June 30,
	2023			2022
Lease cost
Operating lease costs	$	196		$	196
Short-term lease costs		375			4,003
Variable lease costs		—			—
Total lease costs	$	571		$	4,199

Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	196
Right-of-use assets obtained in exchange for new operating lease liabilities		—			—
Weighted-average remaining lease term - operating leases		0.4	years		1.4	years
Weighted-average discount rate - operating leases		4.29	%		4.29	%

Schedule of future minimum lease payments associated with the Company's non-cancellable operating leases for office space and equipment

Future minimum lease payments associated with the Company’s non-cancellable operating leases for office space as of June 30, 2023 are presented in the table below (in thousands):


	June 30, 2023
Remaining period in 2023	$	163
Thereafter		—
Total operating lease payments		163
Less: discount to present value		1
Total operating lease liabilities		162
Less: current operating lease liabilities		162
Noncurrent operating lease liabilities	$	—

DEBT (Tables)

6 Months Ended

Jun. 30, 2023

DEBT

Schedule of debt

As of June 30, 2023 and December 31, 2022, the Company’s debt consisted of the following (in thousands):


	June 30, 2023		December 31, 2022
Term loan credit facility	$	220,000	$	235,000
Other		265		190
Total debt (Face Value)		220,265		235,190
Less:
Current portion of long-term debt⁽¹⁾		(42,606)		(35,067)
Other⁽²⁾		(13,604)		(17,447)
Long-Term Debt, net	$	164,055	$	182,676

(1)	Amounts primarily reflect amortization payments under the Amended Term Loan Agreement due within one year.

(2)

Schedule of prepayment premiums

The Company may elect, at its option, to prepay any borrowing outstanding under the Amended Term Loan Agreement subject to the following prepayment premiums:


Period (after applicable borrowing date⁽¹⁾)			Premium
Months 0-12			Make-whole amount equal to 12 months of interest plus 2.00%
Months 13-24			2.00%
Months 25-36			1.00%
Months 37-48			0.00%

(1)

FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2023

FAIR VALUE MEASUREMENTS

Schedule of fair value of the Company's financial assets and liabilities


	June 30, 2023
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	14,910	$	—	$	14,910

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	32,886	$	—	$	32,886


	December 31, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	21,623	$	—	$	21,623

Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	62,935	$	—	$	62,935

Schedule of changes in fair value of the change of control call option

The following table sets forth a reconciliation of the changes in fair value of the Change of Control Call Option classified as Level 3 in the fair value hierarchy (in thousands):


	Change of Control
	Call Option
Balance at December 31, 2022	$	4,136
Change in fair value		(704)
Balance at June 30, 2023	$	3,432

DERIVATIVE AND HEDGING ACTIVITIES (Tables)

6 Months Ended

Jun. 30, 2023

DERIVATIVE AND HEDGING ACTIVITIES

Summary of location and fair value of derivative contracts


Balance sheet location	June 30, 2023		December 31, 2022		Balance sheet location	June 30, 2023		December 31, 2022
Current assets	$	9,611	$	16,244	Current liabilities	$	(15,480)	$	(29,286)
Other noncurrent assets		5,299		5,379	Other noncurrent liabilities		(17,406)		(33,649)
	$	14,910	$	21,623		$	(32,886)	$	(62,935)

Summary of the location and amounts of the Company's realized and unrealized gains and losses on derivative contracts


	Location of net gain (loss)	Three Months Ended				Six Months Ended
	on derivative contracts on	June 30,				June 30,
Type	Statement of Operations	2023		2022		2023		2022
Commodity derivative contracts:
Unrealized gain (loss)	Other income (expenses)	$	2,332	$	12,837	$	23,336	$	(78,201)
Realized gain (loss)	Other income (expenses)		2,141		(44,747)		610		(77,567)
Total net gain (loss)		$	4,473	$	(31,910)	$	23,946	$	(155,768)

Schedule of open derivative contracts

At June 30, 2023, the Company had the following open crude oil and natural gas derivative contracts:


Instrument		2023		2024		2025		2026		2027
Crude oil:
Fixed-price swap:
Total volumes (Bbls)		1,115,335		1,805,885		1,240,171		936,741		198,000
Weighted average price	$	67.36	$	63.69	$	61.18	$	63.56	$	59.64
Basis swap:
Total volumes (Bbls)		1,047,536		1,801,951		1,240,171		936,741		198,000
Weighted average price	$	0.40	$	0.27	$	0.18	$	(0.01)	$	0.40
WTI NYMEX roll:
Total volumes (Bbls)		1,097,510		1,784,914		1,240,171		936,741		198,000
Weighted average price	$	0.51	$	0.27	$	0.12	$	(0.03)	$	—
Natural gas:
Fixed-price swap:
Total volumes (MMBtu)		2,925,851		4,423,784		3,687,113		1,979,033		—
Weighted average price	$	3.71	$	3.54	$	3.35	$	4.00	$	—
Two-way collar:
Total volumes (MMBtu)		1,082,869		2,610,639		1,651,321		2,063,812		900,000
Weighted average price (call)	$	5.21	$	5.08	$	5.12	$	5.26	$	5.75
Weighted average price (put)	$	3.76	$	3.67	$	3.72	$	3.70	$	4.25
Basis swap:
Total volumes (MMBtu)		4,008,720		7,034,372		5,319,878		4,042,845		900,000
Weighted average price	$	(0.89)	$	(0.87)	$	(0.67)	$	(0.77)	$	(0.78)

Schedule of potential effects of master netting arrangements on the fair value of derivative contracts


	Derivative Assets				Derivative Liabilities
Offsetting of Derivative Assets and Liabilities	June 30, 2023		December 31, 2022		June 30, 2023		December 31, 2022

Gross Amounts - Consolidated Balance Sheet	$	14,910	$	21,623	$	(32,886)	$	(62,935)
Amounts Not Offset - Consolidated Balance Sheet		(11,762)		(20,997)		11,762		20,997
Net Amount	$	3,148	$	626	$	(21,124)	$	(41,938)

ASSET RETIREMENT OBLIGATIONS (Tables)

6 Months Ended

Jun. 30, 2023

ASSET RETIREMENT OBLIGATIONS

Schedule of activity related to ARO liability

The Company recorded the following activity related to its ARO liability (in thousands):


Liability for asset retirement obligations as of December 31, 2022	$	15,469
Accretion expense		372
Liabilities incurred during the period		11
Liability for asset retirement obligations as of June 30, 2023		15,852

EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2023

EARNINGS PER SHARE

Schedule of calculation of earnings (loss) per share

The following represents the calculation of earnings (loss) per share (in thousands, except per share amounts):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2023		2022		2023		2022
Basic:
Net income (loss)	$	(4,748)	$	13,047	$	18,063	$	(79,697)
Less: Preferred stock dividend		(997)		—		(2,489)		—
Less: Undistributed earnings allocable to preferred shareholders		—		—		(1,301)		—
Net income (loss) available to common stockholders	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Basic net income (loss) per share of common stock	$	(0.35)	$	0.80	$	0.87	$	(4.88)

Diluted:
Net income (loss) available to common stockholders basic	$	(5,745)	$	13,047	$	14,273	$	(79,697)
Reallocation of undistributed earnings		—		—		7		—
Net income (loss) available to common stockholders diluted	$	(5,745)	$	13,047	$	14,280	$	(79,697)

Weighted average basic number of common shares outstanding basic		16,457		16,338		16,425		16,320
Common stock equivalent shares representing shares issuable upon:
Exercise of warrants and stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		Anti-dilutive		172		95		Anti-dilutive
Weighted average diluted number of common shares outstanding diluted		16,457		16,510		16,520		16,320
Diluted net income (loss) per share of common stock	$	(0.35)	$	0.79	$	0.86	$	(4.88)

ADDITIONAL FINANCIAL STATEMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2023

ADDITIONAL FINANCIAL STATEMENT INFORMATION

Schedule of additional financial statement information, balance sheet

Certain balance sheet amounts are comprised of the following (in thousands):


	June 30, 2023		December 31, 2022
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	19,853	$	33,980
Joint interest accounts		1,779		3,201
Other		1,886		793
	$	23,518	$	37,974
Prepaids and other:
Prepaids	$	509	$	715
Funds in escrow		343		341
Other		197		75
	$	1,049	$	1,131
Other assets (Non-current):
Investment in unconsolidated affiliate⁽¹⁾	$	1,477	$	1,561
Oil, natural gas and natural gas liquids revenues		24		—
Funds in escrow		538		527
Other		739		739
	$	2,778	$	2,827
Accounts payable and accrued liabilities:
Trade payables	$	17,884	$	42,919
Accrued oil and natural gas capital costs		1,928		19,911
Revenues and royalties payable		20,392		26,759
Accrued interest expense		104		160
Accrued employee compensation		1,190		2,300
Accrued lease operating expenses		7,388		8,005
Other		11		41
	$	48,897	$	100,095

(1)

FINANCIAL STATEMENT PRESENTATION (Details) $ in Thousands	3 Months Ended	6 Months Ended
FINANCIAL STATEMENT PRESENTATION (Details) $ in Thousands	Sep. 30, 2023 USD ($)	Jun. 30, 2023 USD ($) segment shareholder
Number of shareholders in private placement \| shareholder		3
Commitment letter from investors to purchase additional equity		$ 38,000
Proceeds from issuance of preferred stock		$ 24,375
Number of operating segments \| segment		1
Plan
Proceeds from issuance of preferred stock	$ 38,000

FINANCIAL STATEMENT PRESENTATION - Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022	Jun. 30, 2022	Dec. 31, 2021
FINANCIAL STATEMENT PRESENTATION
Cash and cash equivalents	$ 18,514	$ 32,726
Restricted cash	90	90
Total cash, cash equivalents and restricted cash	$ 18,604	$ 32,816	$ 43,775	$ 48,359

LEASES (Details) - USD ($) $ in Thousands	6 Months Ended
LEASES (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Lease cost
Operating lease costs	$ 196	$ 196
Short-term lease costs	375	4,003
Total lease costs	571	4,199
Other information
Operating cash flows from operating leases	$ 196	$ 196
Weighted-average remaining lease term - operating leases	4 months 24 days	1 year 4 months 24 days
Weighted-average discount rate - operating leases	4.29%	4.29%
Initial lease term	2 years 3 months 18 days		2 years 3 months 18 days

LEASES - Future Minimum Lease Payments (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Future minimum lease payments for non-cancellable operating leases
Remaining period in 2023	$ 163
Total operating lease payment	163
Less: discount to present value	(1)
Total operating lease liabilities	162
Less: current operating lease liabilities	$ 162	$ 352

OPERATING REVENUES - Revenue Recognition (Details) - USD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Accounts receivable
Disaggregation of operating revenue
Due from contracts with customers	$ 19.9	$ 34.0

OIL AND NATURAL GAS PROPERTIES - Ceiling Test Value of Company's Reserves (Details)	6 Months Ended
	Jun. 30, 2023 $ / bbl $ / MMBTU	Jun. 30, 2022 $ / bbl $ / MMBTU
Ceiling Limitation Disclosures
First-day-of-month 12-month average price for natural gas (in $/MMBtu) \| $ / MMBTU	4.76	5.13
First-day-of-month 12-month average price for crude oil used in ceiling test impairment (in dollars per barrel) \| $ / bbl	83.23	85.82

DEBT (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Current and long-term debt
Debt	$ 220,265	$ 235,190
Current Portion of Long-Term Debt(1)	(42,606)	(35,067)
Other(2)	(13,604)	(17,447)
Total long-term debt	164,055	182,676
Unamortized debt issuance costs	9,900	13,000
Term loan credit facility
Current and long-term debt
Debt	220,000	235,000
Paycheck Protection Program Loan [Member]
Current and long-term debt
Debt	$ 265	$ 190

DEBT - Term Loan Credit Facility (Details) $ in Thousands		3 Months Ended	6 Months Ended
DEBT - Term Loan Credit Facility (Details) $ in Thousands	Nov. 14, 2022 USD ($)	Jun. 30, 2023 USD ($) item	Jun. 30, 2023 USD ($) item	Jun. 30, 2022 USD ($)	Nov. 30, 2022 USD ($)	Apr. 30, 2022 USD ($)	Nov. 30, 2021 USD ($)
Debt Instrument [Line Items]
Lender fees paid			$ 3,843	$ 1,807
Term loan credit facility
Debt Instrument [Line Items]
Amount available for issuance of letters of credit		$ 5,000	$ 5,000
Basis spread on variable rate (as a percent)			0.50%
Weighted average interest rate			12.60%
Lender fees paid	$ 2,400
Maturity date			Nov. 24, 2025
Amount outstanding		220,300	$ 220,300				$ 200,000
Letters of credit outstanding		$ 1,400	$ 1,400
Covenant compliance			As of June 30, 2023, the Company was in compliance with the financial covenants under the Amended Term Loan Agreement.
Threshold from capital expenditures to cash balance			$ 20,000
Maximum number of additional approved plan of development wells if out of compliance with loan agreement \| item		6	6
Aggregate scheduled amortization payments		$ 105,000	$ 105,000
Term loan credit facility \| Minimum
Debt Instrument [Line Items]
Asset coverage ratio		180.00%
Current ratio		100.00%
Term loan credit facility \| Maximum
Debt Instrument [Line Items]
Net Leverage Ratio		250.00%
Term loan credit facility \| Prior to February 15, 2020
Debt Instrument [Line Items]
Interest plus			2.00%
Term loan credit facility \| Prior to February 15, 2020 \| Minimum
Debt Instrument [Line Items]
Debt instrument prepayment term			0 months
Term loan credit facility \| Prior to February 15, 2020 \| Maximum
Debt Instrument [Line Items]
Debt instrument prepayment term			12 months
Term loan credit facility \| February 15, 2020
Debt Instrument [Line Items]
Interest plus			2.00%
Term loan credit facility \| February 15, 2020 \| Minimum
Debt Instrument [Line Items]
Debt instrument prepayment term			13 months
Term loan credit facility \| February 15, 2020 \| Maximum
Debt Instrument [Line Items]
Debt instrument prepayment term			24 months
Term loan credit facility \| February 15, 2021
Debt Instrument [Line Items]
Interest plus			1.00%
Term loan credit facility \| February 15, 2021 \| Minimum
Debt Instrument [Line Items]
Debt instrument prepayment term			25 months
Term loan credit facility \| February 15, 2021 \| Maximum
Debt Instrument [Line Items]
Debt instrument prepayment term			36 months
Term loan credit facility \| February 15, 2022
Debt Instrument [Line Items]
Interest plus			0.00%
Term loan credit facility \| February 15, 2022 \| Minimum
Debt Instrument [Line Items]
Debt instrument prepayment term			37 months
Term loan credit facility \| February 15, 2022 \| Maximum
Debt Instrument [Line Items]
Debt instrument prepayment term			48 months
Term loan credit facility \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)			7.65%
Applicable margin (as a percent)			0.15%
Delayed Draw Term Loan
Debt Instrument [Line Items]
Incremental borrowing that we can make if we meet certain criteria					$ 15,000	$ 20,000

DEBT - Debt Maturities and Debt Issuance Costs (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Debt Issuance Costs
Debt issuance costs	$ 13,604	$ 17,447

FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	6 Months Ended
FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Assets
Asset transfers between levels	$ 0
Liabilities
Liability transfers between levels	0
Recurring \| Total
Assets
Receivables from derivative contracts	14,910	$ 21,623
Liabilities
Liabilities from derivative contracts	32,886	62,935
Recurring \| Level 2
Assets
Receivables from derivative contracts	14,910	21,623
Liabilities
Liabilities from derivative contracts	$ 32,886	$ 62,935

FAIR VALUE MEASUREMENTS - Change of Control Call Option (Details) - Change of Control Call Option $ in Thousands	6 Months Ended
	Jun. 30, 2023 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance at the beginning of the period	$ 4,136
Change in fair value	(704)
Balance at the end of the period	$ 3,432

DERIVATIVE AND HEDGING ACTIVITIES - (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Derivative and hedging activities
Asset derivative contracts	$ 14,910	$ 21,623
Liability derivative contracts	(32,886)	(62,935)
Derivatives not designated as hedging contracts
Derivative and hedging activities
Asset derivative contracts	14,910	21,623
Liability derivative contracts	(32,886)	(62,935)
Derivatives not designated as hedging contracts \| Commodity contracts \| Current assets - receivables from derivative contracts
Derivative and hedging activities
Asset derivative contracts	9,611	16,244
Derivatives not designated as hedging contracts \| Commodity contracts \| Other noncurrent assets - receivables from derivative contracts
Derivative and hedging activities
Asset derivative contracts	5,299	5,379
Derivatives not designated as hedging contracts \| Commodity contracts \| Current liabilities - liabilities from derivative contracts
Derivative and hedging activities
Liability derivative contracts	(15,480)	(29,286)
Derivatives not designated as hedging contracts \| Commodity contracts \| Other noncurrent liabilities - liabilities from derivative contracts
Derivative and hedging activities
Liability derivative contracts	$ (17,406)	$ (33,649)

DERIVATIVE AND HEDGING ACTIVITIES - Realized Unrealized (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivative and hedging activities
Total net gain (loss) on derivative contracts	$ 4,473	$ (31,910)	$ 23,946	$ (155,768)
Derivatives not designated as hedging contracts \| Commodity contracts
Derivative and hedging activities
Total net gain (loss) on derivative contracts	4,473	(31,910)	23,946	(155,768)
Derivatives not designated as hedging contracts \| Commodity contracts \| Other Income Expense
Derivative and hedging activities
Unrealized gain (loss) on commodity contracts	2,332	12,837	23,336	(78,201)
Realized gain (loss) on commodity contracts	$ 2,141	$ (44,747)	$ 610	$ (77,567)

DERIVATIVE AND HEDGING ACTIVITIES - Open Contracts (Details)	6 Months Ended
	Jun. 30, 2023 MMBTU $ / bbl $ / MMBTU bbl
January 2023 - December 2023 \| Fixed Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	2,925,851
January 2023 - December 2023 \| Fixed Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.71
January 2023 - December 2023 \| Fixed Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,115,335
January 2023 - December 2023 \| Fixed Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	67.36
January 2023 - December 2023 \| Basis Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	4,008,720
January 2023 - December 2023 \| Basis Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.89)
January 2023 - December 2023 \| Basis Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,047,536
January 2023 - December 2023 \| Basis Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.40
January 2023 - December 2023 \| WTI NYMEX Roll \| Crude oil \| Maximum
Derivative and hedging activities
Volume in Bbl's \| bbl	1,097,510
January 2023 - December 2023 \| WTI NYMEX Roll \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.51
January 2023 - December 2023 \| Collars \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	1,082,869
January 2023 - December 2023 \| Call option \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	5.21
January 2023 - December 2023 \| Put options \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.76
January 2024 - December 2024 \| Fixed Swap \| Natural Gas [Member] \| Minimum
Derivative and hedging activities
Floor (in dollars per Mmbtu's/Bbl's)	4,423,784
January 2024 - December 2024 \| Fixed Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.54
January 2024 - December 2024 \| Fixed Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,805,885
January 2024 - December 2024 \| Fixed Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	63.69
January 2024 - December 2024 \| Basis Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	7,034,372
January 2024 - December 2024 \| Basis Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.87)
January 2024 - December 2024 \| Basis Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,801,951
January 2024 - December 2024 \| Basis Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.27
January 2024 - December 2024 \| WTI NYMEX Roll \| Crude oil \| Maximum
Derivative and hedging activities
Volume in Bbl's \| bbl	1,784,914
January 2024 - December 2024 \| WTI NYMEX Roll \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.27
January 2024 - December 2024 \| Collars \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	2,610,639
January 2024 - December 2024 \| Call option \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	5.08
January 2024 - December 2024 \| Put options \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.67
January 2025 - December 2025 \| Fixed Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	3,687,113
January 2025 - December 2025 \| Fixed Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.35
January 2025 - December 2025 \| Fixed Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,240,171
January 2025 - December 2025 \| Fixed Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	61.18
January 2025 - December 2025 \| Basis Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	5,319,878
January 2025 - December 2025 \| Basis Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.67)
January 2025 - December 2025 \| Basis Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	1,240,171
January 2025 - December 2025 \| Basis Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.18
January 2025 - December 2025 \| WTI NYMEX Roll \| Crude oil \| Maximum
Derivative and hedging activities
Volume in Bbl's \| bbl	1,240,171
January 2025 - December 2025 \| WTI NYMEX Roll \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.12
January 2025 - December 2025 \| Collars \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	1,651,321
January 2025 - December 2025 \| Call option \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	5.12
January 2025 - December 2025 \| Put options \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.72
January 2026 - December 2026 \| Fixed Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	1,979,033
January 2026 - December 2026 \| Fixed Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	4.00
January 2026 - December 2026 \| Fixed Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	936,741
January 2026 - December 2026 \| Fixed Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	63.56
January 2026 - December 2026 \| Basis Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	4,042,845
January 2026 - December 2026 \| Basis Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.77)
January 2026 - December 2026 \| Basis Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	936,741
January 2026 - December 2026 \| Basis Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	(0.01)
January 2026 - December 2026 \| WTI NYMEX Roll \| Crude oil \| Maximum
Derivative and hedging activities
Volume in Bbl's \| bbl	936,741
January 2026 - December 2026 \| WTI NYMEX Roll \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	(0.03)
January 2026 - December 2026 \| Collars \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	2,063,812
January 2026 - December 2026 \| Call option \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	5.26
January 2026 - December 2026 \| Put options \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.70
January 2027 - December 2027 \| Fixed Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	198,000
January 2027 - December 2027 \| Fixed Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	59.64
January 2027 - December 2027 \| Basis Swap \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	900,000
January 2027 - December 2027 \| Basis Swap \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.78)
January 2027 - December 2027 \| Basis Swap \| Crude oil
Derivative and hedging activities
Volume in Bbl's \| bbl	198,000
January 2027 - December 2027 \| Basis Swap \| Crude oil \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) \| $ / bbl	0.40
January 2027 - December 2027 \| WTI NYMEX Roll \| Crude oil \| Maximum
Derivative and hedging activities
Volume in Bbl's \| bbl	198,000
January 2027 - December 2027 \| Collars \| Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's \| MMBTU	900,000
January 2027 - December 2027 \| Call option \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	5.75
January 2027 - December 2027 \| Put options \| Natural Gas [Member] \| Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	4.25

DERIVATIVE AND HEDGING ACTIVITIES - Netting Arrangements (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Derivative Assets
Gross Amounts Presented in the Consolidated Balance Sheet	$ 14,910	$ 21,623
Amounts Not Offset in the Consolidated Balance Sheet	(11,762)	(20,997)
Net Amount	3,148	626
Derivative Liabilities
Gross Amounts Presented in the Consolidated Balance Sheet	(32,886)	(62,935)
Amounts Not Offset in the Consolidated Balance Sheet	11,762	20,997
Net Amount	$ (21,124)	$ (41,938)

ASSET RETIREMENT OBLIGATIONS (Details) $ in Thousands	6 Months Ended
ASSET RETIREMENT OBLIGATIONS (Details) $ in Thousands	Jun. 30, 2023 USD ($)
Activity related to ARO liability
Asset retirement obligations at beginning of the period	$ 15,469
Accretion expense	372
Liabilities incurred	11
Asset retirement obligations at end of period	$ 15,852

COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	1 Months Ended	6 Months Ended	12 Months Ended
COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	May 31, 2022 USD ($) MMcf / d $ / Mcf	Jun. 30, 2023	Dec. 31, 2024 MMcf / d
Obligations under drilling rig commitments
Commitment next year \| $	$ 7.3
Minimum volume commitment	20,000
Volume commitment term	5 years
Minimum
Obligations under drilling rig commitments
Treating rate paid \| $ / Mcf	1.65
Gathering, transportation and sales \| West Texas \| Minimum
Obligations under drilling rig commitments
Period of commitment for production from the date of first production		1 year
Gathering, transportation and sales \| West Texas \| Maximum
Obligations under drilling rig commitments
Period of commitment for production from the date of first production		20 years
Plan
Obligations under drilling rig commitments
Minimum volume commitment			12,000

REDEEMABLE CONVERTIBLE PREFERRED STOCK (Details) $ / shares in Units, $ in Thousands			3 Months Ended		6 Months Ended
	Jun. 30, 2023 USD ($) shareholder	Mar. 28, 2023 USD ($) shareholder person $ / shares shares	Jun. 30, 2023 USD ($) shareholder	Mar. 31, 2023 USD ($)	Jun. 30, 2023 USD ($) shareholder
Class of Stock [Line Items]
Number of Shareholders in Private Placement \| shareholder	3		3		3
Board of directors, members \| person		6
Series A redeemable convertible preferred stock	$ 26,030	$ 23,500	$ 26,030		$ 26,030
Series A redeemable convertible preferred stock redemption amount	25,000	25,000	25,000		25,000
Deemed dividends for Series A preferred stock				$ 1,492	1,500
Redeemable Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Proceeds from preferred stock offering		24,400
Beneficial conversion proceeds		$ 600
Shares issued \| shares		25,000
Number of Shareholders in Private Placement \| shareholder		3
Series A redeemable convertible preferred stock redemption amount	26,000		$ 26,000		$ 26,000
Deemed dividends for Series A preferred stock	$ 1,000
Preferred stock voting rights		no
Dividend rate (as a percent)		14.50%
Liquidation preference per share (in dollars per share) \| $ / shares		$ 1,000
Preferred Stock, Liquidation Preference, Value		$ 25,000
Percentage of liquidation preference paid to redeem shares	107.50%	18.00%	107.50%		107.50%
Threshold of time following change of control		20 days
Percentage of common stock value over Conversion Price threshold		130.00%
Period past maturity date of term loan agreement if election of cash payment option is not permitted			1 year
Redeemable Convertible Preferred Stock [Member] \| Maximum
Class of Stock [Line Items]
Threshold of time following change of control			150 days
Redeemable Convertible Preferred Stock [Member] \| Annually [Member]
Class of Stock [Line Items]
Dividend rate (as a percent)		16.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period One [Member]
Class of Stock [Line Items]
Percentage of liquidation preference paid to redeem shares		100.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period One [Member] \| Maximum
Class of Stock [Line Items]
Redemption feature, time period after closing date			120 days
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Two [Member]
Class of Stock [Line Items]
Percentage of liquidation preference paid to redeem shares		102.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Two [Member] \| Minimum
Class of Stock [Line Items]
Redemption feature, time period after closing date			120 days
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Two [Member] \| Maximum
Class of Stock [Line Items]
Redemption feature, time period after closing date			180 days
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Three [Member]
Class of Stock [Line Items]
Percentage of liquidation preference paid to redeem shares		105.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Three [Member] \| Minimum
Class of Stock [Line Items]
Redemption feature, time period after closing date			180 days
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Three [Member] \| Maximum
Class of Stock [Line Items]
Redemption feature, time period after closing date			1 year
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Four [Member]
Class of Stock [Line Items]
Percentage of liquidation preference paid to redeem shares		108.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Four [Member] \| Minimum
Class of Stock [Line Items]
Redemption feature, time period after closing date			1 year
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Four [Member] \| Maximum
Class of Stock [Line Items]
Redemption feature, time period after closing date			2 years
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Five [Member]
Class of Stock [Line Items]
Percentage of liquidation preference paid to redeem shares		120.00%
Redeemable Convertible Preferred Stock [Member] \| Redemption Period Five [Member] \| Minimum
Class of Stock [Line Items]
Redemption feature, time period after closing date			2 years

STOCKHOLDERS' EQUITY - Incentive Plans (Details) - USD ($) shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Directors and employees
Stock-based compensation
Compensation expense recorded		$ 0.9
Allocated share based compensation credit	$ (0.5)
2020 Incentive Plan
Stock-based compensation
Aggregate number of shares available	1.8
Maximum number of shares that remained reserved for issuance under the Plan	0.6

STOCKHOLDERS' EQUITY - Restricted Stock (Details) - Restricted Stock $ / shares in Units, shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) $ / shares shares
Stock-based compensation
Number of shares granted \| shares	0.1
Granted (in dollars per share) \| $ / shares	$ 10.68
Unrecognized compensation expense other than options \| $	$ 1.3
Minimum
Stock-based compensation
Vesting period	3 years
Maximum
Stock-based compensation
Vesting period	4 years
Weighted average remaining vesting period	1 year

STOCKHOLDERS' EQUITY - Stock Options (Details) - Stock options $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) shares
Stock-based compensation
Vesting period	4 years
Percentage of awards vesting on the annual anniversary date of the grant	0.25
Expiration term	7 years
Unrecognized compensation expense stock option \| $	$ 0.1
Weighted average remaining vesting period	1 year
Granted (in shares) \| shares	0

EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended						6 Months Ended
	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022
Basic:
Net income (loss)	$ (4,748)	$ 22,811	$ (7,652)	$ 105,888	$ 13,047	$ (92,744)	$ 18,063	$ (79,697)
Less: Preferred stock dividend	(997)						(2,489)
Less: Undistributed earnings allocable to preferred shareholders							(1,301)
Net income (loss) available to common stockholders	$ (5,745)				$ 13,047		$ 14,273	$ (79,697)
Weighted average basic number of common shares outstanding - basic	16,457				16,338		16,425	16,320
Basic net income (loss) per share of common share (in dollars per share)	$ (0.35)				$ 0.80		$ 0.87	$ (4.88)
Diluted:
Net income (loss) available to common stockholders - basic	$ (5,745)				$ 13,047		$ 14,273	$ (79,697)
Reallocation of undistributed earnings							7
Net income (loss) available to common stockholders - diluted	$ (5,745)				$ 13,047		$ 14,280	$ (79,697)
Weighted average basic number of common shares outstanding - basic	16,457				16,338		16,425	16,320
Common stock equivalent shares representing shares included upon Vesting of restricted shares					172		95
Weighted average diluted number of common shares outstanding - diluted	16,457				16,510		16,520	16,320
Diluted net income (loss) per share of common stock (in dollars per share)	$ (0.35)				$ 0.79		$ 0.86	$ (4.88)
Common stock equivalents excluded from computation of diluted earnings per share of common stock because of anti-dilutive effect	600				7,400		500	7,700

ADDITIONAL FINANCIAL STATEMENT INFORMATION (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022	May 31, 2022
Accounts receivable:
Oil, natural gas and natural gas liquids revenues	$ 19,853	$ 33,980
Joint interest accounts	1,779	3,201
Other	1,886	793
Total	23,518	37,974
Prepaids and other:
Prepaids	509	715
Funds in escrow	343	341
Other	197	75
Total	1,049	1,131
Other assets:
Investment in unconsolidated affiliate	1,477	1,561
Oil, natural gas and natural gas liquids revenues	24
Funds in escrow	538	527
Other	739	739
Total	2,778	2,827
Accounts payable and accrued liabilities:
Trade payables	17,884	42,919
Accrued oil and natural gas capital costs	1,928	19,911
Revenues and royalties payable	20,392	26,759
Accrued interest expense	104	160
Accrued employee compensation	1,190	2,300
Accrued lease operating expenses	7,388	8,005
Other	11	41
Total	$ 48,897	$ 100,095
Brazos Amine Treater, LLC [Member]
Accounts payable and accrued liabilities:
Equity interest			5.00%