10-Q

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, 2022
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 4, 2022, 16,337,910 shares of the Registrant’s Common Stock were outstanding.

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, 2022 and 2021	5
	Condensed Consolidated Balance Sheets (Unaudited) as of June 30, 2022 and December 31, 2021	6
	Condensed Consolidated Statements of Stockholders’ Equity (Unaudited) for the Six Months Ended June 30, 2022 and the Year Ended December 31, 2021	7
	Condensed Consolidated Statements of Cash Flows (Unaudited) for the Six Months Ended June 30, 2022 and 2021	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	36
ITEM 4.	Controls and Procedures	37
PART II	OTHER INFORMATION
ITEM 1.	Legal Proceedings	37
ITEM 1A.	Risk Factors	37
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	38
ITEM 3.	Defaults Upon Senior Securities	38
ITEM 4.	Mine Safety Disclosures	38
ITEM 5.	Other Information	38
ITEM 6.	Exhibits	38
Signatures		40

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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 certain 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, 2021, 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 commodity 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;

● 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;

● 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 large inventory of undeveloped acreage;

● our ability to secure adequate sour gas treating and/or sour gas take-away capacity in our Monument Draw area sufficient to handle production volumes;

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

● the cost and availability of goods and services, such as drilling rigs, fracture stimulation services and tubulars;

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

● 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;

● 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;

● 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;

● 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

3

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;

● 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.

4

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,
	2022		2021		2022		2021
Operating revenues:
Oil, natural gas and natural gas liquids sales:
Oil	$	73,944	$	51,935	$	136,468	$	93,205
Natural gas		14,759		5,317		23,640		14,404
Natural gas liquids		12,587		6,851		22,590		11,760
Total oil, natural gas and natural gas liquids sales		101,290		64,103		182,698		119,369
Other		221		263		415		515
Total operating revenues		101,511		64,366		183,113		119,884
Operating expenses:
Production:
Lease operating		11,909		10,169		23,433		19,636
Workover and other		1,383		767		2,248		1,327
Taxes other than income		5,372		2,912		10,323		6,104
Gathering and other		15,869		14,331		31,124		27,502
General and administrative		4,588		4,031		9,573		8,858
Depletion, depreciation and accretion		12,601		11,249		22,821		21,844
Total operating expenses		51,722		43,459		99,522		85,271
Income (loss) from operations		49,789		20,907		83,591		34,613
Other income (expenses):
Net gain (loss) on derivative contracts		(31,910)		(53,089)		(155,768)		(98,800)
Interest expense and other		(4,832)		(1,747)		(7,520)		(3,117)
Total other income (expenses)		(36,742)		(54,836)		(163,288)		(101,917)
Income (loss) before income taxes		13,047		(33,929)		(79,697)		(67,304)
Income tax benefit (provision)		—		—		—		—
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Net income (loss) per share of common stock:
Basic	$	0.80	$	(2.09)	$	(4.88)	$	(4.14)
Diluted	$	0.79	$	(2.09)	$	(4.88)	$	(4.14)
Weighted average common shares outstanding:
Basic		16,338		16,268		16,320		16,250
Diluted		16,510		16,268		16,320		16,250

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

5

BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

(In thousands, except share and per share amounts)

	June 30, 2022		December 31, 2021
Current assets:
Cash and cash equivalents	$	43,640	$	46,864
Accounts receivable, net		53,002		36,806
Assets from derivative contracts		6,146		1,383
Restricted cash		135		1,495
Prepaids and other		927		1,366
Total current assets		103,850		87,914
Oil and natural gas properties (full cost method):
Evaluated		632,004		569,886
Unevaluated		64,760		64,305
Gross oil and natural gas properties		696,764		634,191
Less - accumulated depletion		(362,257)		(339,776)
Net oil and natural gas properties		334,507		294,415
Other operating property and equipment:
Other operating property and equipment		4,045		3,467
Less - accumulated depreciation		(1,027)		(1,035)
Net other operating property and equipment		3,018		2,432
Other noncurrent assets:
Assets from derivative contracts		3,972		2,515
Operating lease right of use assets		539		721
Other assets		3,329		2,270
Total assets	$	449,215	$	390,267
Current liabilities:
Accounts payable and accrued liabilities	$	97,334	$	62,826
Liabilities from derivative contracts		91,750		58,322
Current portion of long-term debt		15,000		85
Operating lease liabilities		377		369
Asset retirement obligations		401		—
Total current liabilities		204,862		121,602
Long-term debt, net		188,372		181,565
Other noncurrent liabilities:
Liabilities from derivative contracts		58,138		7,144
Asset retirement obligations		11,686		11,896
Operating lease liabilities		162		352
Other		1,408		4,003
Commitments and contingencies (Note 9)
Stockholders' equity:
Common stock: 100,000,000 shares of $0.0001 par value authorized;
16,337,910 and 16,273,913 shares issued and outstanding as of
June 30, 2022 and December 31, 2021, respectively		2		2
Additional paid-in capital		332,766		332,187
Retained earnings (accumulated deficit)		(348,181)		(268,484)
Total stockholders' equity		(15,413)		63,705
Total liabilities and stockholders' equity	$	449,215	$	390,267

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

6

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		—		—		—		—
Reduction in shares to cover
individuals' tax withholding	(26)		—		(461)		—		(461)
Stock-based compensation	—		—		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		—		—		—		—
Reduction in shares to cover
individuals' tax withholding	—		—		(6)		—		(6)
Stock-based compensation	—		—		594		—		594
Balances at June 30, 2022	16,338		2		332,766		(348,181)		(15,413)

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

7

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, 2020	16,204	$	2	$	330,123	$	(240,167)	$	89,958
Net income (loss)	—		—		—		(33,375)		(33,375)
Long-term incentive plan vestings	87		—		—		—		—
Reduction in shares to cover
individuals' tax withholding	(24)		—		(264)		—		(264)
Stock-based compensation	—		—		692		—		692
Balances at March 31, 2021	16,267		2		330,551		(273,542)		57,011
Net income (loss)	—		—		—		(33,929)		(33,929)
Long-term incentive plan vestings	1		—		—		—		—
Reduction in shares to cover
individuals' tax withholding	—		—		(5)		—		(5)
Stock-based compensation	—		—		571		—		571
Balances at June 30, 2021	16,268		2		331,117		(307,471)		23,648
Net income (loss)	—		—		—		13,052		13,052
Long-term incentive plan vestings	8		—		—		—		—
Reduction in shares to cover
individuals' tax withholding	(2)		—		(22)		—		(22)
Stock-based compensation	—		—		565		—		565
Balances at September 30, 2021	16,274		2		331,660		(294,419)		37,243
Net income (loss)	—		—		—		25,935		25,935
Stock-based compensation	—		—		527		—		527
Balances at December 31, 2021	16,274	$	2	$	332,187	$	(268,484)	$	63,705

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

8

BATTALION OIL CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(In thousands)

	Six Months Ended
	June 30,
	2022		2021
Cash flows from operating activities:
Net income (loss)	$	(79,697)	$	(67,304)
Adjustments to reconcile net income (loss) to net cash
provided by (used in) operating activities:
Depletion, depreciation and accretion		22,821		21,844
Stock-based compensation, net		857		1,079
Unrealized loss (gain) on derivative contracts		78,201		70,869
Amortization of deferred loan costs		1,807		—
(Gain) loss on sale of other assets		(96)		—
Reorganization items		(744)		—
Accrued settlements on derivative contracts		14,652		6,972
Change in fair value of Change of Control Call Option		(2,595)		—
Other income (expense)		—		(287)
Change in assets and liabilities:
Accounts receivable		(12,596)		(5,488)
Prepaids and other		438		(441)
Accounts payable and accrued liabilities		5,285		1,856
Net cash provided by (used in) operating activities		28,333		29,100
Cash flows from investing activities:
Oil and natural gas capital expenditures		(51,377)		(37,593)
Proceeds received from sale of oil and natural gas properties		—		926
Other operating property and equipment capital expenditures		(705)		—
Proceeds received from sale of other operating property and equipment		96		—
Funds held in escrow and other		—		(2)
Net cash provided by (used in) investing activities		(51,986)		(36,669)
Cash flows from financing activities:
Proceeds from borrowings		20,000		82,000
Repayments of borrowings		(85)		(77,000)
Debt issuance costs		(379)		—
Other		(467)		(268)
Net cash provided by (used in) financing activities		19,069		4,732
Net increase (decrease) in cash, cash equivalents and restricted cash		(4,584)		(2,837)
Cash, cash equivalents and restricted cash at beginning of period		48,359		4,295
Cash, cash equivalents and restricted cash at end of period	$	43,775	$	1,458
Supplemental cash flow information:
Cash paid for reorganization items	$	744	$	—

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

9

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 7, 2022. Please refer to the notes in the Annual Report on Form 10-K for the year ended December 31, 2021 when reviewing interim financial results. The Company has evaluated events or transactions through the date of issuance of these unaudited condensed consolidated financial statements.

Risk and Uncertainties

The Company is continuously monitoring the current and potential impacts of the novel coronavirus (COVID-19) pandemic on its business, including how it has and may continue to impact its operations, financial results, liquidity, contractors, customers, employees and vendors, and taking appropriate actions in response, including implementing various measures to ensure the continued operation of its business in a safe and secure manner.

During 2021, widespread availability of COVID-19 vaccines in the United States and elsewhere combined with accommodative governmental monetary and fiscal policies and other factors, led to a rebound in demand for oil and natural gas and increases in oil and natural gas prices. Further, in 2022, the effects of Russian sanctions amidst the conflict with Ukraine have pushed oil and gas prices higher. However, there remains the potential for demand for oil and natural gas to be adversely impacted by the economic effects of rising interest rates and tightening monetary policies, as well as the ongoing COVID-19 pandemic, including as a consequence of the circulation of more infectious “variants” of the disease, vaccine hesitancy, waning vaccine effectiveness or 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. The results presented in this Form 10-Q are not necessarily indicative of future operating results.

Additionally, in periods of increasing commodity prices, the Company continues 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.

For further information regarding the actual and potential impacts of COVID-19 and supply chain issues on the Company, see “Risk Factors” in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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, 2022		December 31, 2021
Cash and cash equivalents	$	43,640	$	46,864
Restricted cash		135		1,495
Total cash, cash equivalents and restricted cash	$	43,775	$	48,359

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. The Company establishes provisions for losses on accounts receivable if it determines that collection of all or part of the outstanding balance is doubtful. The Company regularly reviews collectability and establishes or adjusts the allowance for doubtful accounts as necessary using the specific identification method. As of June 30, 2022 and December 31, 2021, allowances for doubtful accounts were approximately $0.2 million for both periods.

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

11

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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, 2022, the Company’s derivative counterparties include two major financial institutions, both of which are secured lenders under the Term Loan Agreement.

Recently Issued Accounting Pronouncements

In March 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2020-04, Reference Rate Reform (Topic 848) (ASU 2020-04), in response to the risk of cessation of the London Interbank Offered Rate (LIBOR). This amendment provides optional expedients and exceptions for applying generally accepted accounting principles to contracts, hedging arrangements, and other transactions that reference LIBOR. ASU 2020-04 will be in effect through December 31, 2022. As of the date of this filing, ASU 2020-04 has not had a material impact on the Company’s operating results, financial position and disclosures.

2. LEASES

The Company leases equipment and office space pursuant to net operating leases. Operating leases where the Company is the lessee are included in “Operating lease right of use assets” and “Operating lease liabilities” on the unaudited condensed consolidated balance sheets. The lease liabilities are initially and subsequently measured at the present value of the unpaid lease payments at the lease commencement date. The Company has no leases that meet the criteria for classification as a finance lease.

Variable lease payments associated with the Company’s leases are recognized when the event, activity, or 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 unaudited condensed consolidated statements of operations in the same line item as the expense arising from the fixed lease payments on the operating leases.

The Company elected not to recognize right of use assets and lease liabilities for all short-term leases that have a lease term of 12 months or less. The Company recognizes the lease payments associated with its short-term leases when incurred. Variable lease payments associated with these leases are recognized and presented in the same manner as for all other leases.

The “Operating lease right of use assets” outstanding on the unaudited condensed consolidated balance sheets as of June 30, 2022 and December 31, 2021 both have initial lease terms 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, 2022 and 2021 (in thousands, except term and discount rate):

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

	Six Months Ended
	June 30,
	2022			2021
Lease cost
Operating lease costs	$	196		$	235
Short-term lease costs		4,003			1,889
Variable lease costs		—			229
Total lease costs	$	4,199		$	2,353
Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	328
Weighted-average remaining lease term - operating leases		1.4	years		0.2	years
Weighted-average discount rate - operating leases		4.29	%		3.70	%

Future minimum lease payments associated with the Company’s non-cancellable operating leases for office space as of June 30, 2022 are presented in the table below (in thousands):

	June 30, 2022
Remaining period in 2022	$	196
2023		359
2024		—
2025		—
2026		—
Thereafter		—
Total operating lease payments		555
Less: discount to present value		16
Total operating lease liabilities		539
Less: current operating lease liabilities		377
Noncurrent operating lease liabilities	$	162

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 the commodity to the customer. Revenue is measured based on consideration specified in a contract with a customer 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. Because the Company’s performance obligations have been satisfied and an unconditional right

13

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

to consideration exists as of the balance sheet date, the Company recognized amounts due from contracts with customers of $47.6 million and $35.1 million as of June 30, 2022 and December 31, 2021, respectively, as “Accounts receivable” and “Other assets” on the unaudited condensed consolidated balance sheets.

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, 2022, the ceiling test value of the Company’s reserves was calculated based on the first-day-of-the-month average for the 12-months ended June 30, 2022 of the West Texas Intermediate (WTI) crude oil spot price of $85.82 per barrel, adjusted by lease or field for quality, transportation fees, and regional price differentials, and the first-day-of-the-month average for the 12-months ended June 30, 2022 of the Henry Hub natural gas price of $5.13 per MMBtu, adjusted by lease or field for energy content, transportation fees, and regional price differentials. Using these prices, the Company’s net book value of oil and natural gas properties at June 30, 2022 did not exceed the ceiling amount.

At June 30, 2021, the ceiling test value of the Company’s reserves was calculated based on the first-day-of-the-month average for the 12-months ended June 30, 2021 of the WTI crude oil spot price of $49.72 per barrel, adjusted by lease or field for quality, transportation fees, and regional price differentials, and the first-day-of-the-month average for the 12-months ended June 30, 2021 of the Henry Hub natural gas price of $2.43 per MMBtu, adjusted by lease or field for energy content, transportation fees, and regional price differentials. Using these prices, the Company’s net book value of oil and natural gas properties at June 30, 2021 did not exceed the ceiling amount.

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.

14

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

5. DEBT

As of June 30, 2022 and December 31, 2021, the Company’s debt consisted of the following (in thousands):

	June 30, 2022		December 31, 2021
Term loan credit facility(1)	$	203,372	$	181,565
Paycheck Protection Program loan		—		85
Total debt, net		203,372		181,650
Current portion of long-term debt(2)		15,000		85
Total long-term debt, net	$	188,372	$	181,565

(1) Amount is net of $12.4 million and $14.2 million in unamortized debt issuance costs at June 30, 2022 and December 31, 2021, respectively. Amount also excludes the initial fair value allocated to the change of control call option embedded derivative of $4.2 million. Refer to “Term Loan Credit Facility” below for further details.

(2) As of June 30, 2022, amount represents amortization payments of $15.0 million under the Term Loan Agreement due within one year. As of December 31, 2021, amount represents the balance owed under the Company’s Paycheck Protection Program Loan.

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. The Term Loan Agreement amends and restates in its entirety the senior secured revolving credit agreement, as amended, (the Senior Credit Agreement) entered into in 2019 as further discussed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2021. Pursuant to the Term Loan Agreement, the lenders have agreed to loan the Company (i) $200.0 million, which was funded on November 24, 2021 and was partially used to refinance all amounts owed under the Senior Credit Agreement; (ii) up to $20.0 million under the first delayed draw of the Term Loan Agreement, which was drawn on April 29, 2022 and (iii) up to $15.0 million, which amount will be available to be drawn from the date certain wells included in the approved plan of development (APOD) are deemed producing APOD wells until up to 18 months after November 24, 2021, subject to the satisfaction of certain conditions. An additional $5.0 million is available for the issuance of letters of credit. The maturity date of the Term Loan Agreement is November 24, 2025. Until such maturity date, borrowings under the Term Loan Agreement bear interest at a rate per annum equal to LIBOR (or another applicable reference rate, as determined pursuant to the provisions of the Term Loan Agreement) plus an applicable margin of 7.00%.

At June 30, 2022, the Company had $220.0 million indebtedness outstanding and approximately $1.3 million letters of credit outstanding under the Term Loan Agreement. The Company also has available $15.0 million in delayed draw term loans, subject to the satisfaction of certain conditions defined in the agreement.

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

Period	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%

15

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

The Company may be required to make mandatory prepayments under the 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 Term Loan Agreement, exceeds $20.0 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 Company is required to make scheduled amortization payments in the aggregate amount of $120.0 million from the fiscal quarter ending March 31, 2023 through the fiscal quarter ending September 30, 2025. Amounts outstanding under the 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 Term Loan Agreement there are certain restrictions on the transfer of assets, including cash, to Battalion from the guarantor subsidiaries.

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

● Asset Coverage Ratio of not less than 1.60 to 1.00 as of June 30, 2022, 1.70 to 1.00 as of September 30, 2022, and 1.80 to 1.00 as of December 31, 2022 and each fiscal quarter thereafter

● Total Net Leverage Ratio of not greater than 3.25 to 1.00 as of June 30, 2022, 3.00 to 1.00 as of September 30, 2022 and December 31, 2022, 2.75 to 1.00 as of March 31, 2023, and 2.50 to 1.00 as of each fiscal quarter thereafter, and

● Current Ratio of not less than 1.00 to 1.00, each determined as of the last day of any fiscal quarter period.

As of June 30, 2022, the Company was in compliance with the financial covenants under the Term Loan Agreement.

The Term Loan Agreement also contains an APOD for the Company’s Monument Draw acreage through the drilling and completion of certain wells. The 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 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 the Term Loan Agreement, 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 Chief 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 Company determined that the Change of Control Call Option was an embedded derivative, concluded the embedded derivative was not clearly and closely related to the host debt instrument, and recorded the initial $4.2 million fair value separately on the unaudited condensed consolidated balance sheet within “Other noncurrent liabilities.” The Change of Control Call Option is subsequently remeasured at fair value each reporting period with fair value changes recorded 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, the significant inputs to the valuation, and for a reconciliation of the change in fair value of the Change of Control Call Option.

16

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Paycheck Protection Program Loan

In 2020, the Company entered into a promissory note (the PPP Loan) for a principal amount of approximately $2.2 million under the Paycheck Protection Program of the CARES Act. Effective August 13, 2021, the principal amount of the Company’s PPP Loan was reduced to approximately $0.2 million upon forgiveness of $2 million based on the use of loan proceeds for eligible expenses under the CARES Act. The Company recorded a gain on the extinguishment of the forgiven portion of the PPP Loan and related accrued interest of $2.1 million presented in “Gain (loss) on extinguishment of debt” in the consolidated statements of operations during the quarter ended September 30, 2021. During the first quarter of 2022, the $0.2 million principal amount of the PPP loan was repaid in full.

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, 2022 and December 31, 2021 (in thousands):

	June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	10,118	$	—	$	10,118
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	149,888	$	—	$	149,888

	December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	3,898	$	—	$	3,898
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	65,466	$	—	$	65,466

17

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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.

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 recorded the fair value of the Change of Control Call Option separately on the unaudited condensed consolidated balance sheets in “Other noncurrent liabilities.” The fair value of the Change of Control Call Option is subsequently remeasured each reporting period with fair value changes recorded 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 LIBOR 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, 2021	$	4,003
Change in fair value		(2,595)
Balance at June 30, 2022	$	1,408

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 borrrowings under the Company’s 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 certain risks relating to its ongoing business operations, such as commodity price risk and interest rate risk. 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

18

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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, 2022, the Company did not post collateral under any of its derivative contracts as they are secured under the Company’s Term Loan Agreement.

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 derivative contracts in the unaudited condensed consolidated balance sheets as of June 30, 2022 and December 31, 2021 (in thousands):

Derivatives not designated as		Asset derivative contracts					Liability derivative contracts
hedging contracts under ASC 815	Balance sheet location	June 30, 2022		December 31, 2021		Balance sheet location	June 30, 2022		December 31, 2021
Commodity contracts	Current assets - assets from derivative contracts	$	6,146	$	1,383	Current liabilities - liabilities from derivative contracts	$	(91,750)	$	(58,322)
Commodity contracts	Other noncurrent assets - assets from derivative contracts		3,972		2,515	Other noncurrent liabilities - liabilities from derivative contracts		(58,138)		(7,144)
Total derivatives not designated as hedging contracts under ASC 815		$	10,118	$	3,898		$	(149,888)	$	(65,466)

19

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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):

		Amount of gain or (loss)				Amount of gain or (loss)
		recognized in income on				recognized in income on
		derivative contracts for the				derivative contracts for the
Derivatives not designated	Location of gain or	Three Months Ended				Six Months Ended
as hedging contracts	(loss) recognized in income	June 30,				June 30,
under ASC 815	on derivative contracts	2022		2021		2022		2021
Commodity contracts:
Unrealized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts	$	12,837	$	(34,817)	$	(78,201)	$	(70,869)
Realized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts		(44,747)		(18,272)		(77,567)		(27,931)
Total net gain (loss) on derivative contracts		$	(31,910)	$	(53,089)	$	(155,768)	$	(98,800)

At June 30, 2022, the Company had the following open crude oil and natural gas derivative contracts:

Instrument		2022	2023	2024	2025	2026
Crude oil fixed-price swap:
Total volumes (Bbls)		1,240,865	2,000,965	1,449,140	1,028,160	212,810
Weighted average price	$	52.80	65.75	60.91	59.69	59.83
Crude oil basis swap:
Total volumes (Bbls)		1,222,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.41	0.25	0.23	0.17	0.19
Crude oil WTI NYMEX roll:
Total volumes (Bbls)		1,005,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.10	0.50	0.28	0.10	0.27
Natural gas fixed-price swap:
Total volumes (MMBtu)		1,167,500	3,957,750	2,658,750	2,428,050
Weighted average price	$	3.92	3.36	3.09	3.00
Natural gas producer two-way collar:
Total volumes (MMBtu)		2,473,400	1,742,100	1,424,100	555,700	653,900
Weighted average price (call)	$	3.97	5.52	4.70	4.24	4.45
Weighted average price (put)	$	3.48	3.86	3.19	3.28	4.00
Natural gas basis swap:
Total volumes (MMBtu)		3,640,900	5,700,600	4,084,350	2,983,750	653,900
Weighted average price	$	(0.51)	(0.64)	(0.64)	(0.56)	(0.96)

20

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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, 2022 and December 31, 2021 (in thousands):

	Derivative Assets				Derivative Liabilities
Offsetting of Derivative Assets and Liabilities	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Gross Amounts Presented in the Consolidated Balance Sheet	$	10,118	$	3,898	$	(149,888)	$	(65,466)
Amounts Not Offset in the Consolidated Balance Sheet		(10,118)		(3,898)		10,118		3,898
Net Amount	$	—	$	—	$	(139,770)	$	(61,568)

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.

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

Liability for asset retirement obligations as of December 31, 2021	$	11,896
Liabilities incurred during the period		103
Liabilities settled during the period		(132)
Accretion expense		220
Liability for asset retirement obligations as of June 30, 2022	$	12,087

9. COMMITMENTS AND CONTINGENCIES

Commitments

As of June 30, 2022, the Company has a minimum volume commitment with a third party for the purchase of chemicals to treat sour gas production through December 31, 2022. The future payments associated with the minimum volume commitment are approximately $3.3 million.

As of June 30, 2022, the Company has an active drilling rig commitment of approximately $1.7 million through the third quarter of 2022. Termination of the active drilling rig commitment would require an early termination penalty of

21

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

$0.6 million, which would be in lieu of paying the active drilling rig commitment of $1.7 million. In July 2022, we extended our drilling rig commitment through the fourth quarter of 2022.

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, 2022, the Company had in place two long-term crude oil contracts and 12 long-term 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. STOCKHOLDERS’ EQUITY

Incentive Plans

The Company’s board of directors has 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, 2022, a maximum of 0.3 million of the Company’s common stock remained reserved for issuance under the Plan. For the six months ended June 30, 2022 and 2021, the Company recognized expense of $0.9 million and $1.1 million, respectively, related to stock-based-compensation awards granted to employees and directors, including grants of stock options and restricted stock. 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 generally vest and convert to shares in equal amounts over a three or four year vesting period from the date of the grant, depending on award, or when the performance or market conditions described further described in our Annual Report on Form 10-K occur.

During the six months ended June 30, 2022, the Company granted 0.2 million shares of RSUs at a weighted average grant date fair value of $14.07 per share. At June 30, 2022, the Company had $4.1 million of unrecognized compensation expense related to non-vested RSU awards to be recognized over a weighted average period of 1.6 years.

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BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

Stock Options

From time to time, the Company grants 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 the six month ended June 30, 2022. At June 30, 2022, the Company had $0.3 million of unrecognized compensation expense related to non-vested stock options to be recognized over a weighted-average period of 1.1 years.

Warrants

On October 8, 2019, the Company entered into a warrant agreement (the Warrant Agreement) with Broadridge Corporate Issuer Solutions, Inc. as the warrant agent, pursuant to which the Company issued approximately 6.9 million warrants (Series A, Series B and Series C Warrants and together, the Warrants) with corresponding initial exercise prices ranging from $40.17 to $60.45 per share, on a pro rata basis to pre-emergence holders of the predecessor Company’s common stock pursuant to the Company’s plan of reorganization. The Warrants do not grant any voting or control rights or dividend rights, or contain any negative covenants restricting the operation of the Company’s business.

Each Warrant represents the right to purchase one share of common stock at the applicable exercise prices, subject to adjustment as provided in the Warrant Agreement and increasing monthly at an annualized rate of 6.75%, compounding monthly. Each series of Warrants issued under the Warrant Agreement has a three-year term, expiring on October 8, 2022. As of June 30, 2022, the Company had 1.8 million Series A, 2.2 million Series B and 2.9 million Series C Warrants outstanding with corresponding exercise prices of $46.15, $55.86 and $70.42 per share, respectively.

11. 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,
	2022		2021		2022		2021
Basic:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Basic net income (loss) per share of common stock	$	0.80	$	(2.09)	$	(4.88)	$	(4.14)
Diluted:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Common stock equivalent shares representing shares issuable upon:
Exercise of Series A Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series B Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series C Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		172		Anti-dilutive		Anti-dilutive		Anti-dilutive
Weighted average diluted number of common shares outstanding		16,510		16,268		16,320		16,250
Diluted net income (loss) per share of common stock	$	0.79	$	(2.09)	$	(4.88)	$	(4.14)

23

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

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

Common stock equivalents, including warrants, options and restricted stock units, totaling 7.7 million for the six months ended June 30, 2021 were not included in the computation of diluted earnings per share of common stock because the effect would have been anti-dilutive.

12. ADDITIONAL FINANCIAL STATEMENT INFORMATION

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

	June 30, 2022		December 31, 2021
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	47,221	$	34,110
Joint interest accounts		5,590		2,503
Other		191		193
	$	53,002	$	36,806
Prepaids and other:
Prepaids	$	536	$	975
Funds in escrow		390		390
Other		1		1
	$	927	$	1,366
Other assets (Non-current):
Investment in unconsolidated affiliate(1)	$	1,653	$	—
Oil, natural gas and natural gas liquids revenues		417		1,010
Funds in escrow		1,228		1,227
Other		31		33
	$	3,329	$	2,270
Accounts payable and accrued liabilities:
Trade payables	$	36,885	$	25,315
Accrued oil and natural gas capital costs		20,518		4,881
Revenues and royalties payable		29,534		22,763
Accrued interest expense		57		42
Accrued employee compensation		2,073		3,735
Accrued lease operating expenses		6,212		6,090
Drilling advances from partners		2,055		—
	$	97,334	$	62,826

(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. We also entered into a gas treating agreement with the joint venture, Brazos Amine Treater, LLC (“BAT”), 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. Caracara will provide all necessary capital for the construction of the treatment facility. We contributed certain full cost pool assets to the joint venture in 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}

24

BATTALION OIL CORPORATION

NOTES TO THE UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (continued)

^{potentially be significant, we are not the primary beneficiary of BAT. Accordingly, we account for our investment in BAT 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.}

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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, 2022 and 2021 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, 2021. 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. During 2017, we acquired certain properties in the Delaware Basin and divested our assets located in the Williston Basin in North Dakota and in the El Halcón area of East Texas. As a result, 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 total operating revenues for the first six months of 2022 and 2021 were $183.1 million and $119.9 million, respectively. The increase in revenues is primarily attributable to an approximate $23.62 per Boe increase in average realized prices (excluding the effects of hedging arrangements). During the first six months of 2022, production averaged 14,906 Boe/d compared to average production of 14,956 Boe/d during the six months of 2021. In February 2021, we temporarily shut-in production due to inclement weather. The estimated decrease in average daily oil and natural gas production associated with this temporary shut-in was approximately 600 Boe/d in the first six months of 2021. Current year production was impacted by natural production declines on our existing producing wells. For the six months ended June 30, 2022, we drilled and cased 5 gross (4.84 net) operated wells and completed and put online 5 gross and net operated wells.

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, 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 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.

Additionally, since oil and natural gas prices are inherently volatile, sustained lower commodity prices could result in impairment charges under our full cost ceiling test calculation. The ceiling test calculation dictates that we use the unweighted arithmetic average price of crude oil and natural gas as of the first day of each month for the 12-month

26

period ending at the balance sheet date. Using the crude oil price for July 2022 of $110.2 per barrel, and holding it constant for two months to create a trailing 12-month period of average prices that is more reflective of recent price trends, our ceiling test calculation would not have generated an impairment, holding all other inputs and factors constant. In addition to commodity prices, our production rates, levels of proved reserves, future development costs, transfers of unevaluated properties to our full cost pool, capital spending and other factors will determine our actual ceiling test calculation and impairment analyses in future periods.

Recent Developments

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 is obligated to provide all necessary capital for the construction of the Facility, which is expected to come online on or before twelve months from the effective date of the GTA, with an initial capacity of approximately 30 MMcf per day, and a design capacity to treat up to 10% combined concentrations for H2S and CO2. 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.

Capital Resources and Liquidity

Overview. At June 30, 2022, we had $43.6 million of cash and cash equivalents, $220.0 million of indebtedness outstanding, approximately $1.3 million letters of credit outstanding and $15.0 million in delayed draw term loans available to be drawn under our Term Loan Agreement, subject to the satisfaction of certain conditions defined in the agreement.

Capital Expenditures. During 2022, we expect to spend approximately $130.0 million to $150.0 million in capital expenditures, including drilling, completion, support infrastructure and other capital costs. Included in our remaining 2022 capital expenditures budget is approximately $4.7 million associated with an active drilling rig commitment through the fourth quarter of 2022. We also have a minimum volume commitment of approximately $3.3 million with a third party for the purchase of chemicals to treat sour gas production through December 31, 2022. Our capital spending requirements and commitments are expected to be funded with cash and cash equivalents on hand from the funding of our Term Loan Agreement (which is further described below) and cash flows from operations.

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. The Term Loan Agreement amends and restates in its entirety our previous revolving credit agreement. Pursuant to the Term Loan Agreement, the lenders agreed to loan us (i) $200.0 million, which funded on November 24, 2021 and was partially used to refinance all amounts owed under the Senior Credit Agreement; (ii) up to $20.0 million under the first delayed draw of the Term Loan Agreement, which was drawn on April 29, 2022 and (iii) up to $15.0 million, which amount will be available to be drawn from the date certain wells included in the approved plan of development (APOD) are deemed producing APOD wells until up to 18 months after November 24, 2021, subject to the satisfaction of certain conditions. An additional $5.0 million is available for the issuance of letters of credit. The maturity date of the Term Loan Agreement is November 24, 2025. Until such maturity date, borrowings under the Term Loan Agreement shall bear interest at a rate per annum equal to LIBOR (or another applicable reference rate, as determined pursuant to the provisions of the Term Loan Agreement) plus an applicable margin of 7.00%.

We may be required to make mandatory prepayments of the loans under the 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

27

our Consolidated Cash Balance, as defined in the Term Loan Agreement, exceeds $20.0 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. We are required to make scheduled amortization payments in the aggregate amount of $120.0 million from the fiscal quarter ending March 31, 2023 through the fiscal quarter ending September 30, 2025. Amounts outstanding under the 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 Term Loan Agreement there are certain restrictions on the transfer of assets, including cash, to Battalion from the guarantor subsidiaries.

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

● Asset Coverage Ratio of not less than 1.60 to 1.00 as of June 30, 2022, 1.70 to 1.00 as of September 30, 2022, and 1.80 to 1.00 as of December 31, 2022 and each fiscal quarter thereafter

● Total Net Leverage Ratio of not greater than 3.25 to 1.00 as of June 30, 2022, 3.00 to 1.00 as of September 30, 2022 and December 31, 2022, 2.75 to 1.00 as of March 31, 2023, and 2.50 to 1.00 as of each fiscal quarter thereafter, and

● Current Ratio of not less than 1.00 to 1.00, each determined as of the last day of any fiscal quarter period.

As of June 30, 2022, the Company was in compliance with the financial covenants under the Term Loan Agreement.

The Term Loan Agreement also contains an APOD for our Monument Draw acreage through the drilling and completion of certain wells. The 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.

The 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.

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 Term Loan Agreement. As a consequence, we endeavor to anticipate potential covenant compliance issues and work with our lenders under our 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 (which last occurred in 2020 under our revolving credit facility which was replaced by our Term Loan Agreement in 2021), there can be no assurance that we will be successful in the future. In the event we are not successful in obtaining covenant modifications, 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 Term Loan Agreement.

Other Risks and Uncertainties. 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. Cash is required to fund capital expenditures necessary to offset inherent declines in our production and proven reserves, which is typical in the capital-intensive oil and natural gas industry. We strive to maintain financial flexibility while pursuing our drilling plans and may access capital markets, pursue joint ventures, sell assets and engage in other transactions as necessary to, among other things, maintain sufficient liquidity, facilitate drilling on our undeveloped acreage position and permit us to selectively expand our acreage. Our ability to complete such 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

28

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.

In periods of increasing commodity prices, the Company also continues 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.

We are also continuously monitoring the current and potential impacts of the novel coronavirus (COVID-19) pandemic on our business, including how it has and may continue to impact our operations, financial results, liquidity, contractors, customers, employees and vendors, and taking appropriate actions in response, including implementing various measures to ensure the continued operation of our business in a safe and secure manner.

During 2021, widespread availability of COVID-19 vaccines in the United States and elsewhere combined with accommodative governmental monetary and fiscal policies and other factors, led to a rebound in demand for oil and natural gas and increases in oil and natural gas prices. Further, in 2022, the effects of Russian sanctions amidst the conflict with Ukraine have pushed oil and gas prices higher. However, there remains the potential for demand for oil and natural gas to be adversely impacted by the economic effects of rising interest rates and tightening monetary policies, as well as the ongoing COVID-19 pandemic, including as a consequence of the circulation of more infectious “variants” of the disease, vaccine hesitancy, waning vaccine effectiveness or 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. For further information regarding risk factors which could impact the Company, see “Risk Factors” in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

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 coronavirus 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 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 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,
	2022		2021
Cash flows provided by (used in) operating activities	$	28,333	$	29,100
Cash flows provided by (used in) investing activities		(51,986)		(36,669)
Cash flows provided by (used in) financing activities		19,069		4,732
Net increase (decrease) in cash, cash equivalents and restricted cash	$	(4,584)	$	(2,837)

Operating Activities. Net cash flows provided by operating activities for the six months ended June 30, 2022 and 2021 were $28.3 million and $29.1 million, respectively. Operating cash flows for the six months ended June 30, 2022 decreased from the six months ended June 30, 2021 due primarily to realized losses from derivative contracts incurred in the six months ended June 30, 2022 as a result of increased commodity prices partially offset by higher total operating revenues due to an approximate $23.62 per Boe increase in average realized prices in the six months ended June 30, 2022.

Investing Activities. Net cash flows used in investing activities for the six months ended June 30, 2022 and 2021 were approximately $52.0 million and $36.7 million, respectively.

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.

During the six months ended June 30, 2021, we spent $37.6 million on oil and natural gas capital expenditures, of which $33.0 million related to drilling and completion costs and $3.1 million related to the development of our treating equipment and gathering support infrastructure. We received $0.9 million in proceeds from the sale of oil and natural gas properties.

Financing Activities. Net cash flows provided by financing activities for the six months ended June 30, 2022 and 2021 were approximately $19.1 million and $4.7 million. During the six months ended June 30, 2022, we borrowed the $20 million available under the first delayed draw of the Term Loan Agreement. During the six months ended June 30, 2021, net borrowings of $5.0 million under our Senior Credit Agreement were used to partially fund our drilling and completions program and the development of our treating equipment and gathering support facilities.

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, 2021.

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Results of Operations

Three Months Ended June 30, 2022 and 2021
​

We reported a net income (loss) of $13.0 million and $(33.9) million for the three months ended June 30, 2022 and 2021, respectively. The table included below sets forth financial information for the periods presented.

	Three Months Ended
	June 30,
In thousands (except per unit and per Boe amounts)	2022		2021		Change
Net income (loss)	$	13,047	$	(33,929)	$	46,976
Operating revenues:
Oil		73,944		51,935		22,009
Natural gas		14,759		5,317		9,442
Natural gas liquids		12,587		6,851		5,736
Other		221		263		(42)
Operating expenses:
Production:
Lease operating		11,909		10,169		1,740
Workover and other		1,383		767		616
Taxes other than income		5,372		2,912		2,460
Gathering and other		15,869		14,331		1,538
General and administrative:
General and administrative		4,115		3,546		569
Stock-based compensation		473		485		(12)
Depletion, depreciation and accretion:
Depletion – Full cost		12,414		11,015		1,399
Depreciation – Other		76		105		(29)
Accretion expense		111		129		(18)
Other income (expenses):
Net gain (loss) on derivative contracts		(31,910)		(53,089)		21,179
Interest expense and other		(4,832)		(1,747)		(3,085)
Production:
Oil – MBbls		674		805		(131)
Natural Gas - MMcf		2,355		2,055		300
Natural gas liquids – MBbls		303		270		33
Total MBoe(1)		1,369		1,417		(48)
Average daily production – Boe/d(1)		15,044		15,571		(527)
Average price per unit (2):
Oil price - Bbl	$	109.71	$	64.52	$	45.19
Natural gas price - Mcf		6.27		2.59		3.68
Natural gas liquids price - Bbl		41.54		25.37		16.17
Total per Boe(1)		73.99		45.24		28.75
Average cost per Boe:
Production:
Lease operating	$	8.70	$	7.18	$	1.52
Workover and other		1.01		0.54		0.47
Taxes other than income		3.92		2.06		1.86
Gathering and other		11.59		10.11		1.48
General and administrative:
General and administrative		3.01		2.50		0.51
Stock-based compensation		0.35		0.34		0.01
Depletion		9.07		7.77		1.30

(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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Oil, natural gas and natural gas liquids revenues were $101.3 million and $64.1 million for the three months ended June 30, 2022 and 2021, respectively. The increase in revenues is primarily attributable to an approximate $28.75 per Boe increase in our average realized prices (excluding the effects of hedging arrangements). 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. For the three months ended June 30, 2022 and 2021, production averaged 15,044 Boe/d and 15,571 Boe/d, respectively.

Lease operating expenses were $11.9 million and $10.2 million for the three months ended June 30, 2022 and 2021, respectively. On a per unit basis, lease operating expenses were $8.70 per Boe and $7.18 per Boe for the three months ended June 30, 2022 and 2021, respectively. The increase in lease operating expenses in 2022 results primarily from a market increase in maintenance, power, and chemical costs..

Workover and other expenses were $1.4 million and $0.8 million for the three months ended June 30, 2022 and 2021, respectively. On a per unit basis, workover and other expenses were $1.01 per Boe and $0.54 per Boe for the three months ended June 30, 2022 and 2021, respectively. The increased workover and other expenses in 2022 relate to more significant workover projects undertaken in the current period.

Taxes other than income were $5.4 million and $2.9 million for the three months ended June 30, 2022 and 2021, respectively. Most production taxes are based on realized prices at the wellhead. As revenues or volumes from oil and natural gas sales increase or decrease, production taxes on these sales also increase or decrease. On a per unit basis, taxes other than income were $3.92 per Boe and $2.06 per Boe for the three months ended June 30, 2022 and 2021, respectively.

Gathering and other expenses were $15.9 million and $14.3 million for the three months ended June 30, 2022 and 2021, 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. Approximately $6.8 million and $4.6 million for the three months ended June 30, 2022 and 2021, respectively, relate to gathering and marketing fees paid to third parties on our oil and natural gas production. Gathering and marketing fees increased in 2022 as we marketed higher quantities of sour gas production to third parties in the current year period. Approximately $9.1 million and $9.7 million for the three months ended June 30, 2022 and 2021, respectively, relate to operating expenses on our treating equipment and gathering support facilities. The decrease in treating equipment and gathering support facilities expenses in 2022 results from lower operating expenses associated with our treating equipment.

General and administrative expense was $4.1 million and $3.5 million for the three months ended June 30, 2022 and 2021, respectively. The increase in general and administrative expense in the current period is primarily associated with an increase in professional fees partially offset by a decrease in corporate office lease expense, payroll and benefits costs. On a per unit basis, general and administrative expenses were $3.01 per Boe and $2.50 per Boe for the three months ended June 30, 2022 and 2021, respectively.

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 $12.4 million and $11.0 million for the three months ended June 30, 2022 and 2021, respectively. On a per unit basis, depletion expense was $9.07 per Boe and $7.77 per Boe for the three months ended June 30, 2022 and 2021, respectively. The increase in our depletion rate for the quarter ended June 30, 2022 compared to the same period in 2021 is primarily due to increased future development costs in 2022 compared to 2021 associated with PUD reserve additions during the periods

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. At June 30, 2022, we had a $10.1 million derivative asset, $6.1 million of which was classified as current, and we had a $149.9 million derivative liability, $91.8 million of which was classified as current. We recorded a net derivative loss of $31.9

32

million ($12.8 million net unrealized gain and $44.7 million net realized loss on settled contracts) for the three months ended June 30, 2022. For the three months ended June 30, 2021, we recorded a net derivative loss of $53.1 million ($34.8 million net unrealized loss and $18.3 million net realized loss on settled and early terminated contracts).

Interest expense and other was $4.8 million and $1.7 million for the three months ended June 30, 2022 and 2021, respectively. Interest expense and other primarily increased in the current period due to higher debt balances in 2022, increased interest rates and amortization of debt issuance costs associated with our Term Loan Agreement entered into in 2022. This was partially offset by a $0.6 million change in the fair value of the Change of Control Call Option.

33

Six Months Ended June 30, 2022 and 2021

We reported a net loss of $(79.7) million and $(67.3) million for the six months ended June 30, 2022 and 2021, respectively. The table included below sets forth financial information for the periods presented.

	Six Months Ended
	June 30,
In thousands (except per unit and per Boe amounts)	2022		2021		Change
Net income (loss)	$	(79,697)	$	(67,304)	$	(12,393)
Operating revenues:
Oil		136,468		93,205		43,263
Natural gas		23,640		14,404		9,236
Natural gas liquids		22,590		11,760		10,830
Other		415		515		(100)
Operating expenses:
Production:
Lease operating		23,433		19,636		3,797
Workover and other		2,248		1,327		921
Taxes other than income		10,323		6,104		4,219
Gathering and other		31,124		27,502		3,622
General and administrative:
General and administrative		8,716		7,779		937
Stock-based compensation		857		1,079		(222)
Depletion, depreciation and accretion:
Depletion – Full cost		22,481		21,356		1,125
Depreciation – Other		120		231		(111)
Accretion expense		220		257		(37)
Other income (expenses):
Net gain (loss) on derivative contracts		(155,768)		(98,800)		(56,968)
Interest expense and other		(7,520)		(3,117)		(4,403)
Production:
Oil – MBbls		1,344		1,524		(180)
Natural Gas - MMcf		4,670		4,188		482
Natural gas liquids – MBbls		576		485		91
Total MBoe(1)		2,698		2,707		(9)
Average daily production – Boe(1)		14,906		14,956		(50)
Average price per unit (2):
Oil price - Bbl	$	101.54	$	61.16	$	40.38
Natural gas price - Mcf		5.06		3.44		1.62
Natural gas liquids price - Bbl		39.22		24.25		14.97
Total per Boe(1)		67.72		44.10		23.62
Average cost per Boe:
Production:
Lease operating	$	8.69	$	7.25	$	1.44
Workover and other		0.83		0.49		0.34
Taxes other than income		3.83		2.25		1.58
Gathering and other		11.54		10.16		1.38
General and administrative:
General and administrative		3.23		2.87		0.36
Stock-based compensation		0.32		0.40		(0.08)
Depletion		8.33		7.89		0.44

(1) Natural gas reserves are converted to oil reserves using a ratio of six Mcf to one Bbl of oil. This ratio is based on energy equivalency, not price equivalency. The price for a barrel of oil equivalent for natural gas is substantially lower than the price for a barrel of oil.

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

34

Oil, natural gas and natural gas liquids revenues were $182.7 million and $119.4 million for the six months ended June 30, 2022 and 2021, respectively. The increase in revenues is primarily attributable to an approximate $23.62 per Boe increase in our average realized prices (excluding the effects of hedging arrangements). 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. For the six months ended June 30, 2022 and 2021, production averaged 14,906 Boe/d and 14,956 Boe/d, respectively. In February 2021, we temporarily shut-in production due to inclement weather. The estimated decrease in average daily oil and natural gas production associated with this temporary shut-in was approximately 600 Boe/d in the first six months of 2021. Current year production was impacted by natural production declines on our existing producing wells.

Lease operating expenses were $23.4 million and $19.6 million for the six months ended June 30, 2022 and 2021, respectively. On a per unit basis, lease operating expenses were $8.69 per Boe and $7.25 per Boe for the six months ended June 30, 2022 and 2021, respectively. The increase in lease operating expenses in 2022 results primarily from a market increase in maintenance, power, and chemical costs.

Workover and other expenses were $2.2 million and $1.3 million for the six months ended June 30, 2022 and 2021, respectively. On a per unit basis, workover and other expenses were $0.83 per Boe and $0.49 per Boe for the six months ended June 30, 2022 and 2021, respectively. The increased workover and other expenses in 2022 relate to more significant workover projects undertaken in the current period.

Taxes other than income were $10.3 million and $6.1 million for the six months ended June 30, 2022 and 2021, respectively. Most production taxes are based on realized prices at the wellhead. As revenues or volumes from oil and natural gas sales increase or decrease, production taxes on these sales also increase or decrease. On a per unit basis, taxes other than income were $3.83 per Boe and $2.25 per Boe for the six months ended June 30, 2022 and 2021, respectively.

Gathering and other expenses were $31.1 million and $27.5 million for the six months ended June 30, 2022 and 2021, 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. Approximately $13.4 million and $8.6 million for the six months ended June 30, 2022 and 2021, respectively, relate to gathering and marketing fees paid to third parties on our oil and natural gas production. Gathering and marketing fees increased in 2022 as we marketed higher quantities of sour gas production to third parties in the current year period. Approximately $17.8 million and $18.9 million for the six months ended June 30, 2022 and 2021, respectively, relate to operating expenses on our treating equipment and gathering support facilities. The decrease in treating equipment and gathering support facilities expenses in 2022 results from lower operating expenses associated with our treating equipment.

General and administrative expense was $8.7 million and $7.8 million for the six months ended June 30, 2022 and 2021, respectively. The increase in general and administrative expense in the current year period is primarily associated with an increase in professional fees and payroll and benefits. On a per unit basis, general and administrative expenses were $3.23 per Boe and $2.87 per Boe for the three months ended June 30, 2022 and 2021, respectively.

Depletion expense was $22.5 million and $21.4 million for the six months ended June 30, 2022 and 2021, respectively. 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. On a per unit basis, depletion expense was $8.33 per Boe and $7.89 per Boe for the six months ended June 30, 2022 and 2021, respectively. The increase in our depletion rate for the six months ended June 30, 2022 compared to the same period in 2021 is primarily due to increased future development costs in 2022 compared to 2021 associated with PUD reserve additions during the periods

We enter into derivative commodity instruments to economically 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. At June 30, 2022, we had a $10.1 million derivative asset, $6.1 million of which was classified as current, and we had a

35

$149.9 million derivative liability, $91.8 million of which was classified as current. We recorded a net derivative loss of $155.8 million ($78.2 million net unrealized loss and $77.6 million net realized loss on settled and early terminated contracts) for the six months ended June 30, 2022. For the six months ended June 30, 2021, we recorded a net derivative loss of $98.8 million ($70.9 million net unrealized loss and $27.9 million net realized loss on settled and early terminated contracts).

Interest expense and other was $7.5 million and $3.1 million for the six months ended June 30, 2022 and 2021, respectively. Interest expense and other increased in the current period due primarily to higher debt balances in 2022, an increase in interest rates and amortization of debt issuance costs associated with our Term Loan Agreement entered in to in 2022. This was partially offset by a $2.6 million change in the fair value of the Change of Control Call Option.

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, 2022, 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 LIBOR based and may result in reductions of earnings or cash flows due to increases in the interest rates we pay on these obligations.

36

At June 30, 2022, the principal amount of our debt was $220.0 million, which all bears interest at floating and variable interest rates that are tied to LIBOR. Fluctuations in market interest rates will cause our annual interest costs to fluctuate. At June 30, 2022, the weighted average interest rate on our variable rate debt was 9.25% per year. If the balance of our variable interest rate at June 30, 2022 were to remain constant, a 10% change in market interest rates would impact our cash flows by approximately $2.0 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 Chief 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, 2022. On the basis of this review, our management, including our Chief Executive Officer and Chief Financial Officer, 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 Chief 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 months ended June 30, 2022 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, 2021.

37

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

The following table sets forth information regarding our acquisition of shares of common stock for the periods presented.

	Total Number of Shares Purchased(1)	Average Price Paid Per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
April 2022	185	$	19.64	—	—
May 2022	—		—	—	—
June 2022	185		15.10	—	—

(1) All of the shares were surrendered by employees in exchange for the payment of tax withholding upon the vesting of restricted stock units. The acquisition of the surrendered shares was not part of a publicly announced program to repurchase shares of our common stock.

ITEM 3.    DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

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 (formerly Halcón Resources 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).
3.2	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).
31.1*	Sarbanes-Oxley Section 302 certification of Principal Executive Officer

38

31.2*	Sarbanes-Oxley Section 302 certification of 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.

39

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 8, 2022	By:	/s/ RICHARD H. LITTLE
		Name:	Richard H. Little
		Title:	Chief Executive Officer
August 8, 2022	By:	/s/ R. KEVIN ANDREWS
		Name:	R. Kevin Andrews
		Title:	Executive Vice President, Chief Financial Officer and Treasurer

40

EX-31.1

Exhibit 31.1

CERTIFICATIONS FOR FORM 10-Q

I, Richard H. Little, 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. The registrant’s other certifying officer and I are 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 our 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 our 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 our 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. The registrant’s other certifying officer and I have disclosed, based on our 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 8, 2022	By:	/s/ Richard H. Little
		Name:	Richard H. Little
		Title:	Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS FOR FORM 10-Q

I, R. Kevin Andrews, 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. The registrant’s other certifying officer and I are 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 our 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 our 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 our 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. The registrant’s other certifying officer and I have disclosed, based on our 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.

	BATTALION OIL CORPORATION
August 8, 2022	By:	/s/ R. Kevin Andrews
		Name:	R. Kevin Andrews
		Title:	Executive Vice President, Chief Financial Officer and Treasurer

EX-32

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), Richard H. Little, Chief Executive Officer, and R. Kevin Andrews, Executive Vice President, Chief Financial Officer and Treasurer, of Battalion Oil Corporation (the “Company”), each 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, 2022 (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/ Richard H. Little
August 8, 2022	Richard H. Little Chief Executive Officer
	/s/ R. Kevin Andrews
August 8, 2022	R. Kevin Andrews Executive Vice President, Chief Financial Officer and Treasurer

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.

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2022	Aug. 04, 2022
Cover [Abstract]
Entity Registrant Name	Battalion Oil Corp
Entity Central Index Key	0001282648
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Amendment Flag	false
Trading Symbol	BATL
Current Fiscal Year End Date	--12-31
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		16,337,910
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-0700684
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
Security Exchange Name	NYSEAMER
Entity File Number	001-35467

XML

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 101,290	$ 64,103	$ 182,698	$ 119,369
Other	221	263	415	515
Total operating revenues	101,511	64,366	183,113	119,884
Production:
Lease operating	11,909	10,169	23,433	19,636
Workover and other	1,383	767	2,248	1,327
Taxes other than income	5,372	2,912	10,323	6,104
Gathering and other	15,869	14,331	31,124	27,502
General and administrative	4,588	4,031	9,573	8,858
Depletion, depreciation and accretion	12,601	11,249	22,821	21,844
Total operating expenses	51,722	43,459	99,522	85,271
Income (loss) from operations	49,789	20,907	83,591	34,613
Other income (expenses):
Net gain (loss) on derivative contracts	(31,910)	(53,089)	(155,768)	(98,800)
Interest expense and other	(4,832)	(1,747)	(7,520)	(3,117)
Total other income (expenses)	(36,742)	(54,836)	(163,288)	(101,917)
Income (loss) before income taxes	13,047	(33,929)	(79,697)	(67,304)
Income tax benefit (provision)
Net income (loss)	$ 13,047	$ (33,929)	$ (79,697)	$ (67,304)
Net income (loss) per share of common stock:
Basic (in dollars per share)	$ 0.80	$ (2.09)	$ (4.88)	$ (4.14)
Diluted (in dollars per share)	$ 0.79	$ (2.09)	$ (4.88)	$ (4.14)
Weighted average common shares outstanding:
Basic (in shares)	16,338	16,268	16,320	16,250
Diluted (in shares)	16,510	16,268	16,320	16,250
Oil
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 73,944	$ 51,935	$ 136,468	$ 93,205
Natural gas
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	14,759	5,317	23,640	14,404
NGLs
Oil, natural gas and natural gas liquids sales:
Total oil, natural gas and natural gas liquids sales	$ 12,587	$ 6,851	$ 22,590	$ 11,760

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 43,640	$ 46,864
Accounts receivable, net	53,002	36,806
Assets from derivative contracts	6,146	1,383
Restricted cash	135	1,495
Prepaids and other	927	1,366
Total current assets	103,850	87,914
Oil and natural gas properties (full cost method):
Evaluated	632,004	569,886
Unevaluated	64,760	64,305
Gross oil and natural gas properties	696,764	634,191
Less - accumulated depletion	(362,257)	(339,776)
Net oil and natural gas properties	334,507	294,415
Other operating property and equipment:
Other operating property and equipment	4,045	3,467
Less - accumulated depreciation	(1,027)	(1,035)
Net other operating property and equipment	3,018	2,432
Other noncurrent assets:
Assets from derivative contracts	3,972	2,515
Operating lease right of use assets	539	721
Other assets	3,329	2,270
Total assets	449,215	390,267
Current liabilities:
Accounts payable and accrued liabilities	97,334	62,826
Liabilities from derivative contracts	91,750	58,322
Current portion of long-term debt	15,000	85
Operating lease liabilities	377	369
Asset retirement obligations	401
Total current liabilities	204,862	121,602
Long-term debt, net	188,372	181,565
Other noncurrent liabilities:
Liabilities from derivative contracts	58,138	7,144
Asset retirement obligations	11,686	11,896
Operating lease liabilities	162	352
Other	1,408	4,003
Commitments and contingencies (Note 10)
Stockholders' equity:
Common stock: 100,000,000 shares of $0.0001 par value authorized; 16,337,910 and 16,273,913 shares issued and outstanding as of June 30, 2022 and December 31, 2021, respectively	2	2
Additional paid-in capital	332,766	332,187
Retained earnings (accumulated deficit)	(348,181)	(268,484)
Total stockholders' equity	(15,413)	63,705
Total liabilities and stockholders' equity	$ 449,215	$ 390,267

XML

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Jun. 30, 2022	Dec. 31, 2021
Stockholders' equity:
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	16,337,910	16,273,913
Common stock, shares outstanding	16,337,910	16,273,913

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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, 2020	$ 2	$ 330,123	$ (240,167)	$ 89,958
Balances (in shares) at Dec. 31, 2020	16,204
Increase (Decrease) in Stockholders' Equity
Net income (loss)			(33,375)	(33,375)
Reduction in shares to cover individuals' tax withholding		(264)		(264)
Reduction in shares to cover individuals' tax withholding (in shares)	(24)
Stock-based compensation		692		692
Balances at Mar. 31, 2021	$ 2	330,551	(273,542)	57,011
Balances (in shares) at Mar. 31, 2021	16,267
Balances at Dec. 31, 2020	$ 2	330,123	(240,167)	89,958
Balances (in shares) at Dec. 31, 2020	16,204
Increase (Decrease) in Stockholders' Equity
Net income (loss)				(67,304)
Long-term incentive plan vestings (in shares)	87
Balances at Jun. 30, 2021	$ 2	331,117	(307,471)	23,648
Balances (in shares) at Jun. 30, 2021	16,268
Balances at Mar. 31, 2021	$ 2	330,551	(273,542)	57,011
Balances (in shares) at Mar. 31, 2021	16,267
Increase (Decrease) in Stockholders' Equity
Net income (loss)			(33,929)	(33,929)
Long-term incentive plan vestings (in shares)	1
Reduction in shares to cover individuals' tax withholding		(5)		(5)
Stock-based compensation		571		571
Balances at Jun. 30, 2021	$ 2	331,117	(307,471)	23,648
Balances (in shares) at Jun. 30, 2021	16,268
Increase (Decrease) in Stockholders' Equity
Net income (loss)			13,052	13,052
Long-term incentive plan vestings (in shares)	8
Reduction in shares to cover individuals' tax withholding		(22)		(22)
Reduction in shares to cover individuals' tax withholding (in shares)	(2)
Stock-based compensation		565		565
Balances at Sep. 30, 2021	$ 2	331,660	(294,419)	37,243
Balances (in shares) at Sep. 30, 2021	16,274
Increase (Decrease) in Stockholders' Equity
Net income (loss)			25,935	25,935
Stock-based compensation		527		527
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)
Reduction in shares to cover individuals' tax withholding		(461)		(461)
Reduction in shares to cover individuals' tax withholding (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

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Cash flows from operating activities:
Net income (loss)	$ (79,697)	$ (67,304)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depletion, depreciation and accretion	22,821	21,844
Stock-based compensation, net	857	1,079
Unrealized loss (gain) on derivative contracts	78,201	70,869
Amortization of deferred loan costs	1,807
(Gain) loss on sale of other assets	(96)
Reorganization items, net	(744)
Accrued settlements on derivative contracts	14,652	6,972
Change in fair value of Change of Control Call Option	(2,595)
Other income (expense)		(287)
Change in assets and liabilities:
Accounts receivable	(12,596)	(5,488)
Prepaids and other	438	(441)
Accounts payable and accrued liabilities	5,285	1,856
Net cash provided by (used in) operating activities	28,333	29,100
Cash flows from investing activities:
Oil and natural gas capital expenditures	(51,377)	(37,593)
Proceeds received from sale of oil and natural gas properties		926
Other operating property and equipment capital expenditures	(705)
Proceeds received from sale of other operating property and equipment	96
Funds held in escrow and other		(2)
Net cash provided by (used in) investing activities	(51,986)	(36,669)
Cash flows from financing activities:
Proceeds from borrowings	20,000	82,000
Repayments of borrowings	(85)	(77,000)
Debt issuance costs	(379)
Other	(467)	(268)
Net cash provided by (used in) financing activities	19,069	4,732
Net increase (decrease) in cash, cash equivalents and restricted cash	(4,584)	(2,837)
Cash, cash equivalents and restricted cash at beginning of period	48,359	4,295
Cash, cash equivalents and restricted cash at end of period	43,775	$ 1,458
Supplemental cash flow information:
Cash paid for reorganization items	$ 744

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FINANCIAL STATEMENT PRESENTATION

6 Months Ended

Jun. 30, 2022

FINANCIAL STATEMENT PRESENTATION

FINANCIAL STATEMENT PRESENTATION

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 7, 2022. Please refer to the notes in the Annual Report on Form 10-K for the year ended December 31, 2021 when reviewing interim financial results. The Company has evaluated events or transactions through the date of issuance of these unaudited condensed consolidated financial statements.

Risk and Uncertainties

The Company is continuously monitoring the current and potential impacts of the novel coronavirus (COVID-19) pandemic on its business, including how it has and may continue to impact its operations, financial results, liquidity, contractors, customers, employees and vendors, and taking appropriate actions in response, including implementing various measures to ensure the continued operation of its business in a safe and secure manner.

During 2021, widespread availability of COVID-19 vaccines in the United States and elsewhere combined with accommodative governmental monetary and fiscal policies and other factors, led to a rebound in demand for oil and natural gas and increases in oil and natural gas prices. Further, in 2022, the effects of Russian sanctions amidst the conflict with Ukraine have pushed oil and gas prices higher. However, there remains the potential for demand for oil and natural gas to be adversely impacted by the economic effects of rising interest rates and tightening monetary policies, as well as the ongoing COVID-19 pandemic, including as a consequence of the circulation of more infectious “variants” of the disease, vaccine hesitancy, waning vaccine effectiveness or 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. The results presented in this Form 10-Q are not necessarily indicative of future operating results.

Additionally, in periods of increasing commodity prices, the Company continues 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.

For further information regarding the actual and potential impacts of COVID-19 and supply chain issues on the Company, see “Risk Factors” in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

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, 2022		December 31, 2021
Cash and cash equivalents	$	43,640	$	46,864
Restricted cash		135		1,495
Total cash, cash equivalents and restricted cash	$	43,775	$	48,359

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. The Company establishes provisions for losses on accounts receivable if it determines that collection of all or part of the outstanding balance is doubtful. The Company regularly reviews collectability and establishes or adjusts the allowance for doubtful accounts as necessary using the specific identification method. As of June 30, 2022 and December 31, 2021, allowances for doubtful accounts were approximately $0.2 million for both periods.

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, 2022, the Company’s derivative counterparties include two major financial institutions, both of which are secured lenders under the Term Loan Agreement.

Recently Issued Accounting Pronouncements

In March 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2020-04, Reference Rate Reform (Topic 848) (ASU 2020-04), in response to the risk of cessation of the London Interbank Offered Rate (LIBOR). This amendment provides optional expedients and exceptions for applying generally accepted accounting principles to contracts, hedging arrangements, and other transactions that reference LIBOR. ASU 2020-04 will be in effect through December 31, 2022. As of the date of this filing, ASU 2020-04 has not had a material impact on the Company’s operating results, financial position and disclosures.

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LEASES

6 Months Ended

Jun. 30, 2022

LEASES

LEASES

2. LEASES

The Company leases equipment and office space pursuant to net operating leases. Operating leases where the Company is the lessee are included in “Operating lease right of use assets” and “Operating lease liabilities” on the unaudited condensed consolidated balance sheets. The lease liabilities are initially and subsequently measured at the present value of the unpaid lease payments at the lease commencement date. The Company has no leases that meet the criteria for classification as a finance lease.

Variable lease payments associated with the Company’s leases are recognized when the event, activity, or 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 unaudited condensed consolidated statements of operations in the same line item as the expense arising from the fixed lease payments on the operating leases.

The Company elected not to recognize right of use assets and lease liabilities for all short-term leases that have a lease term of 12 months or less. The Company recognizes the lease payments associated with its short-term leases when incurred. Variable lease payments associated with these leases are recognized and presented in the same manner as for all other leases.

The “Operating lease right of use assets” outstanding on the unaudited condensed consolidated balance sheets as of June 30, 2022 and December 31, 2021 both have initial lease terms 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, 2022 and 2021 (in thousands, except term and discount rate):

	Six Months Ended
	June 30,
	2022			2021
Lease cost
Operating lease costs	$	196		$	235
Short-term lease costs		4,003			1,889
Variable lease costs		—			229
Total lease costs	$	4,199		$	2,353
Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	328
Weighted-average remaining lease term - operating leases		1.4	years		0.2	years
Weighted-average discount rate - operating leases		4.29	%		3.70	%

Future minimum lease payments associated with the Company’s non-cancellable operating leases for office space as of June 30, 2022 are presented in the table below (in thousands):

	June 30, 2022
Remaining period in 2022	$	196
2023		359
2024		—
2025		—
2026		—
Thereafter		—
Total operating lease payments		555
Less: discount to present value		16
Total operating lease liabilities		539
Less: current operating lease liabilities		377
Noncurrent operating lease liabilities	$	162

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OPERATING REVENUES

6 Months Ended

Jun. 30, 2022

OPERATING REVENUES

OPERATING REVENUES

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 the commodity to the customer. Revenue is measured based on consideration specified in a contract with a customer 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. Because 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 $47.6 million and $35.1 million as of June 30, 2022 and December 31, 2021, respectively, as “Accounts receivable” and “Other assets” on the unaudited condensed consolidated balance sheets.

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OIL AND NATURAL GAS PROPERTIES

6 Months Ended

Jun. 30, 2022

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES

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, 2022, the ceiling test value of the Company’s reserves was calculated based on the first-day-of-the-month average for the 12-months ended June 30, 2022 of the West Texas Intermediate (WTI) crude oil spot price of $85.82 per barrel, adjusted by lease or field for quality, transportation fees, and regional price differentials, and the first-day-of-the-month average for the 12-months ended June 30, 2022 of the Henry Hub natural gas price of $5.13 per MMBtu, adjusted by lease or field for energy content, transportation fees, and regional price differentials. Using these prices, the Company’s net book value of oil and natural gas properties at June 30, 2022 did not exceed the ceiling amount.

At June 30, 2021, the ceiling test value of the Company’s reserves was calculated based on the first-day-of-the-month average for the 12-months ended June 30, 2021 of the WTI crude oil spot price of $49.72 per barrel, adjusted by lease or field for quality, transportation fees, and regional price differentials, and the first-day-of-the-month average for the 12-months ended June 30, 2021 of the Henry Hub natural gas price of $2.43 per MMBtu, adjusted by lease or field for energy content, transportation fees, and regional price differentials. Using these prices, the Company’s net book value of oil and natural gas properties at June 30, 2021 did not exceed the ceiling amount.

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.

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DEBT

6 Months Ended

Jun. 30, 2022

DEBT

DEBT

5. DEBT

As of June 30, 2022 and December 31, 2021, the Company’s debt consisted of the following (in thousands):

	June 30, 2022		December 31, 2021
Term loan credit facility(1)	$	203,372	$	181,565
Paycheck Protection Program loan		—		85
Total debt, net		203,372		181,650
Current portion of long-term debt(2)		15,000		85
Total long-term debt, net	$	188,372	$	181,565

(1) Amount is net of $12.4 million and $14.2 million in unamortized debt issuance costs at June 30, 2022 and December 31, 2021, respectively. Amount also excludes the initial fair value allocated to the change of control call option embedded derivative of $4.2 million. Refer to “Term Loan Credit Facility” below for further details.

(2) As of June 30, 2022, amount represents amortization payments of $15.0 million under the Term Loan Agreement due within one year. As of December 31, 2021, amount represents the balance owed under the Company’s Paycheck Protection Program Loan.

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. The Term Loan Agreement amends and restates in its entirety the senior secured revolving credit agreement, as amended, (the Senior Credit Agreement) entered into in 2019 as further discussed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2021. Pursuant to the Term Loan Agreement, the lenders have agreed to loan the Company (i) $200.0 million, which was funded on November 24, 2021 and was partially used to refinance all amounts owed under the Senior Credit Agreement; (ii) up to $20.0 million under the first delayed draw of the Term Loan Agreement, which was drawn on April 29, 2022 and (iii) up to $15.0 million, which amount will be available to be drawn from the date certain wells included in the approved plan of development (APOD) are deemed producing APOD wells until up to 18 months after November 24, 2021, subject to the satisfaction of certain conditions. An additional $5.0 million is available for the issuance of letters of credit. The maturity date of the Term Loan Agreement is November 24, 2025. Until such maturity date, borrowings under the Term Loan Agreement bear interest at a rate per annum equal to LIBOR (or another applicable reference rate, as determined pursuant to the provisions of the Term Loan Agreement) plus an applicable margin of 7.00%.

At June 30, 2022, the Company had $220.0 million indebtedness outstanding and approximately $1.3 million letters of credit outstanding under the Term Loan Agreement. The Company also has available $15.0 million in delayed draw term loans, subject to the satisfaction of certain conditions defined in the agreement.

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

Period	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%

The Company may be required to make mandatory prepayments under the 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 Term Loan Agreement, exceeds $20.0 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 Company is required to make scheduled amortization payments in the aggregate amount of $120.0 million from the fiscal quarter ending March 31, 2023 through the fiscal quarter ending September 30, 2025. Amounts outstanding under the 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 Term Loan Agreement there are certain restrictions on the transfer of assets, including cash, to Battalion from the guarantor subsidiaries.

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

● Asset Coverage Ratio of not less than 1.60 to 1.00 as of June 30, 2022, 1.70 to 1.00 as of September 30, 2022, and 1.80 to 1.00 as of December 31, 2022 and each fiscal quarter thereafter

● Total Net Leverage Ratio of not greater than 3.25 to 1.00 as of June 30, 2022, 3.00 to 1.00 as of September 30, 2022 and December 31, 2022, 2.75 to 1.00 as of March 31, 2023, and 2.50 to 1.00 as of each fiscal quarter thereafter, and

● Current Ratio of not less than 1.00 to 1.00, each determined as of the last day of any fiscal quarter period.

As of June 30, 2022, the Company was in compliance with the financial covenants under the Term Loan Agreement.

The Term Loan Agreement also contains an APOD for the Company’s Monument Draw acreage through the drilling and completion of certain wells. The 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 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 the Term Loan Agreement, 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 Chief 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 Company determined that the Change of Control Call Option was an embedded derivative, concluded the embedded derivative was not clearly and closely related to the host debt instrument, and recorded the initial $4.2 million fair value separately on the unaudited condensed consolidated balance sheet within “Other noncurrent liabilities.” The Change of Control Call Option is subsequently remeasured at fair value each reporting period with fair value changes recorded 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, the significant inputs to the valuation, and for a reconciliation of the change in fair value of the Change of Control Call Option.

Paycheck Protection Program Loan

In 2020, the Company entered into a promissory note (the PPP Loan) for a principal amount of approximately $2.2 million under the Paycheck Protection Program of the CARES Act. Effective August 13, 2021, the principal amount of the Company’s PPP Loan was reduced to approximately $0.2 million upon forgiveness of $2 million based on the use of loan proceeds for eligible expenses under the CARES Act. The Company recorded a gain on the extinguishment of the forgiven portion of the PPP Loan and related accrued interest of $2.1 million presented in “Gain (loss) on extinguishment of debt” in the consolidated statements of operations during the quarter ended September 30, 2021. During the first quarter of 2022, the $0.2 million principal amount of the PPP loan was repaid in full.

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FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2022

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

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, 2022 and December 31, 2021 (in thousands):

	June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	10,118	$	—	$	10,118
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	149,888	$	—	$	149,888

	December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	3,898	$	—	$	3,898
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	65,466	$	—	$	65,466

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.

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 recorded the fair value of the Change of Control Call Option separately on the unaudited condensed consolidated balance sheets in “Other noncurrent liabilities.” The fair value of the Change of Control Call Option is subsequently remeasured each reporting period with fair value changes recorded 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 LIBOR 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, 2021	$	4,003
Change in fair value		(2,595)
Balance at June 30, 2022	$	1,408

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 borrrowings under the Company’s 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.

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DERIVATIVE AND HEDGING ACTIVITIES

6 Months Ended

Jun. 30, 2022

DERIVATIVE AND HEDGING ACTIVITIES

DERIVATIVE AND HEDGING ACTIVITIES

7. DERIVATIVE AND HEDGING ACTIVITIES

The Company is exposed to certain risks relating to its ongoing business operations, such as commodity price risk and interest rate risk. 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, 2022, the Company did not post collateral under any of its derivative contracts as they are secured under the Company’s Term Loan Agreement.

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 derivative contracts in the unaudited condensed consolidated balance sheets as of June 30, 2022 and December 31, 2021 (in thousands):

Derivatives not designated as		Asset derivative contracts					Liability derivative contracts
hedging contracts under ASC 815	Balance sheet location	June 30, 2022		December 31, 2021		Balance sheet location	June 30, 2022		December 31, 2021
Commodity contracts	Current assets - assets from derivative contracts	$	6,146	$	1,383	Current liabilities - liabilities from derivative contracts	$	(91,750)	$	(58,322)
Commodity contracts	Other noncurrent assets - assets from derivative contracts		3,972		2,515	Other noncurrent liabilities - liabilities from derivative contracts		(58,138)		(7,144)
Total derivatives not designated as hedging contracts under ASC 815		$	10,118	$	3,898		$	(149,888)	$	(65,466)

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):

		Amount of gain or (loss)				Amount of gain or (loss)
		recognized in income on				recognized in income on
		derivative contracts for the				derivative contracts for the
Derivatives not designated	Location of gain or	Three Months Ended				Six Months Ended
as hedging contracts	(loss) recognized in income	June 30,				June 30,
under ASC 815	on derivative contracts	2022		2021		2022		2021
Commodity contracts:
Unrealized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts	$	12,837	$	(34,817)	$	(78,201)	$	(70,869)
Realized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts		(44,747)		(18,272)		(77,567)		(27,931)
Total net gain (loss) on derivative contracts		$	(31,910)	$	(53,089)	$	(155,768)	$	(98,800)

At June 30, 2022, the Company had the following open crude oil and natural gas derivative contracts:

Instrument		2022	2023	2024	2025	2026
Crude oil fixed-price swap:
Total volumes (Bbls)		1,240,865	2,000,965	1,449,140	1,028,160	212,810
Weighted average price	$	52.80	65.75	60.91	59.69	59.83
Crude oil basis swap:
Total volumes (Bbls)		1,222,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.41	0.25	0.23	0.17	0.19
Crude oil WTI NYMEX roll:
Total volumes (Bbls)		1,005,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.10	0.50	0.28	0.10	0.27
Natural gas fixed-price swap:
Total volumes (MMBtu)		1,167,500	3,957,750	2,658,750	2,428,050
Weighted average price	$	3.92	3.36	3.09	3.00
Natural gas producer two-way collar:
Total volumes (MMBtu)		2,473,400	1,742,100	1,424,100	555,700	653,900
Weighted average price (call)	$	3.97	5.52	4.70	4.24	4.45
Weighted average price (put)	$	3.48	3.86	3.19	3.28	4.00
Natural gas basis swap:
Total volumes (MMBtu)		3,640,900	5,700,600	4,084,350	2,983,750	653,900
Weighted average price	$	(0.51)	(0.64)	(0.64)	(0.56)	(0.96)

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, 2022 and December 31, 2021 (in thousands):

	Derivative Assets				Derivative Liabilities
Offsetting of Derivative Assets and Liabilities	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Gross Amounts Presented in the Consolidated Balance Sheet	$	10,118	$	3,898	$	(149,888)	$	(65,466)
Amounts Not Offset in the Consolidated Balance Sheet		(10,118)		(3,898)		10,118		3,898
Net Amount	$	—	$	—	$	(139,770)	$	(61,568)

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.

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ASSET RETIREMENT OBLIGATIONS

6 Months Ended

Jun. 30, 2022

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS

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.

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

Liability for asset retirement obligations as of December 31, 2021	$	11,896
Liabilities incurred during the period		103
Liabilities settled during the period		(132)
Accretion expense		220
Liability for asset retirement obligations as of June 30, 2022	$	12,087

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2022

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

9. COMMITMENTS AND CONTINGENCIES

Commitments

As of June 30, 2022, the Company has a minimum volume commitment with a third party for the purchase of chemicals to treat sour gas production through December 31, 2022. The future payments associated with the minimum volume commitment are approximately $3.3 million.

As of June 30, 2022, the Company has an active drilling rig commitment of approximately $1.7 million through the third quarter of 2022. Termination of the active drilling rig commitment would require an early termination penalty of

$0.6 million, which would be in lieu of paying the active drilling rig commitment of $1.7 million. In July 2022, we extended our drilling rig commitment through the fourth quarter of 2022.

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, 2022, the Company had in place two long-term crude oil contracts and 12 long-term 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.

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STOCKHOLDERS' EQUITY

6 Months Ended

Jun. 30, 2022

STOCKHOLDERS' EQUITY

STOCKHOLDERS' EQUITY

10. STOCKHOLDERS’ EQUITY

Incentive Plans

The Company’s board of directors has 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, 2022, a maximum of 0.3 million of the Company’s common stock remained reserved for issuance under the Plan. For the six months ended June 30, 2022 and 2021, the Company recognized expense of $0.9 million and $1.1 million, respectively, related to stock-based-compensation awards granted to employees and directors, including grants of stock options and restricted stock. 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 generally vest and convert to shares in equal amounts over a three or four year vesting period from the date of the grant, depending on award, or when the performance or market conditions described further described in our Annual Report on Form 10-K occur.

During the six months ended June 30, 2022, the Company granted 0.2 million shares of RSUs at a weighted average grant date fair value of $14.07 per share. At June 30, 2022, the Company had $4.1 million of unrecognized compensation expense related to non-vested RSU awards to be recognized over a weighted average period of 1.6 years.

Stock Options

From time to time, the Company grants 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 the six month ended June 30, 2022. At June 30, 2022, the Company had $0.3 million of unrecognized compensation expense related to non-vested stock options to be recognized over a weighted-average period of 1.1 years.

Warrants

On October 8, 2019, the Company entered into a warrant agreement (the Warrant Agreement) with Broadridge Corporate Issuer Solutions, Inc. as the warrant agent, pursuant to which the Company issued approximately 6.9 million warrants (Series A, Series B and Series C Warrants and together, the Warrants) with corresponding initial exercise prices ranging from $40.17 to $60.45 per share, on a pro rata basis to pre-emergence holders of the predecessor Company’s common stock pursuant to the Company’s plan of reorganization. The Warrants do not grant any voting or control rights or dividend rights, or contain any negative covenants restricting the operation of the Company’s business.

Each Warrant represents the right to purchase one share of common stock at the applicable exercise prices, subject to adjustment as provided in the Warrant Agreement and increasing monthly at an annualized rate of 6.75%, compounding monthly. Each series of Warrants issued under the Warrant Agreement has a three-year term, expiring on October 8, 2022. As of June 30, 2022, the Company had 1.8 million Series A, 2.2 million Series B and 2.9 million Series C Warrants outstanding with corresponding exercise prices of $46.15, $55.86 and $70.42 per share, respectively.

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2022

EARNINGS PER SHARE

EARNINGS PER SHARE

11. 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,
	2022		2021		2022		2021
Basic:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Basic net income (loss) per share of common stock	$	0.80	$	(2.09)	$	(4.88)	$	(4.14)
Diluted:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Common stock equivalent shares representing shares issuable upon:
Exercise of Series A Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series B Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series C Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		172		Anti-dilutive		Anti-dilutive		Anti-dilutive
Weighted average diluted number of common shares outstanding		16,510		16,268		16,320		16,250
Diluted net income (loss) per share of common stock	$	0.79	$	(2.09)	$	(4.88)	$	(4.14)

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

Common stock equivalents, including warrants, options and restricted stock units, totaling 7.7 million for the six months ended June 30, 2021 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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ADDITIONAL FINANCIAL STATEMENT INFORMATION

6 Months Ended

Jun. 30, 2022

ADDITIONAL FINANCIAL STATEMENT INFORMATION

ADDITIONAL FINANCIAL STATEMENT INFORMATION

12. ADDITIONAL FINANCIAL STATEMENT INFORMATION

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

	June 30, 2022		December 31, 2021
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	47,221	$	34,110
Joint interest accounts		5,590		2,503
Other		191		193
	$	53,002	$	36,806
Prepaids and other:
Prepaids	$	536	$	975
Funds in escrow		390		390
Other		1		1
	$	927	$	1,366
Other assets (Non-current):
Investment in unconsolidated affiliate(1)	$	1,653	$	—
Oil, natural gas and natural gas liquids revenues		417		1,010
Funds in escrow		1,228		1,227
Other		31		33
	$	3,329	$	2,270
Accounts payable and accrued liabilities:
Trade payables	$	36,885	$	25,315
Accrued oil and natural gas capital costs		20,518		4,881
Revenues and royalties payable		29,534		22,763
Accrued interest expense		57		42
Accrued employee compensation		2,073		3,735
Accrued lease operating expenses		6,212		6,090
Drilling advances from partners		2,055		—
	$	97,334	$	62,826

(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. We also entered into a gas treating agreement with the joint venture, Brazos Amine Treater, LLC (“BAT”), 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. Caracara will provide all necessary capital for the construction of the treatment facility. We contributed certain full cost pool assets to the joint venture in 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 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.}

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FINANCIAL STATEMENT PRESENTATION (Policies)

6 Months Ended

Jun. 30, 2022

FINANCIAL STATEMENT PRESENTATION

Basis of Presentation and Principles of Consolidation

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 7, 2022. Please refer to the notes in the Annual Report on Form 10-K for the year ended December 31, 2021 when reviewing interim financial results. The Company has evaluated events or transactions through the date of issuance of these unaudited condensed consolidated financial statements.

Risk and Uncertainties

Risk and Uncertainties

The Company is continuously monitoring the current and potential impacts of the novel coronavirus (COVID-19) pandemic on its business, including how it has and may continue to impact its operations, financial results, liquidity, contractors, customers, employees and vendors, and taking appropriate actions in response, including implementing various measures to ensure the continued operation of its business in a safe and secure manner.

During 2021, widespread availability of COVID-19 vaccines in the United States and elsewhere combined with accommodative governmental monetary and fiscal policies and other factors, led to a rebound in demand for oil and natural gas and increases in oil and natural gas prices. Further, in 2022, the effects of Russian sanctions amidst the conflict with Ukraine have pushed oil and gas prices higher. However, there remains the potential for demand for oil and natural gas to be adversely impacted by the economic effects of rising interest rates and tightening monetary policies, as well as the ongoing COVID-19 pandemic, including as a consequence of the circulation of more infectious “variants” of the disease, vaccine hesitancy, waning vaccine effectiveness or 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. The results presented in this Form 10-Q are not necessarily indicative of future operating results.

Additionally, in periods of increasing commodity prices, the Company continues 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.

For further information regarding the actual and potential impacts of COVID-19 and supply chain issues on the Company, see “Risk Factors” in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

Use of Estimates

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 and Cash Equivalents

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, 2022		December 31, 2021
Cash and cash equivalents	$	43,640	$	46,864
Restricted cash		135		1,495
Total cash, cash equivalents and restricted cash	$	43,775	$	48,359

Restricted cash consists of funds to collateralize lines of credit.

Accounts Receivable and Allowance for Doubtful Accounts

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. The Company establishes provisions for losses on accounts receivable if it determines that collection of all or part of the outstanding balance is doubtful. The Company regularly reviews collectability and establishes or adjusts the allowance for doubtful accounts as necessary using the specific identification method. As of June 30, 2022 and December 31, 2021, allowances for doubtful accounts were approximately $0.2 million for both periods.

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, 2022, the Company’s derivative counterparties include two major financial institutions, both of which are secured lenders under the Term Loan Agreement.

Recently Issued Accounting Pronouncements

Recently Issued Accounting Pronouncements

In March 2020, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2020-04, Reference Rate Reform (Topic 848) (ASU 2020-04), in response to the risk of cessation of the London Interbank Offered Rate (LIBOR). This amendment provides optional expedients and exceptions for applying generally accepted accounting principles to contracts, hedging arrangements, and other transactions that reference LIBOR. ASU 2020-04 will be in effect through December 31, 2022. As of the date of this filing, ASU 2020-04 has not had a material impact on the Company’s operating results, financial position and disclosures.

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FINANCIAL STATEMENT PRESENTATION (Tables)

6 Months Ended

Jun. 30, 2022

FINANCIAL STATEMENT PRESENTATION

Schedule Of Cash, Cash Equivalents And Restricted Cash

	June 30, 2022		December 31, 2021
Cash and cash equivalents	$	43,640	$	46,864
Restricted cash		135		1,495
Total cash, cash equivalents and restricted cash	$	43,775	$	48,359

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LEASES (Tables)

6 Months Ended

Jun. 30, 2022

LEASES

Schedule of Company's leases

The table below summarizes the Company’s leases for the six months ended June 30, 2022 and 2021 (in thousands, except term and discount rate):

	Six Months Ended
	June 30,
	2022			2021
Lease cost
Operating lease costs	$	196		$	235
Short-term lease costs		4,003			1,889
Variable lease costs		—			229
Total lease costs	$	4,199		$	2,353
Other information
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	196		$	328
Weighted-average remaining lease term - operating leases		1.4	years		0.2	years
Weighted-average discount rate - operating leases		4.29	%		3.70	%

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, 2022 are presented in the table below (in thousands):

	June 30, 2022
Remaining period in 2022	$	196
2023		359
2024		—
2025		—
2026		—
Thereafter		—
Total operating lease payments		555
Less: discount to present value		16
Total operating lease liabilities		539
Less: current operating lease liabilities		377
Noncurrent operating lease liabilities	$	162

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DEBT (Tables)

6 Months Ended

Jun. 30, 2022

DEBT

Schedule of debt

As of June 30, 2022 and December 31, 2021, the Company’s debt consisted of the following (in thousands):

	June 30, 2022		December 31, 2021
Term loan credit facility(1)	$	203,372	$	181,565
Paycheck Protection Program loan		—		85
Total debt, net		203,372		181,650
Current portion of long-term debt(2)		15,000		85
Total long-term debt, net	$	188,372	$	181,565

(1) Amount is net of $12.4 million and $14.2 million in unamortized debt issuance costs at June 30, 2022 and December 31, 2021, respectively. Amount also excludes the initial fair value allocated to the change of control call option embedded derivative of $4.2 million. Refer to “Term Loan Credit Facility” below for further details.

(2) As of June 30, 2022, amount represents amortization payments of $15.0 million under the Term Loan Agreement due within one year. As of December 31, 2021, amount represents the balance owed under the Company’s Paycheck Protection Program Loan.

Schedule of prepayment premiums

Period	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%

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2022

FAIR VALUE MEASUREMENTS

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

	June 30, 2022
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	10,118	$	—	$	10,118
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	149,888	$	—	$	149,888

	December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets
Assets from commodity-based derivative contracts	$	—	$	3,898	$	—	$	3,898
Liabilities
Liabilities from commodity-based derivative contracts	$	—	$	65,466	$	—	$	65,466

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, 2021	$	4,003
Change in fair value		(2,595)
Balance at June 30, 2022	$	1,408

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DERIVATIVE AND HEDGING ACTIVITIES (Tables)

6 Months Ended

Jun. 30, 2022

DERIVATIVE AND HEDGING ACTIVITIES

Summary of location and fair value of derivative contracts

The following table summarizes the location and fair value amounts of all derivative contracts in the unaudited condensed consolidated balance sheets as of June 30, 2022 and December 31, 2021 (in thousands):

Derivatives not designated as		Asset derivative contracts					Liability derivative contracts
hedging contracts under ASC 815	Balance sheet location	June 30, 2022		December 31, 2021		Balance sheet location	June 30, 2022		December 31, 2021
Commodity contracts	Current assets - assets from derivative contracts	$	6,146	$	1,383	Current liabilities - liabilities from derivative contracts	$	(91,750)	$	(58,322)
Commodity contracts	Other noncurrent assets - assets from derivative contracts		3,972		2,515	Other noncurrent liabilities - liabilities from derivative contracts		(58,138)		(7,144)
Total derivatives not designated as hedging contracts under ASC 815		$	10,118	$	3,898		$	(149,888)	$	(65,466)

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

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):

		Amount of gain or (loss)				Amount of gain or (loss)
		recognized in income on				recognized in income on
		derivative contracts for the				derivative contracts for the
Derivatives not designated	Location of gain or	Three Months Ended				Six Months Ended
as hedging contracts	(loss) recognized in income	June 30,				June 30,
under ASC 815	on derivative contracts	2022		2021		2022		2021
Commodity contracts:
Unrealized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts	$	12,837	$	(34,817)	$	(78,201)	$	(70,869)
Realized gain (loss) on commodity contracts	Other income (expenses) - net gain (loss) on derivative contracts		(44,747)		(18,272)		(77,567)		(27,931)
Total net gain (loss) on derivative contracts		$	(31,910)	$	(53,089)	$	(155,768)	$	(98,800)

Schedule of open derivative contracts

At June 30, 2022, the Company had the following open crude oil and natural gas derivative contracts:

Instrument		2022	2023	2024	2025	2026
Crude oil fixed-price swap:
Total volumes (Bbls)		1,240,865	2,000,965	1,449,140	1,028,160	212,810
Weighted average price	$	52.80	65.75	60.91	59.69	59.83
Crude oil basis swap:
Total volumes (Bbls)		1,222,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.41	0.25	0.23	0.17	0.19
Crude oil WTI NYMEX roll:
Total volumes (Bbls)		1,005,565	1,937,165	1,413,120	1,000,360	212,810
Weighted average price	$	0.10	0.50	0.28	0.10	0.27
Natural gas fixed-price swap:
Total volumes (MMBtu)		1,167,500	3,957,750	2,658,750	2,428,050
Weighted average price	$	3.92	3.36	3.09	3.00
Natural gas producer two-way collar:
Total volumes (MMBtu)		2,473,400	1,742,100	1,424,100	555,700	653,900
Weighted average price (call)	$	3.97	5.52	4.70	4.24	4.45
Weighted average price (put)	$	3.48	3.86	3.19	3.28	4.00
Natural gas basis swap:
Total volumes (MMBtu)		3,640,900	5,700,600	4,084,350	2,983,750	653,900
Weighted average price	$	(0.51)	(0.64)	(0.64)	(0.56)	(0.96)

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, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Gross Amounts Presented in the Consolidated Balance Sheet	$	10,118	$	3,898	$	(149,888)	$	(65,466)
Amounts Not Offset in the Consolidated Balance Sheet		(10,118)		(3,898)		10,118		3,898
Net Amount	$	—	$	—	$	(139,770)	$	(61,568)

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ASSET RETIREMENT OBLIGATIONS (Tables)

6 Months Ended

Jun. 30, 2022

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, 2021	$	11,896
Liabilities incurred during the period		103
Liabilities settled during the period		(132)
Accretion expense		220
Liability for asset retirement obligations as of June 30, 2022	$	12,087

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2022

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,
	2022		2021		2022		2021
Basic:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Basic net income (loss) per share of common stock	$	0.80	$	(2.09)	$	(4.88)	$	(4.14)
Diluted:
Net income (loss)	$	13,047	$	(33,929)	$	(79,697)	$	(67,304)
Weighted average basic number of common shares outstanding		16,338		16,268		16,320		16,250
Common stock equivalent shares representing shares issuable upon:
Exercise of Series A Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series B Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of Series C Warrants		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Exercise of stock options		Anti-dilutive		Anti-dilutive		Anti-dilutive		Anti-dilutive
Vesting of restricted stock units		172		Anti-dilutive		Anti-dilutive		Anti-dilutive
Weighted average diluted number of common shares outstanding		16,510		16,268		16,320		16,250
Diluted net income (loss) per share of common stock	$	0.79	$	(2.09)	$	(4.88)	$	(4.14)

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ADDITIONAL FINANCIAL STATEMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2022

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, 2022		December 31, 2021
Accounts receivable, net:
Oil, natural gas and natural gas liquids revenues	$	47,221	$	34,110
Joint interest accounts		5,590		2,503
Other		191		193
	$	53,002	$	36,806
Prepaids and other:
Prepaids	$	536	$	975
Funds in escrow		390		390
Other		1		1
	$	927	$	1,366
Other assets (Non-current):
Investment in unconsolidated affiliate(1)	$	1,653	$	—
Oil, natural gas and natural gas liquids revenues		417		1,010
Funds in escrow		1,228		1,227
Other		31		33
	$	3,329	$	2,270
Accounts payable and accrued liabilities:
Trade payables	$	36,885	$	25,315
Accrued oil and natural gas capital costs		20,518		4,881
Revenues and royalties payable		29,534		22,763
Accrued interest expense		57		42
Accrued employee compensation		2,073		3,735
Accrued lease operating expenses		6,212		6,090
Drilling advances from partners		2,055		—
	$	97,334	$	62,826

(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. We also entered into a gas treating agreement with the joint venture, Brazos Amine Treater, LLC (“BAT”), 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. Caracara will provide all necessary capital for the construction of the treatment facility. We contributed certain full cost pool assets to the joint venture in 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 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.}

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FINANCIAL STATEMENT PRESENTATION (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) segment	Dec. 31, 2021 USD ($)
Basis of Presentation and Principles of Consolidation
Number of operating segments | segment	1
Allowance for doubtful accounts | $	$ 0.2	$ 0.2

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FINANCIAL STATEMENT PRESENTATION- Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
FINANCIAL STATEMENT PRESENTATION
Cash and cash equivalents	$ 43,640	$ 46,864
Restricted cash	135	1,495
Total cash, cash equivalents and restricted cash	$ 43,775	$ 48,359	$ 1,458	$ 4,295

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LEASES (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Lease cost
Operating lease costs	$ 196	$ 235
Short-term lease costs	4,003	1,889
Variable lease costs		229
Total lease costs	4,199	2,353
Other information
Operating cash flows from operating leases	$ 196	$ 328
Weighted-average remaining lease term - operating leases	1 year 4 months 24 days	2 months 12 days
Weighted-average discount rate - operating leases	4.29%	3.70%
Initial lease term	2 years 3 months 18 days		2 years 3 months 18 days

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LEASES - Reported under ASC 842 and ASC 840 (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Future minimum lease payments for non-cancellable operating leases
Remaining period in 2022	$ 196
2023	359
Total operating lease payment	555
Less: discount to present value	16
Total operating lease liabilities	539
Less: current operating lease liabilities	377	$ 369
Noncurrent operating lease liabilities	$ 162	$ 352

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OPERATING REVENUES - Revenue Recognition (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Disaggregation of operating revenue
Total oil, natural gas and natural gas liquids sales	$ 101,290	$ 64,103	$ 182,698	$ 119,369
Other	221	263	415	515
Total operating revenues	101,511	64,366	183,113	119,884
Oil
Disaggregation of operating revenue
Total oil, natural gas and natural gas liquids sales	73,944	51,935	136,468	93,205
Natural gas
Disaggregation of operating revenue
Total oil, natural gas and natural gas liquids sales	14,759	5,317	23,640	14,404
NGLs
Disaggregation of operating revenue
Total oil, natural gas and natural gas liquids sales	12,587	$ 6,851	22,590	$ 11,760
Accounts receivable
Disaggregation of operating revenue
Due from contracts with customers	$ 47,600		$ 47,600		$ 35,100

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OIL AND NATURAL GAS PROPERTIES (Details)	6 Months Ended
	Jun. 30, 2022 $ / MMBTU $ / bbl	Jun. 30, 2021 $ / MMBTU $ / bbl
Ceiling Limitation Disclosures
First-day-of-month 12-month average price for natural gas (in $/MMBtu) | $ / MMBTU	5.13	2.43
First-day-of-month 12-month average price for crude oil used in ceiling test impairment (in dollars per barrel) | $ / bbl	85.82	49.72

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DEBT (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021	Nov. 24, 2021
Current and long-term debt
Debt	$ 203,372	$ 181,650
Current portion of long-term debt	15,000	85
Total long-term debt	188,372	181,565
Unamortized premium related to debt issued	15,000
Term loan credit facility
Current and long-term debt
Debt	203,372	181,565
Unamortized debt issuance costs	12,400	14,200
Allocated to the change of control call option embedded derivative	4,200	4,200
Term loan credit facility | Other noncurrent liabilities - liabilities from derivative contracts
Current and long-term debt
Allocated to the change of control call option embedded derivative			$ 4,200
Paycheck Protection Program Loan [Member]
Current and long-term debt
Debt		85
Current portion of long-term debt	$ 15,000	$ 85

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DEBT - Term Loan Credit Facility (Details) - USD ($) $ in Millions		6 Months Ended	7 Months Ended
	Nov. 24, 2021	Jun. 30, 2022	Jun. 30, 2022
Term loan credit facility
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 200.0
Amount available for issuance of letters of credit	$ 5.0
Applicable margin (as a percent)	7.00%
Credit facility term			18 months
Maturity date		Nov. 24, 2025
Amount outstanding		$ 220.0	$ 220.0
Letters of credit outstanding		$ 1.3	1.3
Covenant compliance		As of June 30, 2022, the Company was in compliance with the financial covenants under the Term Loan Agreement.
Threshold from capital expenditures to cash balance		$ 20.0
Aggregate scheduled amortization payments		$ 120.0	120.0
Term loan credit facility | Minimum
Debt Instrument [Line Items]
Current ratio	1.00%
Term loan credit facility | Maximum
Debt Instrument [Line Items]
Current ratio	1.00%
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 | Amount available to be drawn up to 18 months from November 24, 2021
Debt Instrument [Line Items]
Incremental borrowing that we can make if we meet certain criteria	$ 20.0
Term loan credit facility | Amount available to be drawn up to 18 months after November 24, 2021
Debt Instrument [Line Items]
Incremental borrowing that we can make if we meet certain criteria	$ 15.0
Term loan credit facility | Fiscal quarter ending June 30, 2022 | Minimum
Debt Instrument [Line Items]
Asset coverage ratio	1.00%
Term loan credit facility | Fiscal quarter ending June 30, 2022 | Maximum
Debt Instrument [Line Items]
Asset coverage ratio	1.60%
Term loan credit facility | Fiscal quarter ending September 30, 2022 | Minimum
Debt Instrument [Line Items]
Asset coverage ratio	1.00%
Term loan credit facility | Fiscal quarter ending September 30, 2022 | Maximum
Debt Instrument [Line Items]
Asset coverage ratio	1.70%
Term loan credit facility | Fiscal quarter ending December 31, 2022 and each fiscal quarter thereafter | Minimum
Debt Instrument [Line Items]
Asset coverage ratio	1.00%
Term loan credit facility | Fiscal quarter ending December 31, 2022 and each fiscal quarter thereafter | Maximum
Debt Instrument [Line Items]
Asset coverage ratio	1.80%
Term loan credit facility | Fiscal quarter ending December 31, 2021 through and including June 30, 2022 | Minimum
Debt Instrument [Line Items]
Net Leverage Ratio	1.00%
Term loan credit facility | Fiscal quarter ending December 31, 2021 through and including June 30, 2022 | Maximum
Debt Instrument [Line Items]
Net Leverage Ratio	3.25%
Term loan credit facility | Fiscal quarter ending September 30, 2022 and December 31, 2022 | Minimum
Debt Instrument [Line Items]
Net Leverage Ratio	1.00%
Term loan credit facility | Fiscal quarter ending September 30, 2022 and December 31, 2022 | Maximum
Debt Instrument [Line Items]
Net Leverage Ratio	3.00%
Term loan credit facility | Fiscal quarter ending March 31, 2023 | Minimum
Debt Instrument [Line Items]
Net Leverage Ratio	1.00%
Term loan credit facility | Fiscal quarter ending March 31, 2023 | Maximum
Debt Instrument [Line Items]
Net Leverage Ratio	2.75%
Term loan credit facility | Fiscal quarter ending each fiscal quarter thereafter | Minimum
Debt Instrument [Line Items]
Net Leverage Ratio	1.00%
Term loan credit facility | Fiscal quarter ending each fiscal quarter thereafter | Maximum
Debt Instrument [Line Items]
Net Leverage Ratio	2.50%
Delayed Draw Term Loan
Debt Instrument [Line Items]
Borrowing capacity available		$ 15.0	$ 15.0

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DEBT - Senior Facility (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
DEBT
Debt	$ 203,372	$ 181,650

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DEBT - Paycheck Protection Program Loan (Details) - USD ($) $ in Thousands			3 Months Ended	6 Months Ended
	Aug. 13, 2021	Apr. 16, 2020	Mar. 31, 2022	Jun. 30, 2022	Jun. 30, 2021
Current and long-term debt
Proceeds from issuance of debt				$ 20,000	$ 82,000
Paycheck Protection Program Loan [Member]
Current and long-term debt
Proceeds from issuance of debt		$ 2,200
Principal repaid			$ 200
Principal amount	$ 200
Forgiveness	$ 2,000
Gain (loss) on extinguishment of debt				$ 2,100

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DEBT - Debt Maturities and Debt Issuance Costs (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Debt Issuance Costs
Payment of debt issuance costs on Senior Credit Agreement	$ 379
Term loan credit facility
Debt Issuance Costs
Unamortized debt issuance costs	$ 12,400	$ 14,200

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FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Assets
Asset transfers between levels	$ 0
Liabilities
Liability transfers between levels	0
Recurring | Total
Assets
Receivables from derivative contracts	10,118	$ 3,898
Liabilities
Liabilities from derivative contracts	149,888	65,466
Recurring | Level 2
Assets
Receivables from derivative contracts	10,118	3,898
Liabilities
Liabilities from derivative contracts	$ 149,888	$ 65,466

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FAIR VALUE MEASUREMENTS - Change of Control Call Option (Details) - Change of Control Call Option $ in Thousands	6 Months Ended
	Jun. 30, 2022 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Balance at the beginning of the period	$ 4,003
Change in fair value	(2,595)
Balance at the end of the period	$ 1,408

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DERIVATIVE AND HEDGING ACTIVITIES - (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Derivative and hedging activities
Asset derivative contracts	$ 10,118	$ 3,898
Liability derivative contracts	(149,888)	(65,466)
Derivatives not designated as hedging contracts
Derivative and hedging activities
Asset derivative contracts	10,118	3,898
Liability derivative contracts	(149,888)	(65,466)
Derivatives not designated as hedging contracts | Commodity contracts | Current assets - receivables from derivative contracts
Derivative and hedging activities
Asset derivative contracts	6,146	1,383
Derivatives not designated as hedging contracts | Commodity contracts | Other noncurrent assets - receivables from derivative contracts
Derivative and hedging activities
Asset derivative contracts	3,972	2,515
Derivatives not designated as hedging contracts | Commodity contracts | Current liabilities - liabilities from derivative contracts
Derivative and hedging activities
Liability derivative contracts	(91,750)	(58,322)
Derivatives not designated as hedging contracts | Commodity contracts | Other noncurrent liabilities - liabilities from derivative contracts
Derivative and hedging activities
Liability derivative contracts	$ (58,138)	$ (7,144)

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DERIVATIVE AND HEDGING ACTIVITIES - Realized Unrealized (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative and hedging activities
Total net gain (loss) on derivative contracts	$ (31,910)	$ (53,089)	$ (155,768)	$ (98,800)
Derivatives not designated as hedging contracts | Commodity contracts
Derivative and hedging activities
Total net gain (loss) on derivative contracts	(31,910)	(53,089)	(155,768)	(98,800)
Derivatives not designated as hedging contracts | Commodity contracts | Other Income Expense
Derivative and hedging activities
Unrealized gain (loss) on commodity contracts	12,837	(34,817)	(78,201)	(70,869)
Realized gain (loss) on commodity contracts	$ (44,747)	$ (18,272)	$ (77,567)	$ (27,931)

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DERIVATIVE AND HEDGING ACTIVITIES - Open Contracts (Details)	6 Months Ended
	Jun. 30, 2022 MMBTU $ / MMBTU $ / bbl bbl
January 2022 - December 2022 | Fixed Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,240,865
January 2022 - December 2022 | Fixed Swap | Crude oil | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) | $ / bbl	52.80
January 2022 - December 2022 | Fixed Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	1,167,500
January 2022 - December 2022 | Fixed Swap | Natural Gas [Member] | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.92
January 2022 - December 2022 | Basis Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,222,565
January 2022 - December 2022 | Basis Swap | Crude oil | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) | $ / bbl	0.41
January 2022 - December 2022 | Basis Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	3,640,900
January 2022 - December 2022 | Basis Swap | Natural Gas [Member] | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	(0.51)
January 2022 - December 2022 | WTI NYMEX Roll | Crude oil | Maximum
Derivative and hedging activities
Volume in Bbl's | bbl	1,005,565
January 2022 - December 2022 | WTI NYMEX Roll | Crude oil | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's) | $ / bbl	0.10
January 2022 - December 2022 | Collars | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	2,473,400
January 2022 - December 2022 | Call option | Natural Gas [Member] | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.97
January 2022 - December 2022 | Put options | Natural Gas [Member] | Weighted Average
Derivative and hedging activities
Weighted Average Price (in dollars per Mmbtu's/Bbl's)	3.48
January 2023 - December 2023 | Fixed Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	2,000,965
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	65.75
January 2023 - December 2023 | Fixed Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	3,957,750
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)	3.36
January 2023 - December 2023 | Basis Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,937,165
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	0.25
January 2023 - December 2023 | Basis Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	5,700,600
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)	(0.64)
January 2023 - December 2023 | WTI NYMEX Roll | Crude oil | Maximum
Derivative and hedging activities
Volume in Bbl's | bbl	1,937,165
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	0.50
January 2023 - December 2023 | Collars | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	1,742,100
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)	5.52
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)	3.86
January 2024 - December 2024 | Fixed Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,449,140
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	60.91
January 2024 - December 2024 | Fixed Swap | Natural Gas [Member] | Minimum
Derivative and hedging activities
Floor (in dollars per Mmbtu's/Bbl's)	2,658,750
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)	3.09
January 2024 - December 2024 | Basis Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,413,120
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	0.23
January 2024 - December 2024 | Basis Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	4,084,350
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)	(0.64)
January 2024 - December 2024 | WTI NYMEX Roll | Crude oil | Maximum
Derivative and hedging activities
Volume in Bbl's | bbl	1,413,120
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	0.28
January 2024 - December 2024 | Collars | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	1,424,100
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)	4.70
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)	3.19
January 2025 - December 2025 | Fixed Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,028,160
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	59.69
January 2025 - December 2025 | Fixed Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	2,428,050
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)	3.00
January 2025 - December 2025 | Basis Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	1,000,360
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	0.17
January 2025 - December 2025 | Basis Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	2,983,750
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)	(0.56)
January 2025 - December 2025 | WTI NYMEX Roll | Crude oil | Maximum
Derivative and hedging activities
Volume in Bbl's | bbl	1,000,360
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	0.10
January 2025 - December 2025 | Collars | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	555,700
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)	4.24
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)	3.28
January 2026 - December 2026 | Fixed Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	212,810
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	59.83
January 2026 - December 2026 | Basis Swap | Crude oil
Derivative and hedging activities
Volume in Bbl's | bbl	212,810
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	0.19
January 2026 - December 2026 | Basis Swap | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	653,900
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)	(0.96)
January 2026 - December 2026 | WTI NYMEX Roll | Crude oil | Maximum
Derivative and hedging activities
Volume in Bbl's | bbl	212,810
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	0.27
January 2026 - December 2026 | Collars | Natural Gas [Member]
Derivative and hedging activities
Volume in Mmbtu's | MMBTU	653,900
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)	4.45
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)	4.00

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DERIVATIVE AND HEDGING ACTIVITIES - Netting Arrangements (Details) - USD ($) $ in Thousands	Jun. 30, 2022	Dec. 31, 2021
Derivative Assets
Gross Amounts Presented in the Consolidated Balance Sheet	$ 10,118	$ 3,898
Amounts Not Offset in the Consolidated Balance Sheet	(10,118)	(3,898)
Net Amount	0	0
Derivative Liabilities
Gross Amounts Presented in the Consolidated Balance Sheet	(149,888)	(65,466)
Amounts Not Offset in the Consolidated Balance Sheet	10,118	3,898
Net Amount	$ (139,770)	$ (61,568)

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ASSET RETIREMENT OBLIGATIONS (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2022 USD ($)
Activity related to ARO liability
Liability for asset retirement obligations at the beginning of the period	$ 11,896
Liabilities incurred during the period	103
Liabilities settled and divested	(132)
Accretion expense	220
Liability for asset retirement obligations at the end of the period	$ 12,087

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COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) contract
Purchase commitments related to equipment
Total	$ 1.7
Remaining commitment	3.3
Drilling rig commitment	1.7
Early termination penalty	$ 0.6
Gathering, transportation and sales | West Texas
Purchase commitments related to equipment
Number of long-term crude oil sales contracts to which the entity is committed | contract	2
Number of long-term natural gas sales contracts to which the entity is committed | contract	12
Gathering, transportation and sales | West Texas | Minimum
Purchase commitments related to equipment
Period of commitment for production from the date of first production	1 year
Gathering, transportation and sales | West Texas | Maximum
Purchase commitments related to equipment
Period of commitment for production from the date of first production	20 years

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STOCKHOLDERS' EQUITY - Warrants (Details) - $ / shares	Oct. 08, 2019	Jun. 30, 2022
Stockholders' equity
Number of shares of common stock that can be purchased from warrants		1
Warrants issued	6,900,000
Annualized rate of increase to the strike price of warrants issued under the warrants agreement.		6.75%
Warrant term (in years)		3 years
Warrant maturity date		Oct. 08, 2022
Minimum
Stockholders' equity
Exercise price (in dollars per share)	$ 40.17
Maximum
Stockholders' equity
Exercise price (in dollars per share)	$ 60.45
Series A Warrants
Stockholders' equity
Exercise price (in dollars per share)		$ 46.15
Number of warrants issued		1,800,000
Series B Warrants
Stockholders' equity
Exercise price (in dollars per share)		$ 55.86
Number of warrants issued		2,200,000
Series C Warrants
Stockholders' equity
Exercise price (in dollars per share)		$ 70.42
Number of warrants issued		2,900,000

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STOCKHOLDERS' EQUITY - Incentive Plans (Details) $ / shares in Units, shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) $ / shares shares	Jun. 30, 2021 USD ($)	Jan. 29, 2020 shares
General and administrative
Stock-based compensation
Compensation expense recorded | $	$ 0.9	$ 1.1
Restricted Stock
Number of Shares
Granted (in shares)	0.2
Weighted Average Grant Date fair Value Per Share
Granted (in dollars per share) | $ / shares	$ 14.07
2020 Incentive Plan | Common Stock
Stock-based compensation
Aggregate number of shares available			1.8
2020 Incentive Plan | Common Stock | Maximum
Stock-based compensation
Maximum number of shares that remained reserved for issuance under the Plan	0.3
2020 Incentive Plan | Stock options
Stock-based compensation
Percentage of awards vesting on the annual anniversary date of the grant	25

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STOCKHOLDERS' EQUITY - Stock Options (Details) - Stock options $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) shares
Stock-based compensation
Vesting period	4 years
Expiration term	7 years
Unrecognized compensation expense stock option | $	$ 0.3
Weighted average remaining vesting period	1 year 1 month 6 days
2020 Incentive Plan
Stock-based compensation
Percentage of awards vesting on the annual anniversary date of the grant	25
Granted (in shares) | shares	0

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STOCKHOLDERS' EQUITY - Restricted Stock (Details) - Restricted Stock $ / shares in Units, shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) $ / shares shares
Stock-based compensation
Number of shares granted | shares	0.2
Granted (in dollars per share) | $ / shares	$ 14.07
Unrecognized compensation expense other than options | $	$ 4.1
Weighted average remaining vesting period	1 year 7 months 6 days
Minimum
Stock-based compensation
Vesting period	3 years
Maximum
Stock-based compensation
Vesting period	4 years

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Basic:
Net income (loss) available to common stockholders	$ 13,047	$ (33,929)	$ (79,697)	$ (67,304)
Weighted average basic number of common shares outstanding	16,338	16,268	16,320	16,250
Basic net income (loss) per share of common share (in dollars per share)	$ 0.80	$ (2.09)	$ (4.88)	$ (4.14)
Diluted:
Net income (loss) available to common stockholders	$ 13,047	$ (33,929)	$ (79,697)	$ (67,304)
Weighted average basic number of common shares outstanding	16,338	16,268	16,320	16,250
Common stock equivalent shares representing shares included upon Vesting of restricted shares	172
Weighted average diluted number of common shares outstanding	16,510	16,268	16,320	16,250
Diluted net income (loss) per share of common stock (in dollars per share)	$ 0.79	$ (2.09)	$ (4.88)	$ (4.14)
Common stock equivalents excluded from computation of diluted earnings per share of common stock because of anti-dilutive effect	7,400		7,700	7,700

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ADDITIONAL FINANCIAL STATEMENT INFORMATION (Details) $ in Thousands	1 Months Ended
	May 31, 2022 MMcf / d	Jun. 30, 2022 USD ($)	Dec. 31, 2021 USD ($)
Accounts receivable:
Oil, natural gas and natural gas liquids revenues		$ 47,221	$ 34,110
Joint interest accounts		5,590	2,503
Other		191	193
Total		53,002	36,806
Prepaids and other:
Prepaids		536	975
Funds in escrow		390	390
Other		1	1
Total		927	1,366
Other assets:
Investment in Unconsolidated Affiliate		1,653
Oil, natural gas and natural gas liquids revenues		417	1,010
Funds in escrow		1,228	1,227
Other		31	33
Total		3,329	2,270
Accounts payable and accrued liabilities:
Trade payables		36,885	25,315
Accrued oil and natural gas capital costs		20,518	4,881
Revenues and royalties payable		29,534	22,763
Accrued interest expense		57	42
Accrued employee compensation		2,073	3,735
Accrued lease operating expenses		6,212	6,090
Drilling advances from partners		2,055
Total		$ 97,334	$ 62,826
Minimum volume commitment | MMcf / d	20
Volume commitment term	5 years
Brazos Amine Treater, LLC [Member]
Accounts payable and accrued liabilities:
Equity interest	5.00%