Tellurian (TELZ) 10-K 23 Feb 24 2023 FY Annual report Financial data

Cover

Cover - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Feb. 08, 2024	Jun. 30, 2023
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2023
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-5507
Entity Registrant Name	TELLURIAN INC. /DE/
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	06-0842255
Entity Address, Address Line One	1201 Louisiana Street,
Entity Address, Address Line Two	Suite 3100,
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	832
Local Phone Number	962-4000
Entity Well Known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction [Flag]	false
Entity Shell Company	false
Entity Public Float			$ 767,326
Entity Common Stock, Shares Outstanding		782,393,431
Documents Incorporated by Reference	Portions of the definitive proxy statement related to the 2024 annual meeting of stockholders, to be filed within 120 days after December 31, 2023, are incorporated by reference in Part III of this annual report on Form 10-K.
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
Entity Central Index Key	0000061398
Common Stock
Document Information [Line Items]
Title of 12(b) Security	Common stock, par value $0.01 per share
Trading Symbol	TELL
Security Exchange Name	NYSE
Senior Unsecured Notes due 2028
Document Information [Line Items]
Title of 12(b) Security	8.25% Senior Notes due 2028
Trading Symbol	TELZ
Security Exchange Name	NYSE

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2023
Audit Information [Abstract]
Auditor Location	Houston, Texas
Auditor Name	DELOITTE & TOUCHE LLP
Auditor Firm ID	34

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 75,789	$ 474,205
Accounts receivable	25,790	76,731
Prepaid expenses and other current assets	15,951	23,355
Total current assets	117,530	574,291
Property, plant and equipment, net	1,136,299	789,076
Other non-current assets	70,199	63,316
Total assets	1,324,028	1,426,683
Current liabilities:
Accrued and other liabilities	123,650	129,180
Borrowings	0	163,556
Total current liabilities	179,198	297,541
Long-term liabilities:
Borrowings	361,402	382,208
Finance lease liabilities	121,450	49,963
Other non-current liabilities	37,054	24,428
Total long-term liabilities	519,906	456,599
Commitments and Contingencies (Note 10)
Stockholders’ equity:
Preferred stock, $0.01 par value, 100,000,000 shares authorized: 6,123,782 and 6,123,782 shares outstanding, respectively	61	61
Common stock, $0.01 par value, 1,600,000,000 and 800,000,000 shares authorized: 703,739,585 and 564,567,568 shares outstanding, respectively	6,866	5,456
Additional paid-in capital	1,765,044	1,647,896
Accumulated deficit	(1,147,047)	(980,870)
Total stockholders’ equity	624,924	672,543
Total liabilities and stockholders’ equity	1,324,028	1,426,683
Nonrelated Party
Current liabilities:
Accounts payable	$ 55,548	$ 4,805

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Preferred stock, par value (in usd per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	100,000,000	100,000,000
Preferred stock, shares outstanding (in shares)	6,123,782	6,123,782
Common stock, par value (in usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	1,600,000,000	800,000,000
Common stock, shares, outstanding (in shares)	703,739,585	564,567,568

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Revenues:
Total revenue	$ 166,128	$ 391,926	$ 71,275
Operating costs and expenses:
Operating expenses	78,186	37,886	11,693
Development expenses	35,616	68,782	50,186
Depreciation, depletion and amortization	98,426	44,357	11,481
General and administrative expenses	101,902	126,386	85,903
Related party charges (Note 6)	660	625	0
Total operating costs and expenses	314,790	409,699	184,008
Loss from operations	(148,662)	(17,773)	(112,733)
Interest expense, net	(18,047)	(13,860)	(9,378)
(Loss) gain on extinguishment of debt, net	(32,295)	0	1,422
Other income (expense), net	32,827	(18,177)	5,951
Loss before income taxes	(166,177)	(49,810)	(114,738)
Income tax benefit (provision)	0	0	0
Net loss	$ (166,177)	$ (49,810)	$ (114,738)
Net loss per common share:
Basic (in dollars per share)	$ (0.29)	$ (0.09)	$ (0.28)
Diluted (in dollars per share)	$ (0.29)	$ (0.09)	$ (0.28)
Weighted average shares outstanding:
Basic (in shares)	565,678	526,946	407,615
Diluted (in shares)	565,678	526,946	407,615
Natural gas sales
Revenues:
Total revenue	$ 166,128	$ 270,975	$ 51,499
LNG sales
Revenues:
Total revenue	0	120,951	19,776
Operating costs and expenses:
LNG cost of sales	$ 0	$ 131,663	$ 24,745

CONSOLIDATED STATEMENT OF CHANG

CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY - USD ($) $ in Thousands	Total	Preferred stock	Common Stock	Additional Paid-in Capital	Accumulated Deficit
Beginning balance at Dec. 31, 2020	$ 109,090		$ 3,309	$ 922,042	$ (816,322)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock issuance			1,361	406,493
Share-based compensation, net			43	7,892
Shared-based payments			1	200
Warrants exercised			60	8,117
Debt extinguishment				(218)
Net loss	(114,738)				(114,738)
Ending balance at Dec. 31, 2021	418,301	$ 61	4,774	1,344,526	(931,060)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock issuance			677	299,063
Share-based compensation, net			3	3,631
Shared-based payments			2	676
Net loss	(49,810)				(49,810)
Ending balance at Dec. 31, 2022	672,543	61	5,456	1,647,896	(980,870)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock issuance			1,407	115,614
Share-based compensation, net			3	1,534
Net loss	(166,177)
Ending balance at Dec. 31, 2023	$ 624,924	$ 61	$ 6,866	$ 1,765,044	$ (1,147,047)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Cash flows from operating activities:
Net loss	$ (166,177)	$ (49,810)	$ (114,738)
Adjustments to reconcile Net loss to Net cash used in operating activities:
Depreciation, depletion and amortization	98,426	44,357	11,481
Amortization of debt issuance costs, discounts and fees	7,111	2,424	3,102
Share-based compensation	1,537	3,633	5,950
Share-based payments	0	678	200
Interest elected to be paid-in-kind	0	0	508
Loss (gain) on financial instruments not designated as hedges	10,346	(9,073)	(8,693)
Total gains or losses (realized and unrealized) included in earnings	(18,594)	0	0
Loss (gain) on extinguishment of debt, net	32,295	0	(1,422)
Other	2,977	1,210	1,035
Net changes in working capital (Note 17)	20,890	(15,953)	41,017
Net cash used in operating activities	(11,189)	(22,534)	(61,560)
Cash flows from investing activities:
Acquisition and development of natural gas properties	(113,653)	(344,800)	(32,364)
Driftwood Project construction costs	(200,127)	(175,791)	(15,208)
Land purchases and land improvements	0	(23,492)	(10,293)
Investment in unconsolidated entity	0	(6,089)	0
Note receivable	(18,000)	(6,595)	0
Capitalized internal use software and other assets	(3,725)	(8,804)	0
Net cash used in investing activities	(335,505)	(565,571)	(57,865)
Cash flows from financing activities:
Proceeds from common stock issuances	115,612	309,021	421,809
Equity issuance costs	(3,489)	(9,281)	(13,955)
Borrowing proceeds	0	501,178	56,500
Borrowing issuance costs	0	(11,487)	(2,854)
Borrowing principal repayments	(166,666)	0	(119,725)
Proceeds from warrant exercise	0	0	8,177
Tax payments for net share settlements of equity awards (Note 17)	0	0	(3,064)
Other	(1,854)	(132)	(1,926)
Net cash (used in) provided by financing activities	(56,397)	789,299	344,962
Net (decrease) increase in cash, cash equivalents and restricted cash	(403,091)	201,194	225,537
Cash, cash equivalents and restricted cash, beginning of period	508,468	307,274	81,737
Cash, cash equivalents and restricted cash, end of period	105,377	508,468	307,274
Supplementary disclosure of cash flow information:
Interest paid, net of capitalized interest	$ 14,203	$ 20,647	$ 4,105

ORGANIZATION AND NATURE OF OPER

ORGANIZATION AND NATURE OF OPERATIONS	12 Months Ended
	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND NATURE OF OPERATIONS	NOTE 1 — ORGANIZATION AND NATURE OF OPERATIONS Tellurian Inc. (“Tellurian,” “we,” “us,” “our,” or the “Company”), a Delaware corporation, is a Houston-based company that is developing and plans to own and operate a portfolio of LNG marketing and infrastructure assets that includes an LNG terminal facility (the “Driftwood terminal”) and related pipelines. The Driftwood terminal and related pipelines are collectively referred to as the “Driftwood Project.” We also own upstream natural gas assets. On February 6, 2024, we announced that we are exploring a sale of those assets. See Note 19, Subsequent Events , for further information. We refer to the Driftwood Project and our upstream assets collectively as the “Business.” The terms “we,” “our,” “us,” “Tellurian” and the “Company” as used in this report refer collectively to Tellurian Inc. and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity associated with Tellurian Inc.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation Our Consolidated Financial Statements have been prepared in accordance with GAAP. The Consolidated Financial Statements include the accounts of Tellurian Inc. and its wholly owned subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications did not have a material effect on our consolidated financial position, results of operations or cash flows. Going Concern Our Consolidated Financial Statements have been prepared in accordance with GAAP, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business as well as the Company’s ability to continue as a going concern. In accordance with ASC Subtopic 205-40, Presentation of Financial Statements—Going Concern , the Company evaluates whether conditions and/or events raise substantial doubt about its ability to meet its obligations as they become due within one year after the date that the financial statements are issued. As of December 31, 2023, the Company has generated losses and cash outflows from operations. We have not yet established an ongoing source of revenues that is sufficient to satisfy our future liquidity thresholds and obligations and fund our working capital needs as they become due during the twelve months following the issuance of the financial statements. These conditions raise substantial doubt about our ability to continue as a going concern. To date, the Company has been meeting its liquidity needs primarily from cash on hand and the combined proceeds generated by debt and equity issuances, upstream operations, and the sale of common stock under its at-the-market equity offering programs. Our evaluation does not take into consideration the potential mitigating effect of activities that have not been fully implemented or are not within the Company’s direct control. Since the issuance of our interim Condensed Consolidated Financial Statements on November 2, 2023, and through the date of this filing, the Company has undertaken the following actions to improve its available cash balances and liquidity: • From November 2, 2023 to December 31, 2023, raised net proceeds of approximately $40.2 million from the sale of common stock under our at-the-market equity offering program; • Subsequent to December 31, 2023, raised net proceeds of approximately $17.8 million from the sale of common stock under our at-the-market equity offering program (See Note 19, Subsequent Events ); • Executed amendments to the Company’s Replacement Notes indentures (See Note 19, Subsequent Events ); • Initiated a process to explore the sale of our upstream natural gas assets (See Note 19, Subsequent Events ). Despite these actions, the Company will need to take further measures to generate additional proceeds from various other potential transactions, such as issuances of equity, equity-linked and debt securities, or similar transactions, managing costs, amending or refinancing the Replacement Notes and offering equity interests in the Driftwood Project (collectively “Management’s Plans”). The Company's ability to effectively implement Management’s Plans is subject to numerous risks and uncertainties such as a potential inability to sell our upstream assets, market demand for our equity and debt securities, commodity prices and other factors affecting natural gas markets. As of the date of this filing, Management’s Plans have not been finalized and are not within the Company’s control and, therefore, cannot be deemed probable. As a result, there remains substantial doubt about the Company’s ability to continue as a going concern. The Consolidated Financial Statements do not include any adjustments to the carrying amounts and classification of assets, liabilities, and reported expenses that may be necessary if the Company were unable to continue as a going concern. Segments Segment information is prepared on the same basis that our Chief Operating Decision Maker, uses to manage the segments, evaluate financial results and make key operating decisions. We identified the Upstream, Midstream and Marketing & Trading components as the Company’s operating segments. These operating segments represent the Company’s reportable segments. The remainder of our business is presented as “Corporate,” and consists of corporate costs and intersegment eliminations. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions on a regular basis. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates. Fair Value Fair value is 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. The Company uses three levels of the fair value hierarchy of inputs to measure the fair value of an asset or a liability. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Level 3 inputs are inputs that are not observable in the market. Revenue Recognition For the sale of natural gas, we consider the delivery of each unit (MMBtu) to be a separate performance obligation that is satisfied upon delivery to the designated sales point and therefore is recognized at a point in time. These contracts are either fixed price contracts or contracts with a fixed differential to an index price, both of which are deemed fixed consideration that is allocated to each performance obligation and represents the relative standalone selling price basis. Each LNG cargo, in its entirety, is deemed to be a single performance obligation due to each molecule of LNG being distinct and substantially the same and therefore meeting the criteria for the transfer of a series of distinct goods. Accordingly, LNG sales are recognized at a point in time when the LNG has completed discharging to the customer. These are contracts with a fixed differential to an index price, which is deemed fixed consideration that is allocated to each performance obligation and represents the relative standalone selling price basis. These LNG sales are recorded on a gross basis and reported in “LNG sales” on the Consolidated Statements of Operations. Purchases and sales of LNG inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “LNG sales” on the Consolidated Statements of Operations. For such LNG sales, we require payment within 10 days from delivery. We exclude all taxes from the measurement of the transaction price. Receivables The Company’s accounts receivable consist primarily of trade receivables from natural gas sales and joint interest billings due from owners on properties the Company operates. The majority of these receivables have payment terms of 30 days or less. The Company generally has the ability to withhold future revenue disbursements to recover non-payment of joint interest billings for receivables due from joint interest owners. We evaluate expected credit losses on our receivables based on relevant information about past events, including historical experience and other relevant conditions which may impact their carrying value. The Company’s historical credit losses have been de minimis and are expected to remain so in the future assuming no substantial changes to the business or creditworthiness of the Company’s counterparties. Cash, Cash Equivalents and Restricted Cash We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. Cash and cash equivalents that are restricted as to withdrawal or use under the terms of certain contractual agreements are recorded as restricted cash on our Consolidated Balance Sheets. The carrying value of cash, cash equivalents and restricted cash approximates their fair value. Concentration of Cash We maintain cash balances and restricted cash at financial institutions, which may, at times, be in excess of federally insured levels. We have not incurred losses related to these balances to date. Derivative Instruments We may use derivative instruments to hedge our exposure to cash flow variability from commodity price risk. Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities, depending on the derivative position and the expected timing of settlement, unless they satisfy the criteria for and we elect the normal purchases and sales exception. We have not elected and do not apply hedge accounting for our derivative instruments; therefore, all changes in fair value of the Company’s derivative instruments are recognized within Other income, net, in the Consolidated Statements of Operations. Settlements of derivative instruments are reported as a component of cash flows from operations in the Consolidated Statements of Cash Flows. Property, Plant and Equipment Natural gas development and production activities are accounted for using the successful efforts method of accounting. Costs incurred to acquire a property (whether proved or unproved) are capitalized when incurred. Costs to develop proved reserves are capitalized and our natural gas reserves are depleted using the units-of-production method. Fixed assets are recorded at cost. We depreciate our property, plant and equipment, excluding land, using the straight-line depreciation method over the estimated useful life of the asset. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed, and the resulting gains or losses are recorded in our Consolidated Statements of Operations. Management tests property, plant and equipment for impairment whenever there are indicators that the carrying amount of property, plant and equipment might not be recoverable. The carrying values of our proved natural gas properties are reviewed for impairment when events or circumstances indicate that the remaining carrying value may not be recoverable. If there is an indication that the carrying amount of our proved natural gas properties may not be recoverable, we compare the estimated probability-weighted undiscounted future cash flows from our natural gas properties to the carrying values of those properties. Proved properties that have carrying amounts in excess of estimated undiscounted cash flows are written down to fair value. Leases The Company determines if an arrangement is a lease at inception. Leases are recognized as either finance or operating leases on our Consolidated Balance Sheets by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. We combine lease and non-lease components of an arrangement for all classes of our leased assets and omit short-term leases with a term of 12 months or less from recognition on the balance sheet. In the absence of a readily determinable implicit interest rate, we discount our expected future lease payments using our incremental borrowing rate. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability, only to the extent they are reasonably certain to be exercised. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Lease expense for finance leases is recognized as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities over the lease term. Accounting for LNG Development Activities During the preliminary stage of developing the Driftwood terminal, substantially all the costs related to such activities have been expensed. These costs primarily included professional fees associated with FEED studies and complying with FERC for authorization to construct our terminal and other required permitting for the Driftwood Project. Costs incurred in connection with a project to develop the Driftwood terminal shall generally be treated as development expenses until the project has reached the notice-to-proceed state (“NTP State”) and the following criteria (the “NTP Criteria”) have been met: (i) the necessary regulatory permits have been obtained, (ii) financing for the project has been secured and (iii) management has committed to commence construction. In addition, certain costs incurred prior to achieving the NTP State will be capitalized although the NTP Criteria have not been met. Costs to be capitalized prior to achieving the NTP State include land purchase costs, land improvement costs, costs associated with preparing the facility for use, direct payroll and payroll benefit-related costs and any fixed structure construction costs (fence, storage areas, drainage, etc.). Furthermore, activities directly associated with detailed engineering and/or facility designs shall be capitalized. Interest is capitalized in connection with the construction of major facilities. All amounts capitalized are periodically assessed for impairment and may be impaired if indicators are present. Prior to reaching the NTP State, costs incurred to complete construction activities necessary to proceed under our LSTK EPC agreement with Bechtel are capitalized as construction in progress when the following criteria are met: (i) costs incurred are directly identifiable, (ii) necessary regulatory permits are secured, (iii) funding for the scope of work is available, and (iv) construction activities are creditable under the LSTK EPC agreement. Prior to reaching the NTP State, costs incurred to complete construction activities necessary to develop the Driftwood pipelines are capitalized as construction in progress when the following criteria are met: (i) costs incurred are directly identifiable, (ii) necessary regulatory permits are secured, and (iii) funding for the scope of work is available. Debt Discounts, premiums, fees and expenses incurred with the issuance of debt are amortized over the term of the debt. These amounts are presented net of our indebtedness balances on the accompanying Consolidated Balance Sheets. We evaluate embedded features within a debt host contract to determine whether there are embedded derivatives that should be bifurcated and carried separately at fair value. Embedded derivatives that are not clearly and closely related to the host contract are bifurcated and recorded at fair value with subsequent changes in fair value recorded in the Consolidated Statements of Operations. Share-Based Compensation We have awarded share-based compensation in the form of stock, restricted stock, restricted stock units and stock options to employees, directors and outside consultants. Share-based compensation transactions are measured based on the grant-date estimated fair value. For awards containing only service conditions or performance conditions deemed probable of occurring, the fair value is recognized as expense over the requisite service period using the straight-line method. We recognize compensation cost for awards with performance conditions if and when we conclude that it is probable that the performance condition will be achieved. For awards where the performance or market condition is not considered probable, compensation cost is not recognized until the performance or market condition becomes probable. We reassess the probability of vesting at each reporting period for awards with performance conditions and adjust compensation cost based on our probability assessment. We recognize forfeitures as they occur. Income Taxes We account for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, we determine deferred tax assets and liabilities on the basis of the differences between the financial statement and tax basis of assets and liabilities by using enacted tax rates in effect for the year in which the differences are expected to be realized or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. We recognize deferred tax assets to the extent that we believe that these assets are more likely than not to be realized. In making such a determination, we consider current and historical financial results, expectations for future taxable income and the availability of tax planning strategies that can be implemented, if necessary, to realize deferred tax assets. If we determine that we would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we will make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes. Post employment benefits The Company provides cash and other termination benefits pursuant to ongoing benefit arrangements to its employees in connection with a qualifying termination of their employment. The cost of providing post employment benefits is recognized when the obligation is probable of occurring and can be reasonably estimated. Net Loss Per Share Basic net loss per share excludes dilution and is computed by dividing net loss by the weighted average number of common shares outstanding during the period. Diluted net loss per share reflects potential dilution and is computed by dividing net loss by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued and were dilutive.

PREPAID EXPENSES AND OTHER CURR

PREPAID EXPENSES AND OTHER CURRENT ASSETS	12 Months Ended
	Dec. 31, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
PREPAID EXPENSES AND OTHER CURRENT ASSETS	NOTE 3 — PREPAID EXPENSES AND OTHER CURRENT ASSETS Prepaid expenses and other current assets consist of the following (in thousands): December 31, 2023 2022 Prepaid expenses $ 1,788 $ 2,174 Restricted cash 4,688 9,375 Derivative asset, net - current (Note 9) — 10,463 Upstream pipe 4,278 978 Deposits and other current assets 5,197 365 Total prepaid expenses and other current assets $ 15,951 $ 23,355 Restricted Cash Restricted cash as of December 31, 2023 and December 31, 2022 represents cash held in escrow under the terms of the purchase and sale agreement for the acquisition of certain natural gas assets in the Haynesville Shale. See Note 4, Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	12 Months Ended
	Dec. 31, 2023
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT	NOTE 4 — PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment consist of the following (in thousands): December 31, 2023 2022 Upstream natural gas assets: Proved properties $ 492,506 $ 412,977 Wells in progress 68,797 55,374 Accumulated DD&A (187,171) (92,423) Total upstream natural gas assets, net 374,132 375,928 Driftwood Project assets: Terminal construction in progress 533,316 292,734 Pipeline construction in progress 35,939 — Land and land improvements 53,664 52,460 Finance lease assets, net of accumulated DD&A 55,534 56,708 Buildings and other assets, net of accumulated DD&A 310 340 Total Driftwood Project assets, net 678,763 402,242 Fixed assets and other: Finance lease assets, net of accumulated DD&A 70,691 — Leasehold improvements and other assets, net of accumulated DD&A 12,713 10,906 Total fixed assets and other, net 83,404 10,906 Total property, plant and equipment, net $ 1,136,299 $ 789,076 Depreciation, depletion and amortization expenses for the years ended December 31, 2023, 2022 and 2021 were approximately $98.4 million, $44.4 million and $11.5 million, respectively. Terminal Construction in Progress During the year ended December 31, 2023, we capitalized approximately $240.6 million of directly identifiable project costs as construction in progress, inclusive of approximately $22.4 million in capitalized interest. Pipeline Construction in Progress On April 21, 2023, the Company received FERC approval for the construction of the Driftwood pipelines. During the second quarter of 2023, pipeline materials and rights of way of approximately $14.6 million were transferred to construction in progress. For the year ended December 31, 2023, we also capitalized approximately $21.4 million of directly identifiable project costs as Pipeline construction in progress, inclusive of approximately $0.6 million in capitalized interest. Proved Properties

OTHER NON-CURRENT ASSETS

OTHER NON-CURRENT ASSETS	12 Months Ended
	Dec. 31, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
OTHER NON-CURRENT ASSETS	NOTE 5 — OTHER NON-CURRENT ASSETS Other non-current assets consist of the following (in thousands): December 31, 2023 2022 Restricted cash 24,900 24,888 Note receivable 24,189 6,595 Right of use asset — operating leases 12,814 13,303 Investment in unconsolidated entity 6,089 6,089 Pipeline materials and rights of way — 9,136 Permitting costs — 916 Land lease and purchase options $ — $ 300 Other 2,207 2,089 Total other non-current assets $ 70,199 $ 63,316 Restricted Cash Restricted cash as of December 31, 2023 and December 31, 2022, represents the cash collateralization of letters of credit associated with finance leases. Note Receivable In February 2023, the Company issued an amended and restated promissory note due June 14, 2031 (the “Note Receivable”) to an unaffiliated entity engaged in the development of infrastructure projects in the energy industry. The outstanding principal balance of the Note Receivable as of December 31, 2023 was approximately $24.2 million. The promissory note bears interest at a rate of 6.00%, which is capitalized into the outstanding principal balance annually. Investment in Unconsolidated Entities On February 24, 2022, the Company purchased 1.5 million ordinary shares of an unaffiliated entity that provides renewable energy services. The total cost of this investment was approximately $6.1 million. This investment does not provide the Company with a controlling financial interest in or significant influence over the operating or financial decisions of the unaffiliated entity. The Company’s investment was recorded at cost. Pipeline materials and rights of way Pipeline materials and rights of way were transferred to construction in progress in the second quarter of 2023. See Note 4, Property, Plant and Equipment.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2023
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 6 — RELATED PARTY TRANSACTIONS Related Party Contractor Service Fees and Expenses The Company entered into a one-year independent contractor agreement, effective January 1, 2022, with Mr. Martin Houston, the then-Vice Chairman of the Company’s Board of Directors. Pursuant to the terms and conditions of this agreement, the Company paid Mr. Houston a monthly fee of $50.0 thousand plus approved expenses. In December 2022, the Company amended the independent contractor agreement to expire on the earlier of (i) termination of Mr. Houston and (ii) December 31, 2023, and to increase the monthly fee to $55.0 thousand plus approved expenses. For the years ended December 31, 2023 and 2022, the Company paid Mr. Houston $660.0 thousand and $625.0 thousand, respectively, for contractor service fees and expenses. As of December 31, 2023 and 2022, there were no balances due to Mr. Houston.

ACCRUED AND OTHER LIABILITIES

ACCRUED AND OTHER LIABILITIES	12 Months Ended
	Dec. 31, 2023
Payables and Accruals [Abstract]
ACCRUED AND OTHER LIABILITIES	NOTE 7 — ACCRUED AND OTHER LIABILITIES Accrued and other liabilities consist of the following (in thousands): December 31, 2023 2022 Upstream accrued liabilities 47,652 $ 71,977 Payroll and compensation 15,423 37,329 Accrued taxes 1,476 730 Driftwood Project development activities 24,455 4,423 Lease liabilities 4,710 2,875 Accrued interest 8,293 5,793 Embedded derivative (Note 9) 13,332 — Other 8,309 6,053 Total accrued and other liabilities $ 123,650 $ 129,180

BORROWINGS

BORROWINGS	12 Months Ended
	Dec. 31, 2023
Debt Disclosure [Abstract]
BORROWINGS	NOTE 8 — BORROWINGS The Company’s borrowings consist of the following (in thousands): December 31, 2023 Principal repayment obligation Unamortized Discount (DFC) Carrying value Senior Secured Convertible Notes due 2025 $ 83,334 $ (10,415) $ 72,919 Senior Secured Notes due 2025 250,000 (16,954) 233,046 Senior Unsecured Notes due 2028 57,678 (2,241) 55,437 Total borrowings $ 391,012 $ (29,610) $ 361,402 December 31, 2022 Principal repayment obligation Unamortized DFC Carrying value Convertible Notes, current $ 166,666 $ (3,110) $ 163,556 Convertible Notes, non-current 333,334 (6,219) 327,115 Senior Unsecured Notes due 2028 57,678 (2,585) 55,093 Total borrowings $ 557,678 $ (11,914) $ 545,764 Amortization of the borrowings’ DFC is a component of Interest expense, net in the Company’s Consolidated Statements of Operations. We amortized approximately $7.1 million, $2.4 million, and $3.1 million during the years ended December 31, 2023, 2022, and 2021, respectively. Senior Secured Convertible Notes due 2025 (Extinguished) On June 3, 2022, we issued and sold $500.0 million aggregate principal amount of 6.00% Senior Secured Convertible Notes due May 1, 2025 (the “Extinguished Convertible Notes”). Net proceeds from the Extinguished Convertible Notes were approximately $488.7 million after deducting fees and expenses. The Extinguished Convertible Notes had quarterly interest payments due on February 1, May 1, August 1, and November 1 of each year and on the maturity date. DFC of approximately $11.5 million were capitalized. Partial Redemption On March 27, 2023, the holder of the Extinguished Convertible Notes delivered to the Company notice to redeem $166.7 million of the initial principal amount of the Extinguished Convertible Notes at par, plus accrued interest (the “Redemption Amount”). On March 28, 2023, the Company irrevocably deposited the Redemption Amount of approximately $169.1 million in order to satisfy the redemption and retirement of $166.7 million principal amount of the Extinguished Convertible Notes, plus accrued interest. As a result of paying the Redemption Amount prior to the Extinguished Convertible Notes’ contractual maturity, the Company wrote off approximately $2.8 million of prorated unamortized DFC, which was recognized within Loss on extinguishment of debt, net, in its Consolidated Statements of Operations. Extinguishment On August 15, 2023, we issued and sold in a private placement $250.0 million aggregate principal amount of 10% Senior Secured Notes due October 1, 2025 (the “Senior Notes”) and approximately $83.3 million aggregate principal amount of 6% Secured Convertible Notes (the “Convertible Notes”) due October 1, 2025 (collectively the “Replacement Notes”). The issuance of the Replacement Notes to the holder of the Extinguished Convertible Notes resulted in the satisfaction and discharge of the Company’s outstanding principal repayment obligation under the Extinguished Convertible Notes. As a result, the Company recorded a Loss on extinguishment of debt of approximately $29.5 million in its Consolidated Statements of Operations. Amendments to the Replacement Notes Indentures On January 2, 2024, we amended the indentures governing the Replacement Notes. See Note 19, Subsequent Events , for further information. Senior Secured Notes due 2025 The Senior Notes have quarterly interest payments in cash due on the first day of January, April, July, and October of each year, commencing in October 2023. DFC of approximately $20.1 million were capitalized and are being amortized over the term of the Senior Notes using the effective interest rate method. Holders of the Senior Notes may force the Company to redeem the applicable Senior Notes for cash upon (i) a fundamental change or (ii) an event of default. On or after October 1, 2024, the holders of the Senior Notes may redeem up to the entire principal amount of the Senior Notes for a cash purchase price equal to the principal amount of the Senior Notes being redeemed, plus accrued and unpaid interest, if the Company’s liquidity falls below (a) $200.0 million, if the Convertible Notes are not outstanding at such time, or (b) $250.0 million, if any of the Convertible Notes are outstanding at such time. The Company may provide written notice to each holder of the Senior Notes calling all of such holder’s Senior Notes for redemption for a cash purchase price equal to 100% of the principal amount being redeemed, plus accrued and unpaid interest (the “Optional Redemption”). Our borrowing obligations under the Senior Notes are collateralized by a first priority lien on the Company’s equity interests in Tellurian Production Holdings LLC (“Tellurian Production Holdings”), a wholly owned subsidiary of Tellurian Inc. Tellurian Production Holdings owns all of the Company’s upstream natural gas assets described in Note 4, Property, Plant and Equipment . The Senior Notes contain financial and non-financial covenants, including a minimum cash balance of $50.0 million. As of December 31, 2023, we remained in compliance with all covenants under the Senior Notes. As of December 31, 2023, the estimated fair value of the Senior Notes was approximately $215.3 million. The Level 3 fair value was estimated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and inputs that are not observable in the market. Senior Secured Convertible Notes due 2025 The Convertible Notes have quarterly interest payments in cash due on the first day of January, April, July, and October of each year, commencing in October 2023. DFC of approximately $12.3 million were capitalized and are being amortized over the term of the Senior Convertible Notes using the effective interest rate method. The holders of the Convertible Notes have the right to convert the notes into shares of our common stock at an initial conversion rate of 512.8205 shares per $1,000 principal amount of notes (equivalent to a conversion price of approximately $1.95 per share of common stock) (the “Conversion Price”), subject to adjustment in certain circumstances, at any time until the second trading day immediately prior to the maturity date (the “Conversion Feature”). The Company will force the holders of the Convertible Notes to convert all of the notes if the trading price of our common stock closes above 300% of the Conversion Price for 20 consecutive trading days and certain other equity conditions are satisfied. Holders of the Convertible Notes may force the Company to redeem the applicable Notes for cash upon (i) a fundamental change or (ii) an event of default. On or after October 1, 2024, the holders of the Convertible Notes may redeem up to the entire principal amount of the notes for a cash purchase price equal to the principal amount of the notes being redeemed, plus accrued and unpaid interest, if the Company’s liquidity falls below (a) $75.0 million, if the Senior Notes are not outstanding at such time, or (b) $250.0 million, if any of the Senior Notes are outstanding at such time. The shares subject to conversion are excluded from the computation of diluted loss per share because including it in the computation would have been antidilutive for the periods presented. Our borrowing obligations under the Convertible Notes are collateralized by a first priority lien on the Company’s equity interests in Tellurian Production Holdings and mortgages of the material real property oil and gas assets of Tellurian Production Holdings LLC and its subsidiaries (together, the “Collateral”). Tellurian Production Holdings owns all of the Company’s upstream natural gas assets described in Note 4, Property, Plant and Equipment . The Collateral will be removed as a secured obligation under the Convertible Notes if the Senior Notes are no longer outstanding. The Convertible Notes contain financial and non-financial covenants, including a minimum cash balance of $50.0 million. As of December 31, 2023, we remained in compliance with all covenants under the Convertible Notes. As of December 31, 2023, the estimated fair value of the Convertible Notes was approximately $70.1 million. The Level 3 fair value was estimated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and inputs that are not observable in the market. Replacement Notes Embedded Derivatives As part of the issuance of the Replacement Notes, the Company agreed to issue an aggregate total of 25.7 million shares of its common stock (the “Share Coupon”) to the holders of the Replacement Notes. The Share Coupon is payable quarterly on the first day of January, April, July, and October of each year, commencing on or before October 2023. To the extent that the average daily volume-weighted average price of the common stock of the Company during each quarter is less than $1.35, the Company will pay a cash amount equal to that difference multiplied by the number of shares issuable for that quarter (the “Cash Shortfall Payments”). Upon any retirement, redemption, or conversion of the Replacement Notes, the Company will issue any and all unpaid Share Coupon plus Cash Shortfall Payments, as applicable (the “Make Whole”). The Company evaluated the potential embedded features within the Replacement Notes host contracts and determined that the Convertible Feature, Share Coupon, the Cash Shortfall Payments and the Make Whole embedded features required bifurcation as a single unit of account from the Replacement Notes and accounted for them separately at fair value. See Note 9, Financial Instruments, for more information on the fair value measurement of the Replacement Notes embedded derivatives. Senior Unsecured Notes due 2028 On November 10, 2021, we sold in a registered public offering $50.0 million aggregate principal amount of 8.25% Senior Unsecured Notes due November 30, 2028 (the “Senior Unsecured Notes”). Net proceeds from the Senior Unsecured Notes were approximately $47.5 million after deducting fees. The underwriter was granted an option to purchase up to an additional $7.5 million of the Senior Unsecured Notes within 30 days. On December 7, 2021, the underwriter exercised the option and purchased an additional $6.5 million of the Senior Unsecured Notes resulting in net proceeds of approximately $6.2 million after deducting fees. The Senior Unsecured Notes have quarterly interest payments due on January 31, April 30, July 31, and October 31 of each year and on the maturity date. As of December 31, 2023, the Company was in compliance with all covenants under the indenture governing the Senior Unsecured Notes. The Senior Unsecured Notes are listed and trade on the NYSE American under the symbol “TELZ,” and are classified as Level 1 within the fair value hierarchy. As of December 31, 2023, the closing market price was $12.25 per Senior Unsecured Note. At-the-Market Debt Offering Program On December 17, 2021, we entered into an at-the-market debt offering program under which the Company may offer and sell, from time to time on the NYSE American, up to an aggregate principal amount of $200.0 million of additional Senior Unsecured Notes. During the year ended December 31, 2022, we sold approximately $1.2 million aggregate principal amount of additional Senior Unsecured Notes for total proceeds of approximately $1.1 million after fees and commissions under our at-the-market debt offering program. On December 30, 2022, the Company terminated the at-the-market debt offering program. 2020 Senior Unsecured Note On April 29, 2020, we issued a zero coupon $56.0 million senior unsecured note (the “2020 Unsecured Note”) to an unrelated third party. The 2020 Unsecured Note was repaid in installments with the final contractually required payment made on March 31, 2021. 2019 Term Loan On May 23, 2019, Driftwood Holdings LP (“Driftwood Holdings”), a wholly owned subsidiary of the Company, entered into a senior secured term loan agreement (the “2019 Term Loan”) to borrow an aggregate principal amount of $60.0 million. On July 16, 2019, the principal amount was increased by an additional $15.0 million. Upon maturity or early repayment of the 2019 Term Loan, Driftwood Holdings was obligated to pay to the lender a fee equal to 20% of the principal amount borrowed less financing costs and cash interest paid (the “Final Payment Fee”). We issued to the lender a warrant to purchase approximately 1.5 million shares of our common stock at $10.00 per share (the “Original Warrant”). On March 3, 2020, the Original Warrant was replaced with a new warrant (the “Replacement Warrant”) which provided the lender with the right to purchase 9.0 million shares of our common stock at $1.00 per share. On March 12, 2021 (the “Extinguishment Date”), we finalized a voluntary repayment of the remaining outstanding principal balance of the 2019 Term Loan. The extinguishment of the 2019 Term Loan resulted in an approximately $2.1 million gain, which was recognized within Gain on extinguishment of debt, net, on our Consolidated Statements of Operations for the year ended December 31, 2021. As a result of repaying the outstanding balance prior to its contractual maturity, an approximately $4.4 million in unamortized debt issuance costs and discount were written off and included in the computation of the gain from the extinguishment of the 2019 Term Loan for the year ended December 31, 2021. The holder of the 2019 Term Loan held approximately 3.5 million unvested warrants that had a fair value of approximately $6.3 million as of the Extinguishment Date. Due to the extinguishment of the 2019 Term Loan, all the unvested warrants were contractually terminated, and their respective fair value was included in the computation of the gain on extinguishment of the 2019 Term Loan. 2018 Term Loan On September 28, 2018, Tellurian Production Holdings LLC, a wholly owned subsidiary of Tellurian Inc., entered into a three-year senior secured term loan credit agreement (the “2018 Term Loan”) in an aggregate principal amount of $60.0 million. On April 23, 2021, we voluntarily repaid the remaining outstanding principal balance of the 2018 Term Loan. As a result of the voluntary repayment, we recognized an approximately $0.7 million loss, which was recognized within Gain on extinguishment of debt, net, on our Consolidated Statements of Operations for the year ended December 31, 2021.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
FINANCIAL INSTRUMENTS	NOTE 9 — FINANCIAL INSTRUMENTS Natural Gas Financial Instruments The primary purpose of our commodity risk management activities is to hedge our exposure to cash flow variability from commodity price risk due to fluctuations in commodity prices. The Company may use natural gas financial futures and option contracts to economically hedge the commodity price risks associated with a portion of our expected natural gas production. As of December 31, 2023, there were no open natural gas financial instrument positions. LNG Financial Futures During the year ended December 31, 2021, we entered into LNG financial futures contracts to reduce our exposure to commodity price fluctuations and to achieve more predictable cash flows relative to two LNG cargos that we were committed to purchase from and sell to unrelated third-party LNG merchants in the normal course of business in January and April 2022. As of December 31, 2023, there were no open LNG financial instrument positions. Contingent Consideration On August 18, 2022, the Company completed the acquisition of certain natural gas assets in the Haynesville Shale basin (the “Asset Acquisition”). The Asset Acquisition included cash consideration payable to the sellers of $7.5 million (the “Contingent Consideration”) if the average NYMEX Henry Hub gas price for the contract delivery months beginning with August 2022 through March 2023 exceeded a specific threshold (the “Threshold”) per MMBtu. The Threshold was not met and, therefore, the Company is not obligated to pay the Contingent Consideration. Embedded Derivatives We evaluate embedded features within a host contract to determine whether they are embedded derivatives that should be bifurcated and carried separately at fair value. Embedded derivatives that are not clearly and closely related to the host contract are bifurcated and recorded at fair value with subsequent changes in fair value recorded in Other income (expense), net in the Company’s Consolidated Statement of Operations. As described in Note 8, Borrowings , we determined that the Replacement Notes contained embedded features which required bifurcation from the host contracts. The following table presents the classification of the Company’s financial instruments that are required to be measured at fair value on a recurring basis on the Company’s Consolidated Balance Sheets (in thousands): Year ended December 31, 2023 Year ended December 31, 2022 Current Assets: Natural Gas Financial Instruments $ — $ 10,463 LNG Financial Futures — — Current liabilities: Contingent Consideration — 118 Embedded derivatives 13,332 — Long-term liabilities Embedded derivatives 18,892 — The following table summarizes the effect of the Company’s financial instruments which are included within Other expense, net on the Consolidated Statements of Operations (in thousands): Year ended December 31, 2023 Year ended December 31, 2022 Natural gas financial instruments: Realized gain (loss) $ 23,310 $ (27,179) Unrealized (loss) gain (10,463) 10,463 LNG financial futures contracts: Realized gain — 3,532 Unrealized loss — 5,161 Contingent Consideration: Realized gain 118 — Unrealized gain — 3,770 Embedded derivative Realized gain 1,554 — Unrealized gain 17,041 — The following table summarizes changes in the Company’s Embedded Derivatives (in thousands): Year ended December 31, 2023 Balance at January 1, 2023 $ — Issued 56,005 Settled (5,186) Total gains or losses (realized and unrealized) included in earnings (18,594) Balance at December 31, 2023 $ 32,225 The Company’s natural gas financial instruments are valued using quoted prices in active exchange markets as of the balance sheet date and are classified as a Level 1 fair value measurement. The fair value of the Company’s embedded derivatives as of December 31, 2023 was estimated using a Black-Scholes valuation model which is considered to be a Level 3 fair value measurement.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 10 — COMMITMENTS AND CONTINGENCIES Trade Finance Credit Line On July 19, 2021, we entered into an uncommitted trade finance credit line for up to $30.0 million that is intended to finance the purchase of LNG cargos for ultimate resale in the normal course of business. On December 7, 2021, the uncommitted trade finance credit line was amended and increased to $150.0 million. As of December 31, 2023, no amounts were drawn under this credit line. Minimum Volume Commitments The Company is subject to gas gathering commitments with unrelated companies which provide dedicated gathering capacity for a portion of the Upstream segment’s Haynesville Shale future natural gas production. The gas gathering agreements may require us to make deficiency payments to the extent the Company does not meet the minimum volume commitments per the terms of each contract. The estimated minimum volume deficiency liability as of December 31, 2023 is approximately $5.0 million.

STOCKHOLDERS_ EQUITY

STOCKHOLDERS’ EQUITY	12 Months Ended
	Dec. 31, 2023
Equity [Abstract]
STOCKHOLDERS’ EQUITY	NOTE 11 — STOCKHOLDERS’ EQUITY At-the-Market Equity Offering Programs We maintain at-the-market equity offering programs pursuant to which we sell shares of our common stock from time to time on the NYSE American. For the year ended December 31, 2022, we issued 67.7 million shares of our common stock under our at-the-market equity offering programs for net proceeds of approximately $299.7 million. On December 30, 2022, we terminated the Company’s then-existing at-the-market equity offering programs. On December 30, 2022, we entered into a new at-the-market equity offering program pursuant to which the Company may sell shares of its common stock from time to time on the NYSE American for aggregate sales proceeds of up to $500.0 million. For the year ended December 31, 2023, we issued 135.8 million shares of our common stock under our at-the-market equity offering program for net proceeds of approximately $112.1 million. See Note 19, Subsequent Events , for further information. Common Stock Issuances On August 6, 2021, we sold 35.0 million shares of our common stock in an underwritten public offering at a price of $3.00 per share. Net proceeds from this offering, after deducting fees and expenses, were approximately $100.8 million. The underwriters were granted an option to purchase up to an additional 5.3 million shares of common stock within 30 days. On August 31, 2021, the underwriters exercised this option, which generated net proceeds, after deducting fees, of approximately $15.1 million. Common Stock Purchase Warrants 2020 Unsecured Note In conjunction with the issuance of the 2020 Unsecured Note, we issued a warrant providing the lender with the right to purchase up to 20.0 million shares of our common stock at $1.542 per share (the “2020 Warrant”). The 2020 Warrant, which vested immediately, will expire in October 2025. The 2020 Warrant was valued using a Black-Scholes option pricing model that resulted in a relative fair value of approximately $16.1 million on the issuance date and is not subject to subsequent remeasurement. The 2020 Warrant has been classified as equity and is recognized within Additional paid-in capital on our Consolidated Balance Sheets. The 2020 Warrant has been excluded from the computation of diluted loss per share because including it in the computation would have been antidilutive for the periods presented. 2019 Term Loan During the first quarter of 2021, the lender of the 2019 Term Loan exercised warrants to purchase approximately 6.0 million shares of our common stock for total proceeds of approximately $8.2 million. As discussed in Note 10, Borrowings , the 2019 Term Loan has been repaid in full and the lender no longer holds any warrants. Preferred Stock In March 2018, we entered into a preferred stock purchase agreement with BDC Oil and Gas Holdings, LLC (“Bechtel Holdings”), a Delaware limited liability company and an affiliate of Bechtel Energy Inc., pursuant to which we sold to Bechtel Holdings approximately 6.1 million shares of our Series C convertible preferred stock (the “Preferred Stock”). The holders of the Preferred Stock do not have dividend rights but do have a liquidation preference over holders of our common stock. The holders of the Preferred Stock may convert all or any portion of their shares into shares of our common stock on a one-for-one basis. At any time after “Substantial Completion” of “Project 1,” each as defined in and pursuant to the LSTK EPC Agreement for the Driftwood LNG Phase 1 Liquefaction Facility, dated as of November 10, 2017, or at any time after March 21, 2028, we have the right to cause all of the Preferred Stock to be converted into shares of our common stock on a one-for-one basis. The Preferred Stock has been excluded from the computation of diluted loss per share because including it in the computation would have been antidilutive for the periods presented.

2020 SEVERANCE AND REORGANIZATI

2020 SEVERANCE AND REORGANIZATION	12 Months Ended
	Dec. 31, 2023
Restructuring and Related Activities [Abstract]
2020 SEVERANCE AND REORGANIZATION	NOTE 12 — 2020 SEVERANCE AND REORGANIZATION Employee Retention Plan During the first quarter of 2020, we implemented a cost reduction and reorganization plan due to the sharp decline in oil and natural gas prices as well as the negative economic effects of the COVID-19 pandemic. We satisfied all amounts owed to former employees. In July 2020, the Company’s Board of Directors approved an employee retention incentive plan (the “Employee Retention Plan”) aggregating $12.0 million. The Employee Retention Plan was designed to vest in four equal installments upon the attainment of a ten-day average closing price of the Company’s common stock above $2.25, $3.25, $4.25 and $5.25 (the “Stock Performance Targets”). During the year ended December 31, 2021, three of the four installments vested and we recognized approximately $7.9 million in retention charges within General and administrative expenses and Development expenses in our Consolidated Statements of Operations, of which $3.6 million was paid during 2022. The plan expired on March 31, 2022, and the fourth installment did not vest, as the final Stock Performance Target was not attained.

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2023
Share-Based Payment Arrangement [Abstract]
SHARE-BASED COMPENSATION	NOTE 13 — SHARE-BASED COMPENSATION We have granted restricted stock and restricted stock units (collectively, “Restricted Stock”), as well as unrestricted stock and stock options, to employees, directors and outside consultants under the Tellurian Inc. 2016 Omnibus Incentive Compensation Plan, as amended (the “2016 Plan”), and the Amended and Restated Tellurian Investments Inc. 2016 Omnibus Incentive Plan (the “Legacy Plan”). The maximum number of shares of Tellurian common stock authorized for issuance under the 2016 Plan is 40 million shares of common stock, and no further awards can be made under the Legacy Plan. For the years ended December 31, 2023, 2022 and 2021, Tellurian recognized approximately $1.5 million, $3.6 million and $6.0 million, respectively, of share-based compensation expense related to all share-based awards. As of December 31, 2023, unrecognized compensation expense, based on the grant date fair value, for all share-based awards totaled approximately $172.2 million. Restricted Stock As of December 31, 2023, we had approximately 26.2 million shares of primarily performance-based Restricted Stock outstanding, of which approximately 14.9 million shares will vest entirely based upon an affirmative FID by the Company’s Board of Directors, as defined in the award agreements, and approximately 10.8 million shares will vest in one-third increments at FID and the first and second anniversaries of FID. The remaining shares of primarily performance-based Restricted Stock, totaling approximately 0.5 million shares, will vest based on other criteria. As of December 31, 2023, no expense had been recognized in connection with performance-based Restricted Stock. The approximately 26.2 million shares of primarily performance-based and time-based Restricted Stock have been excluded from the computation of diluted loss per share because including them in the computation would have been antidilutive for the periods presented. Summary of our Restricted Stock transactions for the year ended December 31, 2023 (shares and units in thousands): Shares Weighted-Average Grant Unvested at January 1, 2023 27,426 $ 6.52 Granted (1) 1,993 1.19 Vested (352) 2.57 Forfeited (2,868) 2.91 Unvested at December 31, 2023 26,199 6.57 (1) The weighted-average per share grant date fair values of Restricted Stock granted during the years ended December 31, 2022 and 2021 were $4.46 and $2.90, respectively. The total grant date fair value of restricted stock vested during the years ended December 31, 2023, 2022 and 2021 was approximately $0.9 million, $1.7 million and $7.4 million, respectively. Stock Options Participants in the 2016 Plan have been granted non-qualified options to purchase shares of common stock. Stock options are granted at a price not less than the market price of the common stock on the date of grant. Summary of our stock option transactions for the year ended December 31, 2023 (stock options in thousands): Stock Options Weighted Average Outstanding at January 1, 2023 10,970 $ 5.01 Granted — — Exercised — — Forfeited or expired (138) 10.32 Outstanding at December 31, 2023 10,832 4.95 Exercisable at December 31, 2023 10,832 $ 4.95 The stock options that were granted to a former member of the Company’s executive management team during the year ended December 31, 2020 vest and become exercisable upon the achievement of both triggers as follows (stock options in thousands): Service Trigger (1) Stock Price Trigger (2) Amount December 15, 2021 (3) $3.50 3,333 December 15, 2022 (4) $4.50 3,333 December 15, 2023 (5) $5.50 3,334 10,000 (1) Satisfied through continued employment or other service to the Company through the designated date. (2) Satisfied upon the Company’s common stock price closing at a price per share at or equal to the designated closing price for any ten consecutive trading days. (3) Vested during the year ended December 31, 2021. (4) Vested during the year ended December 31, 2022. (5) Vested during the year ended December 31, 2023. The stock options granted during the year ended December 31, 2020, were set to expire on the fifth anniversary of the date of its grant but will now expire in March 2024. The fair value of each stock option awarded in 2020 was estimated using a Monte Carlo simulation and, due to the service trigger, is being recognized as compensation expense ratably over the vesting term. Valuation assumptions used to value stock options granted during the year ended December 31, 2020 were as follows: Expected volatility 113.6 % Expected dividend yields — % Risk-free rate 0.4 % Due to our limited history, the expected volatility is based on a blend of our historical annualized volatility and the implied volatility utilizing options quoted or traded. The expected dividend yield is based on historical yields on the date of grant. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of the grant.

INCENTIVE COMPENSATION PROGRAM

INCENTIVE COMPENSATION PROGRAM	12 Months Ended
	Dec. 31, 2023
Compensation Related Costs [Abstract]
INCENTIVE COMPENSATION PROGRAM	NOTE 14 — INCENTIVE COMPENSATION PROGRAM On November 18, 2021, the Company’s Board of Directors approved the adoption of the Tellurian Incentive Compensation Program (the “Incentive Compensation Program” or “ICP”). The ICP allows the Company to award short-term and long-term performance and service-based incentive compensation to full-time employees of the Company. ICP awards may be earned with respect to each calendar year and are determined based on guidelines established by the Compensation Committee of the Board of Directors, as administrator of the ICP. Short-term incentive awards Short-term incentive (“STI”) awards are payable annually in cash at the discretion of the Company’s Board of Directors. Compensation expense for STI awards is recognized over the performance period when it is probable that the performance condition will be achieved. For the year ended December 31, 2023 we recognized no compensation expense related to STI awards, as compared to approximately $15.7 million for the year ended December 31, 2022. Long-term incentive awards Long-term incentive (“LTI”) awards under the ICP were granted in January 2022 in the form of “tracking units,” at the discretion of the Company’s Board of Directors (the “2021 LTI Award”). Each such tracking unit has a value equal to one share of Tellurian common stock and entitles the grantee to receive, upon vesting, a cash payment equal to the closing price of our common stock on the trading day prior to the vesting date. These tracking units will vest in three equal tranches at grant date, and the first and second anniversaries of the grant date. Non-vested 2021 LTI Awards as of December 31, 2023 during the period were as follows: Number of Tracking Units (in thousands) Price per Tracking Unit Balance at January 1, 2023 12,719 $ 1.68 Granted — $ — Vested (6,359) 2.13 Forfeited (368) 1.50 Unvested balance at December 31, 2023 5,992 $ 0.76 LTI awards under the ICP were granted in February 2023 in the form of “tracking units,” at the discretion of the Compensation Committee of the Company’s Board of Directors (the “2022 LTI Awards”). Each such tracking unit has a value equal to one share of Tellurian common stock and entitles the grantee to receive, upon vesting, a cash payment equal to the closing price of our common stock on the trading day prior to the vesting date. These tracking units will vest in three equal tranches at the grant date and the first and second anniversaries of the grant date. Non-vested 2022 LTI Awards as of December 31, 2023 and awards granted during the period were as follows: Number of Tracking Units (in thousands) Price per Tracking Unit Balance at January 1, 2023 — — Granted 14,802 $ 2.10 Vested (4,934) 1.63 Forfeited (606) 1.46 Unvested balance at December 31, 2023 9,262 $ 0.76 We recognize compensation expense for awards with graded vesting schedules over the requisite service periods for each separately vesting portion of the award as if each award was in substance multiple awards. Compensation expense for the first tranche of the 2021 LTI Awards and the 2022 LTI Awards that vested at the grant date was primarily recognized over the performance period when it was probable that the performance condition was achieved. Compensation expense for the second and third tranches of the 2021 LTI Awards and the 2022 LTI Awards is recognized on a straight-line basis over the requisite service vesting period. Compensation expense for unvested tracking units is subsequently adjusted each reporting period to reflect the estimated payout levels based on changes in the Company’s stock price and actual forfeitures. Compensation expense (income) related to the second and third tranches of the 2021 LTI Awards and the 2022 LTI Awards are as follows (in thousands): Year Ended December 31, 2023 2022 2022 LTI Awards $ 5,280 $ — 2021 LTI Awards (788) 15,681

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
INCOME TAXES	NOTE 15 — INCOME TAXES Income tax benefit (provision) included in our reported net loss consisted of the following (in thousands): Year Ended December 31, 2023 2022 2021 Current: Federal $ — $ — $ — State — — — Foreign — — — Total Current — — — Deferred: Federal — — — State — — — Foreign — — — Total Deferred — — — Total income tax benefit (provision) $ — $ — $ — The sources of loss from operations before income taxes were as follows (in thousands): Year Ended December 31, 2023 2022 2021 Domestic $ (166,694) $ (36,591) $ (111,114) Foreign 517 (13,219) (3,624) Total loss before income taxes $ (166,177) $ (49,810) $ (114,738) The reconciliation of the federal statutory income tax rate to our effective income tax rate is as follows: Year Ended December 31, 2023 2022 2021 Income tax benefit (provision) at U.S. statutory rate $ 34,897 $ 10,460 $ 24,095 Share-based compensation (126) (126) 1,352 Executive compensation (3,919) (3,688) (203) Change in U.S. state tax rate — (1,313) — Change in foreign tax rate — 1,816 — Disallowed interest (4,683) — — U.S. state tax 5,494 792 4,333 Change in valuation allowance (29,877) (8,871) (29,648) R&D Credit — 748 524 Foreign rate differential (38) 516 (74) Other (1,748) (334) (379) Total income tax benefit (provision) $ — $ — $ — Significant components of our deferred tax assets and liabilities are as follows (in thousands): December 31, 2023 2022 Deferred tax assets: Capitalized costs $ 92,758 $ 85,875 Compensation and benefits 2,299 8,860 Lease liability 34,391 16,086 Disallowed interest expense carryforward 3,974 3,510 Net operating loss carryforwards and credits: Federal 124,320 99,922 State 21,036 16,142 Foreign 10,760 11,023 Other, net 14,689 7,080 Deferred tax assets 304,227 248,498 Less valuation allowance (241,034) (211,157) Deferred tax assets, net of valuation allowance 63,193 37,341 Deferred tax liabilities Property and equipment (63,193) (37,341) Net deferred tax assets $ — $ — As of December 31, 2023, we had federal, state and international net operating loss (“NOL”) carryforwards of approximately $572.0 million, $361.1 million and $44.7 million, respectively. Approximately $670.6 million of these NOLs have an indefinite carryforward period. All other NOLs will expire between 2036 and 2040. Due to our historical losses and other available evidence related to our ability to generate taxable income, we have established a valuation allowance to fully offset our federal, state and international deferred tax assets as of December 31, 2023 and 2022. We will continue to evaluate the realizability of our deferred tax assets in the future. The increase in the valuation allowance was approximately $29.9 million for the year ended December 31, 2023. In addition, we experienced a Section 382 ownership change in April 2017. An analysis of the annual limitation on the utilization of our NOLs was performed in accordance with IRC Section 382. It was determined that IRC Section 382 will not materially limit the use of our NOLs over the carryover period. We will continue to monitor trading activity in our shares which could cause an additional ownership change. If the Company experiences a Section 382 ownership change, it could further affect our ability to utilize our existing NOL carryforwards. As of December 31, 2023, the Company determined that it has no uncertain tax positions, interest or penalties as defined within ASC 740-10. The Company does not have unrecognized tax benefits. The Company does not believe that it is reasonably possible that the total unrecognized benefits will significantly increase within the next 12 months. We are subject to tax in the U.S. and various state and foreign jurisdictions. Federal and state tax returns filed with each jurisdiction remain open to examination under the normal three-year statute of limitations. Pursuant to ASC 740-30-25-17, the Company recognizes deferred tax liabilities associated with outside basis differences on investments in foreign subsidiaries unless the difference is considered essentially permanent in duration. As of December 31, 2023, the Company has not recorded any deferred taxes on unremitted earnings as the Company has no undistributed earnings and profits. If circumstances change in the foreseeable future and it becomes apparent that some or all of the undistributed earnings and profits will not be reinvested indefinitely, or will be remitted in the foreseeable future, a deferred tax liability will be recorded for some or all of the outside basis difference.

LEASES

LEASES	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
LEASES	NOTE 16 — LEASES Our Driftwood Project land leases are classified as finance leases and include one or more options to extend the lease term for up to 40 years, as well as to terminate the lease within five years, at our sole discretion. We are reasonably certain that those options will be exercised and that our termination rights will not be exercised, and we have, therefore, included those assumptions within our right of use assets and corresponding lease liabilities. Our other land leases are classified as finance leases and include one or more options to extend the lease term for up to 69 years or to terminate the lease within seven years, at our sole discretion. We are reasonably certain that those options and termination rights will not be exercised, and we have, therefore, excluded those assumptions within our right of use assets and corresponding lease liabilities. Our office space leases are classified as operating leases and include one or more options to extend the lease term up to 10 years, at our sole discretion. As we are not reasonably certain that those options will be exercised, none are recognized as part of our right of use assets and lease liabilities. As none of our leases provide an implicit rate, we have determined our own discount rate. The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in thousands): December 31, Leases Consolidated Balance Sheets Classification 2023 2022 Right of use asset Operating Other Non-Current Assets $ 12,814 $ 13,303 Finance Property, plant and equipment, net 126,225 56,708 Total Leased Assets $ 139,039 $ 70,011 Liabilities Current Operating Accrued and other liabilities $ 3,835 $ 2,734 Finance Accrued and other liabilities 875 140 Non-Current Operating Other non-current liabilities 10,743 12,148 Finance Finance lease liabilities 121,450 49,963 Total leased liabilities $ 136,903 $ 64,985 Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): Year Ended December 31, Lease costs 2023 2022 2021 Operating lease cost $ 3,915 $ 3,149 $ 2,519 Finance lease cost Amortization of lease assets 3,461 1,174 788 Interest on lease liabilities 9,202 3,978 2,904 Finance lease cost $ 12,663 $ 5,152 $ 3,692 Total lease cost $ 16,578 $ 8,301 $ 6,211 Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: December 31, Lease term and discount rate 2023 2022 Weighted average remaining lease term (years) Operating lease 3.5 4.5 Finance lease 36.1 48.4 Weighted average discount rate Operating lease 6.4 % 6.2 % Finance lease 8.7 % 9.4 % The following shows other quantitative information for our operating and finance leases (in thousands): Year Ended December 31, . 2023 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 4,333 $ 3,423 $ 2,953 Operating cash flows from finance leases $ 7,950 $ 3,674 $ 1,813 Financing cash flows from finance leases $ 512 $ 132 $ 1,926 The table below presents an analysis of the maturity of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2022 (in thousands): Operating Finance 2024 $ 4,666 $ 10,491 2025 4,721 10,491 2026 4,756 10,491 2027 1,954 10,491 2028 275 10,491 After 2028 — 322,334 Total lease payments $ 16,372 $ 374,789 Less: discount 1,794 252,465 Present value of lease liability $ 14,578 $ 122,324
LEASES	NOTE 16 — LEASES Our Driftwood Project land leases are classified as finance leases and include one or more options to extend the lease term for up to 40 years, as well as to terminate the lease within five years, at our sole discretion. We are reasonably certain that those options will be exercised and that our termination rights will not be exercised, and we have, therefore, included those assumptions within our right of use assets and corresponding lease liabilities. Our other land leases are classified as finance leases and include one or more options to extend the lease term for up to 69 years or to terminate the lease within seven years, at our sole discretion. We are reasonably certain that those options and termination rights will not be exercised, and we have, therefore, excluded those assumptions within our right of use assets and corresponding lease liabilities. Our office space leases are classified as operating leases and include one or more options to extend the lease term up to 10 years, at our sole discretion. As we are not reasonably certain that those options will be exercised, none are recognized as part of our right of use assets and lease liabilities. As none of our leases provide an implicit rate, we have determined our own discount rate. The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in thousands): December 31, Leases Consolidated Balance Sheets Classification 2023 2022 Right of use asset Operating Other Non-Current Assets $ 12,814 $ 13,303 Finance Property, plant and equipment, net 126,225 56,708 Total Leased Assets $ 139,039 $ 70,011 Liabilities Current Operating Accrued and other liabilities $ 3,835 $ 2,734 Finance Accrued and other liabilities 875 140 Non-Current Operating Other non-current liabilities 10,743 12,148 Finance Finance lease liabilities 121,450 49,963 Total leased liabilities $ 136,903 $ 64,985 Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): Year Ended December 31, Lease costs 2023 2022 2021 Operating lease cost $ 3,915 $ 3,149 $ 2,519 Finance lease cost Amortization of lease assets 3,461 1,174 788 Interest on lease liabilities 9,202 3,978 2,904 Finance lease cost $ 12,663 $ 5,152 $ 3,692 Total lease cost $ 16,578 $ 8,301 $ 6,211 Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: December 31, Lease term and discount rate 2023 2022 Weighted average remaining lease term (years) Operating lease 3.5 4.5 Finance lease 36.1 48.4 Weighted average discount rate Operating lease 6.4 % 6.2 % Finance lease 8.7 % 9.4 % The following shows other quantitative information for our operating and finance leases (in thousands): Year Ended December 31, . 2023 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 4,333 $ 3,423 $ 2,953 Operating cash flows from finance leases $ 7,950 $ 3,674 $ 1,813 Financing cash flows from finance leases $ 512 $ 132 $ 1,926 The table below presents an analysis of the maturity of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2022 (in thousands): Operating Finance 2024 $ 4,666 $ 10,491 2025 4,721 10,491 2026 4,756 10,491 2027 1,954 10,491 2028 275 10,491 After 2028 — 322,334 Total lease payments $ 16,372 $ 374,789 Less: discount 1,794 252,465 Present value of lease liability $ 14,578 $ 122,324

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION	12 Months Ended
	Dec. 31, 2023
Supplemental Cash Flow Information [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	NOTE 17 — SUPPLEMENTAL CASH FLOW INFORMATION The following table provides information regarding the net changes in working capital (in thousands): Year Ended December 31, 2023 2022 2021 Accounts receivable $ 50,941 $ (67,462) $ (4,770) Prepaid expenses and other current assets (9,250) 5,801 (2,536) Accounts payable (17,950) 1,953 (5,514) Accounts payable due to related parties — — (910) Accrued liabilities 1 (2,851) 44,548 55,884 Other, net — (793) (1,137) Net changes in working capital $ 20,890 $ (15,953) $ 41,017 1 Excludes changes in the Company’s derivative assets and liabilities. The following table provides supplemental disclosure of cash flow information (in thousands): Year Ended December 31, 2023 2022 2021 Non-cash accruals of property, plant and equipment and other non-current assets $ 48,096 $ 13,323 $ 56,305 Non-cash settlement of Embedded derivative $ 4,899 — — Non-cash settlement of withholding taxes associated with the 2019 bonus paid and vesting of certain awards — — 3,064 Non-cash settlement of the 2019 bonus paid — — 5,430 Asset retirement obligation additions and revisions — 1,533 76 The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the Consolidated Balance Sheets that sum to the total of such amounts shown in the Consolidated Statements of Cash Flows (in thousands): Year Ended December 31, 2023 2022 2021 Cash and cash equivalents $ 75,789 $ 474,205 $ 305,496 Current restricted cash 4,688 9,375 — Non-current restricted cash 24,900 24,888 1,778 Total cash, cash equivalents and restricted cash in the statement of cash flows $ 105,377 $ 508,468 $ 307,274

DISCLOSURE ABOUT SEGMENTS AND R

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION	12 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION	NOTE 18 — DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION The Upstream segment is organized and operates to produce, gather and deliver natural gas and to acquire and develop natural gas assets. The Midstream segment is organized to develop, construct and operate LNG terminals and pipelines. The Marketing & Trading segment is organized and operates to purchase and sell natural gas produced primarily by the Upstream segment, market the Driftwood terminal’s LNG production capacity and trade LNG. These operating segments represent the Company’s reportable segments. The remainder of our business is presented as “Corporate,” and consists of corporate costs and intersegment eliminations. The Company’s Chief Operating Decision Maker does not currently assess segment performance or allocate resources based on a measure of total assets. Accordingly, a total asset measure has not been provided for segment disclosure. Year ended December 31, 2023 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 18,047 $ — $ 148,081 $ — $ 166,128 Intersegment revenues (purchases) (2) (3) 148,081 (7,969) (135,781) (4,331) — Segment operating income (loss) (4) (55,501) (55,289) (7,306) (30,566) (148,662) Interest expense, net 1,506 (1,007) 6 (18,552) (18,047) Loss on extinguishment of debt, net — — — (32,295) (32,295) Other income (loss), net 1,193 — 12,783 18,850 32,827 Consolidated loss before tax $ (166,177) Year ended December 31, 2022 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 15,993 $ — $ 375,933 $ — $ 391,926 Intersegment revenues (purchases) (2) (3) 254,984 (1,760) (241,229) (11,995) — Segment operating income (loss) (4) 130,663 (80,626) (31,192) (36,618) (17,773) Interest expense, net — (1,751) (454) (11,655) (13,860) Gain on extinguishment of debt, net — — — — — Other income (loss), net 3,770 — (22,912) 964 (18,177) Consolidated loss before tax $ (49,810) Year ended December 31, 2021 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 2,317 $ — $ 68,958 $ — $ 71,275 Intersegment revenues (purchases) (2) (3) 49,182 — (44,755) (4,427) — Segment operating loss (4) (5,651) (42,040) (22,889) (42,153) (112,733) Interest expense, net (1,642) (4,722) — (3,014) (9,378) Gain on extinguishment of debt, net (665) 2,087 — — 1,422 Other (loss) income , net (1,284) (2,494) 9,460 269 5,951 Consolidated loss before tax $ (114,738) (1) The Marketing & Trading segment markets to third party-purchasers most of the Company's natural gas production from the Upstream segment. (2) The Marketing & Trading segment purchases most of the Company’s natural gas production from the Upstream segment. Intersegment revenues are eliminated at consolidation. (3) Intersegment revenues related to the Marketing & Trading segment are a result of cost allocations to the Corporate component using a cost plus transfer pricing methodology. Intersegment revenues related to the Corporate component are associated with intercompany interest charged to the Midstream segment. Intersegment revenues are eliminated at consolidation. (4) Operating profit (loss) is defined as operating revenues less operating costs and allocated corporate costs. Year Ended December 31, Capital expenditures 2023 2022 2021 Upstream $ 112,992 $ 347,240 $ 32,364 Midstream 200,127 199,283 25,501 Marketing & Trading 490 675 — Total capital expenditures for reportable segments 313,609 547,198 57,865 Corporate capital expenditures 3,896 5,690 — Consolidated capital expenditures $ 317,505 $ 552,888 $ 57,865

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2023
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	NOTE 19 — SUBSEQUENT EVENTS Amendments to Replacement Notes Indentures January Amendments On January 2, 2024, we amended the supplemental indentures governing the Replacement Notes and issued approximately 47.8 million shares of common stock to the holder of the Replacement Notes to repay approximately $37.9 million of the outstanding principal amount of the notes plus accrued interest of approximately $7.5 million (the “January Transaction”). As part of the January Transaction, the minimum cash balance of $50.0 million was reduced to $40.0 million for the limited period set forth in such indentures and the Company’s liquidity threshold of $250.0 million was reduced to $212.1 million. February Amendments On February 22, 2024, we closed an additional transaction (the “February Transaction”) with the holder of the Replacement Notes. The quarterly cash interest payment due, and any stock shortfall payment owed, on April 1, 2024 in respect of the Replacement Notes will be added to the aggregate principal amounts of the applicable notes and we issued all shares due to the holder with respect to the Share Coupon, subject to certain lockup provisions and anti-shorting restrictions. The Company is required to use its reasonable best efforts to sell its upstream natural gas exploration and production assets and to use the proceeds from such sale to repay amounts due under the Senior Notes. The Company’s minimum cash balance was reduced as set forth in the supplemental indentures. The Convertible Notes conversion price is now approximately $1.05 per share, with the number of shares of common stock of the Company issuable upon conversion limited to approximately 42.7 million. The remaining principal amount of the Convertible Notes will remain outstanding as a non-convertible instrument. The Convertible Notes, including the non-convertible component of those notes are required to be paid monthly over a period of 10 months beginning on January 1, 2025. The right of the holder of the Convertible Notes to cause the Company to redeem those notes on or after October 1, 2024 as a result of a failure to satisfy a liquidity threshold has been eliminated. Tellurian Investments LLC, a wholly owned subsidiary of the Company, provided a non-recourse pledge of all of its equity interests in the principal properties of the Company comprising the Driftwood Project and a certain intercompany note to secure the obligations under the indentures governing the Replacement Notes. Upon repayment in full of the Senior Notes, substantially all collateral securing the Convertible Notes will be released. At-the-Market Equity Offering Program Subsequent to December 31, 2023, and through the date of this filing, we issued approximately 29.6 million shares of our common stock under our at-the-market equity offering program for net proceeds of approximately $17.8 million. As of the date of this filing, we have availability to raise aggregate gross sales proceeds of approximately $366.1 million under this at-the-market equity offering program. Announcement to explore the sale of upstream natural gas assets As part of Management’s Plans to alleviate substantial doubt, on February 6, 2024, we announced our intention to explore the sale of the Company’s upstream natural gas assets. The carrying value of our upstream natural gas assets are disclosed in Note 4, Property, Plant and Equipment

SUPPLEMENTAL DISCLOSURES ABOUT

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES	12 Months Ended
	Dec. 31, 2023
Extractive Industries [Abstract]
SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES	SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES In accordance with FASB and SEC disclosure requirements for natural gas producing activities, this section provides supplemental information on Tellurian’s natural gas producing activities in six separate tables. Tables I through III provide historical cost information pertaining to costs incurred in exploration, property acquisitions and development; capitalized costs; and results of operations. Tables IV through VI present information on the Company’s estimated net proved reserve quantities, standardized measure of estimated discounted future net cash flows related to proved reserves and changes in estimated discounted future net cash flows. Table I — Capitalized Costs Related to Natural Gas Producing Activities Capitalized costs related to Tellurian’s natural gas producing activities are summarized as follows (in thousands): December 31, 2023 2022 2021 Proved properties $ 561,303 $ 468,351 $ 113,950 Unproved properties — — — Gross capitalized costs 561,303 468,351 113,950 Accumulated DD&A (187,171) (92,423) (48,637) Net capitalized costs $ 374,132 $ 375,928 $ 65,313 Table II — Costs Incurred in Property Acquisitions,Exploration and Development Costs incurred in natural gas property acquisition (inclusive of producing well costs), exploration and development activities are summarized as follows (in thousands): Year Ended December 31, 2023 2022 2021 Property acquisitions: Proved $ — $ 135,974 $ 3,409 Unproved — — — Exploration costs — — — Development costs 116,045 210,546 28,955 Costs incurred $ 116,045 $ 346,520 $ 32,364 Table III — Results of Operations for Natural Gas Producing Activities The following table includes revenues and expenses directly associated with our natural gas and condensate producing activities. It does not include any interest costs or indirect general and administrative costs and, therefore, is not necessarily indicative of the contribution to consolidated net operating results of our natural gas operations. Tellurian’s results of operations from natural gas and condensate producing activities for the periods presented are as follows (in thousands): Year Ended December 31, 2023 2022 2021 Natural gas sales $ 166,128 $ 270,977 $ 51,499 Operating costs 88,276 53,963 20,576 Depreciation, depletion and amortization 95,202 43,966 10,998 Total operating costs and expenses 183,478 97,929 31,574 Results of operations $ (17,350) $ 173,048 $ 19,925 Table IV — Natural Gas Reserve Quantity Information Our estimated proved reserves are located in Louisiana. We caution that there are many uncertainties inherent in estimating proved reserve quantities and in projecting future production rates and the timing of development expenditures. Accordingly, these estimates are expected to change as further information becomes available. Material revisions of reserve estimates may occur in the future, development and production of the natural gas and condensate reserves may not occur in the periods assumed, and actual prices realized and actual costs incurred may vary significantly from those used in these estimates. The estimates of our proved reserves as of December 31, 2023, 2022 and 2021 have been prepared by Netherland, Sewell & Associates, Inc., independent petroleum consultants. Gas Gas Equivalent Proved reserves: December 31, 2020 99,508 99,508 Extensions, discoveries and other additions 202,897 202,897 Revisions of previous estimates 35,237 35,237 Production (14,306) (14,306) Sale of reserves-in-place — — Purchases of reserves-in-place — — December 31, 2021 323,336 323,336 Extensions, discoveries and other additions 113,047 113,047 Revisions of previous estimates (52,185) (52,185) Production (47,322) (47,322) Sale of reserves-in-place — — Purchases of reserves-in-place 108,017 108,017 December 31, 2022 444,893 444,893 Extensions, discoveries and other additions 983 983 Revisions of previous estimates (179,737) (179,737) Production (72,476) (72,476) Sale of reserves-in-place (15,627) (15,627) Purchases of reserves-in-place — — December 31, 2023 178,036 178,036 Proved developed reserves: December 31, 2021 73,927 73,927 December 31, 2022 218,382 218,382 December 31, 2023 178,036 178,036 Proved undeveloped reserves: December 31, 2021 249,409 249,409 December 31, 2022 226,511 226,511 December 31, 2023 — — 2022 to 2023 Overall Reserve Changes • The Company added 1 Bcfe of proved developed reserves from drilling activities. • The Company had total negative revisions of approximately 180 Bcfe, comprised primarily of a 170 Bcfe negative revision from removing proved undeveloped locations due to uncertainty regarding the Company's future commitment to capital, a 12 Bcfe negative revision from decreases in commodity prices, a 26 Bcfe negative revision from well performance and a 27 Bcfe positive revision from changes in ownership. • The Company divested 16 Bcfe of proved undeveloped reserves. 2022 to 2023 PUD Changes • The Company had total negative revisions of approximately 170 Bcfe from removing proved undeveloped locations due to uncertainty regarding the Company's future commitment to capital • The Company divested 16 Bcfe of proved undeveloped reserves. • The Company converted approximately 41 Bcfe from proved undeveloped to proved developed reserves. 2021 to 2022 Overall Reserve Changes • The Company added 113 Bcfe of proved reserves comprised of 89 Bcfe from additional proved undeveloped locations and 24 Bcfe of proved developed reserves from drilling activities. • The Company had total negative revisions of approximately 52 Bcfe, comprised primarily of a 38 Bcfe negative revision from removing proved undeveloped locations that now fall outside of the SEC mandated five-year development window, a 25 Bcfe negative revision from changes in lateral lengths and ownership, a 3 Bcfe negative revision from increased operational costs, partially offset by an 8 Bcfe positive revision from improved well performance, and a 6 Bcfe positive revision due to an increase in commodity prices. The removal of the proved undeveloped locations that fell outside of the five-year development window resulted from a re-prioritization of activity due to (i) our asset acquisition and (ii) unanticipated third party development activity that caused an existing well to be shut in and unable to return to production and thereby required us to alter our drilling schedule to preserve the affected leases. • During the year ending December 31, 2022, we acquired approximately 108 Bcfe primarily related to the acquisition of natural gas assets. 2021 to 2022 PUD Changes • The Company added approximately 89 Bcfe from additional proved undeveloped locations. • The Company had total negative revisions of approximately 44 Bcfe, comprised of a 38 Bcfe negative revision from removing proved undeveloped locations that now fall outside of the SEC mandated five-year development window, a 13 Bcfe negative revision from changes in lateral lengths and ownership, partially offset by a 5 Bcfe positive revision from improved well performance, and a 2 Bcfe positive revision due to an increase in commodity prices. • During the year ending December 31, 2022, we acquired approximately 71 Bcfe of proved undeveloped reserves primarily related to the acquisition of natural gas assets. • The Company converted approximately 138 Bcfe from proved undeveloped reserves to proved developed reserves. 2020 to 2021 Overall Reserve Changes • Added 203 Bcfe of proved reserves comprised of 152 Bcfe from additional proved undeveloped locations and 51 Bcfe of proved developed reserves from drilling activities. • Had total positive revisions of approximately 35 Bcfe, comprised primarily of a 9 Bcfe positive revision due to an increase in commodity prices, a 15 Bcfe positive revision from changes in ownership and an 11 Bcfe positive revision from improved well performance. 2020 to 2021 PUD Changes • Added approximately 152 Bcfe from additional proved undeveloped locations. • Had total positive revisions of approximately 25 Bcfe, comprised of a 3 Bcfe positive revision due to an increase in commodity prices, a 16 Bcfe positive revision from changes in ownership and a 6 Bcfe positive revision from improved well performance. Table V — Standardized Measure of Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves ASC 932 prescribes guidelines for computing a standardized measure of future net cash flows and changes therein relating to estimated proved reserves. Tellurian has followed these guidelines, which are briefly discussed below. Future cash inflows and future production and development costs as of December 31, 2023, 2022 and 2021 were determined by applying the average of the first-day-of-the-month prices for the 12 months of the year and year-end costs to the estimated quantities of natural gas and condensate to be produced. Actual future prices and costs may be materially higher or lower than the prices and costs used. For each year, estimates are made of quantities of proved reserves and the future periods during which they are expected to be produced based on the continuation of the economic conditions applied for that year. Estimated future income taxes are computed using current statutory income tax rates, including consideration of the current tax basis of the properties and related carryforwards, giving effect to permanent differences and tax credits. The resulting future net cash flows are reduced to present value amounts by applying a 10% annual discount factor. The assumptions used to compute the standardized measure are those prescribed by the FASB and do not necessarily reflect our expectations of actual revenue to be derived from those reserves or their present worth. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these estimates reflect the valuation process. The following summary sets forth our future net cash flows relating to proved natural gas and condensate reserves based on the standardized measure (in thousands): Year Ended December 31, 2023 2022 2021 Future cash inflows $ 326,246 $ 2,441,930 $ 945,651 Future production costs (102,356) (341,925) (133,909) Future development costs (56,207) (360,107) (211,836) Future income tax provisions — (257,908) (54,401) Future net cash flows 167,683 1,481,990 545,505 Less effect of a 10% discount factor (42,254) (445,686) (181,302) Standardized measure of discounted future net cash flows $ 125,429 $ 1,036,304 $ 364,203 Table VI — Changes in Standardized Measure of Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves The following sets forth the changes in the standardized measure of discounted future net cash flows (in thousands): December 31, 2020 $ 6,885 Sales and transfers of gas and condensate produced, net of production costs (39,806) Net changes in prices and production costs 110,850 Extensions, discoveries, additions and improved recovery, net of related costs 255,246 Development costs incurred — Revisions of estimated development costs 10,643 Revisions of previous quantity estimates 35,012 Accretion of discount 688 Net change in income taxes (27,455) Purchases of reserves in place — Sales of reserves in place — Changes in timing and other 12,140 December 31, 2021 $ 364,203 Sales and transfers of gas and condensate produced, net of production costs (236,374) Net changes in prices and production costs 503,099 Extensions, discoveries, additions and improved recovery, net of related costs 255,970 Development costs incurred 154,931 Revisions of estimated development costs (105,352) Revisions of previous quantity estimates (143,398) Accretion of discount 36,420 Net change in income taxes (127,154) Purchases of reserves in place 262,050 Sales of reserves in place — Changes in timing and other 71,909 December 31, 2022 $ 1,036,304 Sales and transfers of gas and condensate produced, net of production costs (101,438) Net changes in prices and production costs (660,129) Extensions, discoveries, additions and improved recovery, net of related costs 1,227 Development costs incurred 75,788 Revisions of estimated development costs (88,121) Revisions of previous quantity estimates (331,376) Accretion of discount 63,350 Net change in income taxes 154,609 Purchases of reserves in place — Sales of reserves in place (30,124) Changes in timing and other 5,339 December 31, 2023 $ 125,429

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Pay vs Performance Disclosure
Net loss	$ (166,177)	$ (49,810)	$ (114,738)

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Our Consolidated Financial Statements have been prepared in accordance with GAAP. The Consolidated Financial Statements include the accounts of Tellurian Inc. and its wholly owned subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. Certain reclassifications have been made to conform prior period information to the current presentation. The reclassifications did not have a material effect on our consolidated financial position, results of operations or cash flows.
Segments	Segments
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. Management evaluates its estimates and related assumptions on a regular basis. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
Fair Value	Fair Value Fair value is 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. The Company uses three levels of the fair value hierarchy of inputs to measure the fair value of an asset or a liability. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Level 3 inputs are inputs that are not observable in the market.
Revenue Recognition	Revenue Recognition For the sale of natural gas, we consider the delivery of each unit (MMBtu) to be a separate performance obligation that is satisfied upon delivery to the designated sales point and therefore is recognized at a point in time. These contracts are either fixed price contracts or contracts with a fixed differential to an index price, both of which are deemed fixed consideration that is allocated to each performance obligation and represents the relative standalone selling price basis. Each LNG cargo, in its entirety, is deemed to be a single performance obligation due to each molecule of LNG being distinct and substantially the same and therefore meeting the criteria for the transfer of a series of distinct goods. Accordingly, LNG sales are recognized at a point in time when the LNG has completed discharging to the customer. These are contracts with a fixed differential to an index price, which is deemed fixed consideration that is allocated to each performance obligation and represents the relative standalone selling price basis. These LNG sales are recorded on a gross basis and reported in “LNG sales” on the Consolidated Statements of Operations. Purchases and sales of LNG inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “LNG sales” on the Consolidated Statements of Operations. For such LNG sales, we require payment within 10 days from delivery. We exclude all taxes from the measurement of the transaction price.
Receivables	Receivables
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted Cash We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. Cash and cash equivalents that are restricted as to withdrawal or use under the terms of certain contractual agreements are recorded as restricted cash on our Consolidated Balance Sheets. The carrying value of cash, cash equivalents and restricted cash approximates their fair value.
Concentration of Cash	Concentration of Cash We maintain cash balances and restricted cash at financial institutions, which may, at times, be in excess of federally insured levels. We have not incurred losses related to these balances to date.
Derivative Instruments	Derivative Instruments We may use derivative instruments to hedge our exposure to cash flow variability from commodity price risk. Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities, depending on the derivative position and the expected timing of settlement, unless they satisfy the criteria for and we elect the normal purchases and sales exception.
Property, Plant and Equipment	Property, Plant and Equipment Natural gas development and production activities are accounted for using the successful efforts method of accounting. Costs incurred to acquire a property (whether proved or unproved) are capitalized when incurred. Costs to develop proved reserves are capitalized and our natural gas reserves are depleted using the units-of-production method. Fixed assets are recorded at cost. We depreciate our property, plant and equipment, excluding land, using the straight-line depreciation method over the estimated useful life of the asset. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed, and the resulting gains or losses are recorded in our Consolidated Statements of Operations. Management tests property, plant and equipment for impairment whenever there are indicators that the carrying amount of property, plant and equipment might not be recoverable. The carrying values of our proved natural gas properties are reviewed for impairment when events or circumstances indicate that the remaining carrying value may not be recoverable. If there is an indication that the carrying amount of our proved natural gas properties may not be recoverable, we compare the estimated probability-weighted undiscounted future cash flows from our natural gas properties to the carrying values of those properties. Proved properties that have carrying amounts in excess of estimated undiscounted cash flows are written down to fair value.
Leases	Leases The Company determines if an arrangement is a lease at inception. Leases are recognized as either finance or operating leases on our Consolidated Balance Sheets by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. We combine lease and non-lease components of an arrangement for all classes of our leased assets and omit short-term leases with a term of 12 months or less from recognition on the balance sheet. In the absence of a readily determinable implicit interest rate, we discount our expected future lease payments using our incremental borrowing rate. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability, only to the extent they are reasonably certain to be exercised. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Lease expense for finance leases is recognized as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities over the lease term.
Accounting for LNG Development Activities	Accounting for LNG Development Activities During the preliminary stage of developing the Driftwood terminal, substantially all the costs related to such activities have been expensed. These costs primarily included professional fees associated with FEED studies and complying with FERC for authorization to construct our terminal and other required permitting for the Driftwood Project. Costs incurred in connection with a project to develop the Driftwood terminal shall generally be treated as development expenses until the project has reached the notice-to-proceed state (“NTP State”) and the following criteria (the “NTP Criteria”) have been met: (i) the necessary regulatory permits have been obtained, (ii) financing for the project has been secured and (iii) management has committed to commence construction. In addition, certain costs incurred prior to achieving the NTP State will be capitalized although the NTP Criteria have not been met. Costs to be capitalized prior to achieving the NTP State include land purchase costs, land improvement costs, costs associated with preparing the facility for use, direct payroll and payroll benefit-related costs and any fixed structure construction costs (fence, storage areas, drainage, etc.). Furthermore, activities directly associated with detailed engineering and/or facility designs shall be capitalized. Interest is capitalized in connection with the construction of major facilities. All amounts capitalized are periodically assessed for impairment and may be impaired if indicators are present. Prior to reaching the NTP State, costs incurred to complete construction activities necessary to proceed under our LSTK EPC agreement with Bechtel are capitalized as construction in progress when the following criteria are met: (i) costs incurred are directly identifiable, (ii) necessary regulatory permits are secured, (iii) funding for the scope of work is available, and (iv) construction activities are creditable under the LSTK EPC agreement. Prior to reaching the NTP State, costs incurred to complete construction activities necessary to develop the Driftwood pipelines are capitalized as construction in progress when the following criteria are met: (i) costs incurred are directly identifiable, (ii) necessary regulatory permits are secured, and (iii) funding for the scope of work is available.
Debt	Debt Discounts, premiums, fees and expenses incurred with the issuance of debt are amortized over the term of the debt. These amounts are presented net of our indebtedness balances on the accompanying Consolidated Balance Sheets. We evaluate embedded features within a debt host contract to determine whether there are embedded derivatives that should be bifurcated and carried separately at fair value. Embedded derivatives that are not clearly and closely related to the host contract are bifurcated and recorded at fair value with subsequent changes in fair value recorded in the Consolidated Statements of Operations.
Share-Based Compensation	Share-Based Compensation
Income Taxes	Income Taxes We account for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, we determine deferred tax assets and liabilities on the basis of the differences between the financial statement and tax basis of assets and liabilities by using enacted tax rates in effect for the year in which the differences are expected to be realized or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. We recognize deferred tax assets to the extent that we believe that these assets are more likely than not to be realized. In making such a determination, we consider current and historical financial results, expectations for future taxable income and the availability of tax planning strategies that can be implemented, if necessary, to realize deferred tax assets. If we determine that we would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we will make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes.
Post employment benefits	Post employment benefits The Company provides cash and other termination benefits pursuant to ongoing benefit arrangements to its employees in connection with a qualifying termination of their employment. The cost of providing post employment benefits is recognized when the obligation is probable of occurring and can be reasonably estimated.
Net Loss Per Share	Net Loss Per Share Basic net loss per share excludes dilution and is computed by dividing net loss by the weighted average number of common shares outstanding during the period. Diluted net loss per share reflects potential dilution and is computed by dividing net loss by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued and were dilutive.

PREPAID EXPENSES AND OTHER CU_2

PREPAID EXPENSES AND OTHER CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Prepaid Expenses and Other Current Assets	Prepaid expenses and other current assets consist of the following (in thousands): December 31, 2023 2022 Prepaid expenses $ 1,788 $ 2,174 Restricted cash 4,688 9,375 Derivative asset, net - current (Note 9) — 10,463 Upstream pipe 4,278 978 Deposits and other current assets 5,197 365 Total prepaid expenses and other current assets $ 15,951 $ 23,355

PROPERTY, PLANT AND EQUIPMENT (

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2023
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	Property, plant and equipment consist of the following (in thousands): December 31, 2023 2022 Upstream natural gas assets: Proved properties $ 492,506 $ 412,977 Wells in progress 68,797 55,374 Accumulated DD&A (187,171) (92,423) Total upstream natural gas assets, net 374,132 375,928 Driftwood Project assets: Terminal construction in progress 533,316 292,734 Pipeline construction in progress 35,939 — Land and land improvements 53,664 52,460 Finance lease assets, net of accumulated DD&A 55,534 56,708 Buildings and other assets, net of accumulated DD&A 310 340 Total Driftwood Project assets, net 678,763 402,242 Fixed assets and other: Finance lease assets, net of accumulated DD&A 70,691 — Leasehold improvements and other assets, net of accumulated DD&A 12,713 10,906 Total fixed assets and other, net 83,404 10,906 Total property, plant and equipment, net $ 1,136,299 $ 789,076

OTHER NON-CURRENT ASSETS (Table

OTHER NON-CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2023
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Non-Current Assets	Other non-current assets consist of the following (in thousands): December 31, 2023 2022 Restricted cash 24,900 24,888 Note receivable 24,189 6,595 Right of use asset — operating leases 12,814 13,303 Investment in unconsolidated entity 6,089 6,089 Pipeline materials and rights of way — 9,136 Permitting costs — 916 Land lease and purchase options $ — $ 300 Other 2,207 2,089 Total other non-current assets $ 70,199 $ 63,316

ACCRUED AND OTHER LIABILITIES (

ACCRUED AND OTHER LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2023
Payables and Accruals [Abstract]
Schedule of Components of Accrued and Other Liabilities	Accrued and other liabilities consist of the following (in thousands): December 31, 2023 2022 Upstream accrued liabilities 47,652 $ 71,977 Payroll and compensation 15,423 37,329 Accrued taxes 1,476 730 Driftwood Project development activities 24,455 4,423 Lease liabilities 4,710 2,875 Accrued interest 8,293 5,793 Embedded derivative (Note 9) 13,332 — Other 8,309 6,053 Total accrued and other liabilities $ 123,650 $ 129,180

BORROWINGS (Tables)

BORROWINGS (Tables)	12 Months Ended
	Dec. 31, 2023
Debt Disclosure [Abstract]
Schedule of Borrowings	The Company’s borrowings consist of the following (in thousands): December 31, 2023 Principal repayment obligation Unamortized Discount (DFC) Carrying value Senior Secured Convertible Notes due 2025 $ 83,334 $ (10,415) $ 72,919 Senior Secured Notes due 2025 250,000 (16,954) 233,046 Senior Unsecured Notes due 2028 57,678 (2,241) 55,437 Total borrowings $ 391,012 $ (29,610) $ 361,402 December 31, 2022 Principal repayment obligation Unamortized DFC Carrying value Convertible Notes, current $ 166,666 $ (3,110) $ 163,556 Convertible Notes, non-current 333,334 (6,219) 327,115 Senior Unsecured Notes due 2028 57,678 (2,585) 55,093 Total borrowings $ 557,678 $ (11,914) $ 545,764

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the classification of the Company’s financial instruments that are required to be measured at fair value on a recurring basis on the Company’s Consolidated Balance Sheets (in thousands): Year ended December 31, 2023 Year ended December 31, 2022 Current Assets: Natural Gas Financial Instruments $ — $ 10,463 LNG Financial Futures — — Current liabilities: Contingent Consideration — 118 Embedded derivatives 13,332 — Long-term liabilities Embedded derivatives 18,892 —
Summary of Derivative Instruments, Gain (Loss)	The following table summarizes the effect of the Company’s financial instruments which are included within Other expense, net on the Consolidated Statements of Operations (in thousands): Year ended December 31, 2023 Year ended December 31, 2022 Natural gas financial instruments: Realized gain (loss) $ 23,310 $ (27,179) Unrealized (loss) gain (10,463) 10,463 LNG financial futures contracts: Realized gain — 3,532 Unrealized loss — 5,161 Contingent Consideration: Realized gain 118 — Unrealized gain — 3,770 Embedded derivative Realized gain 1,554 — Unrealized gain 17,041 —
Schedule of Derivative Instruments	The following table summarizes changes in the Company’s Embedded Derivatives (in thousands): Year ended December 31, 2023 Balance at January 1, 2023 $ — Issued 56,005 Settled (5,186) Total gains or losses (realized and unrealized) included in earnings (18,594) Balance at December 31, 2023 $ 32,225

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2023
Share-Based Payment Arrangement [Abstract]
Summary of Restricted Stock Transactions	Summary of our Restricted Stock transactions for the year ended December 31, 2023 (shares and units in thousands): Shares Weighted-Average Grant Unvested at January 1, 2023 27,426 $ 6.52 Granted (1) 1,993 1.19 Vested (352) 2.57 Forfeited (2,868) 2.91 Unvested at December 31, 2023 26,199 6.57 (1) The weighted-average per share grant date fair values of Restricted Stock granted during the years ended December 31, 2022 and 2021 were $4.46 and $2.90, respectively.
Summary of Stock Option Transactions	Summary of our stock option transactions for the year ended December 31, 2023 (stock options in thousands): Stock Options Weighted Average Outstanding at January 1, 2023 10,970 $ 5.01 Granted — — Exercised — — Forfeited or expired (138) 10.32 Outstanding at December 31, 2023 10,832 4.95 Exercisable at December 31, 2023 10,832 $ 4.95
Summary of Share-based Compensation Arrangements by Share-based Payment Award	The stock options that were granted to a former member of the Company’s executive management team during the year ended December 31, 2020 vest and become exercisable upon the achievement of both triggers as follows (stock options in thousands): Service Trigger (1) Stock Price Trigger (2) Amount December 15, 2021 (3) $3.50 3,333 December 15, 2022 (4) $4.50 3,333 December 15, 2023 (5) $5.50 3,334 10,000 (1) Satisfied through continued employment or other service to the Company through the designated date. (2) Satisfied upon the Company’s common stock price closing at a price per share at or equal to the designated closing price for any ten consecutive trading days. (3) Vested during the year ended December 31, 2021. (4) Vested during the year ended December 31, 2022. (5) Vested during the year ended December 31, 2023. Compensation expense (income) related to the second and third tranches of the 2021 LTI Awards and the 2022 LTI Awards are as follows (in thousands): Year Ended December 31, 2023 2022 2022 LTI Awards $ 5,280 $ — 2021 LTI Awards (788) 15,681
Schedule of Stock Option Valuation Assumptions	Valuation assumptions used to value stock options granted during the year ended December 31, 2020 were as follows: Expected volatility 113.6 % Expected dividend yields — % Risk-free rate 0.4 %

INCENTIVE COMPENSATION PROGRAM

INCENTIVE COMPENSATION PROGRAM (Tables)	12 Months Ended
	Dec. 31, 2023
Compensation Related Costs [Abstract]
Schedule of Nonvested Awards	Non-vested 2021 LTI Awards as of December 31, 2023 during the period were as follows: Number of Tracking Units (in thousands) Price per Tracking Unit Balance at January 1, 2023 12,719 $ 1.68 Granted — $ — Vested (6,359) 2.13 Forfeited (368) 1.50 Unvested balance at December 31, 2023 5,992 $ 0.76 Number of Tracking Units (in thousands) Price per Tracking Unit Balance at January 1, 2023 — — Granted 14,802 $ 2.10 Vested (4,934) 1.63 Forfeited (606) 1.46 Unvested balance at December 31, 2023 9,262 $ 0.76
Schedule of Recognized Compensation Expenses Related to the 2021 LTI Award and the 2022 LTI Award	The stock options that were granted to a former member of the Company’s executive management team during the year ended December 31, 2020 vest and become exercisable upon the achievement of both triggers as follows (stock options in thousands): Service Trigger (1) Stock Price Trigger (2) Amount December 15, 2021 (3) $3.50 3,333 December 15, 2022 (4) $4.50 3,333 December 15, 2023 (5) $5.50 3,334 10,000 (1) Satisfied through continued employment or other service to the Company through the designated date. (2) Satisfied upon the Company’s common stock price closing at a price per share at or equal to the designated closing price for any ten consecutive trading days. (3) Vested during the year ended December 31, 2021. (4) Vested during the year ended December 31, 2022. (5) Vested during the year ended December 31, 2023. Compensation expense (income) related to the second and third tranches of the 2021 LTI Awards and the 2022 LTI Awards are as follows (in thousands): Year Ended December 31, 2023 2022 2022 LTI Awards $ 5,280 $ — 2021 LTI Awards (788) 15,681

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Benefit (Provision)	Income tax benefit (provision) included in our reported net loss consisted of the following (in thousands): Year Ended December 31, 2023 2022 2021 Current: Federal $ — $ — $ — State — — — Foreign — — — Total Current — — — Deferred: Federal — — — State — — — Foreign — — — Total Deferred — — — Total income tax benefit (provision) $ — $ — $ —
Schedule of Loss before Income Tax, Domestic and Foreign	The sources of loss from operations before income taxes were as follows (in thousands): Year Ended December 31, 2023 2022 2021 Domestic $ (166,694) $ (36,591) $ (111,114) Foreign 517 (13,219) (3,624) Total loss before income taxes $ (166,177) $ (49,810) $ (114,738)
Summary of Effective Income Tax Rate Reconciliation	The reconciliation of the federal statutory income tax rate to our effective income tax rate is as follows: Year Ended December 31, 2023 2022 2021 Income tax benefit (provision) at U.S. statutory rate $ 34,897 $ 10,460 $ 24,095 Share-based compensation (126) (126) 1,352 Executive compensation (3,919) (3,688) (203) Change in U.S. state tax rate — (1,313) — Change in foreign tax rate — 1,816 — Disallowed interest (4,683) — — U.S. state tax 5,494 792 4,333 Change in valuation allowance (29,877) (8,871) (29,648) R&D Credit — 748 524 Foreign rate differential (38) 516 (74) Other (1,748) (334) (379) Total income tax benefit (provision) $ — $ — $ —
Schedule of Deferred Tax Assets and Liabilities	Significant components of our deferred tax assets and liabilities are as follows (in thousands): December 31, 2023 2022 Deferred tax assets: Capitalized costs $ 92,758 $ 85,875 Compensation and benefits 2,299 8,860 Lease liability 34,391 16,086 Disallowed interest expense carryforward 3,974 3,510 Net operating loss carryforwards and credits: Federal 124,320 99,922 State 21,036 16,142 Foreign 10,760 11,023 Other, net 14,689 7,080 Deferred tax assets 304,227 248,498 Less valuation allowance (241,034) (211,157) Deferred tax assets, net of valuation allowance 63,193 37,341 Deferred tax liabilities Property and equipment (63,193) (37,341) Net deferred tax assets $ — $ —

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Summary of Assets And Liabilities, Lessee	The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in thousands): December 31, Leases Consolidated Balance Sheets Classification 2023 2022 Right of use asset Operating Other Non-Current Assets $ 12,814 $ 13,303 Finance Property, plant and equipment, net 126,225 56,708 Total Leased Assets $ 139,039 $ 70,011 Liabilities Current Operating Accrued and other liabilities $ 3,835 $ 2,734 Finance Accrued and other liabilities 875 140 Non-Current Operating Other non-current liabilities 10,743 12,148 Finance Finance lease liabilities 121,450 49,963 Total leased liabilities $ 136,903 $ 64,985 Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: December 31, Lease term and discount rate 2023 2022 Weighted average remaining lease term (years) Operating lease 3.5 4.5 Finance lease 36.1 48.4 Weighted average discount rate Operating lease 6.4 % 6.2 % Finance lease 8.7 % 9.4 %
Schedule of Lease, Cost	Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): Year Ended December 31, Lease costs 2023 2022 2021 Operating lease cost $ 3,915 $ 3,149 $ 2,519 Finance lease cost Amortization of lease assets 3,461 1,174 788 Interest on lease liabilities 9,202 3,978 2,904 Finance lease cost $ 12,663 $ 5,152 $ 3,692 Total lease cost $ 16,578 $ 8,301 $ 6,211 The following shows other quantitative information for our operating and finance leases (in thousands): Year Ended December 31, . 2023 2022 2021 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 4,333 $ 3,423 $ 2,953 Operating cash flows from finance leases $ 7,950 $ 3,674 $ 1,813 Financing cash flows from finance leases $ 512 $ 132 $ 1,926
Schedule of Finance Lease, Liability, Maturity	The table below presents an analysis of the maturity of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2022 (in thousands): Operating Finance 2024 $ 4,666 $ 10,491 2025 4,721 10,491 2026 4,756 10,491 2027 1,954 10,491 2028 275 10,491 After 2028 — 322,334 Total lease payments $ 16,372 $ 374,789 Less: discount 1,794 252,465 Present value of lease liability $ 14,578 $ 122,324
Schedule of Operating Lease Maturity	The table below presents an analysis of the maturity of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2022 (in thousands): Operating Finance 2024 $ 4,666 $ 10,491 2025 4,721 10,491 2026 4,756 10,491 2027 1,954 10,491 2028 275 10,491 After 2028 — 322,334 Total lease payments $ 16,372 $ 374,789 Less: discount 1,794 252,465 Present value of lease liability $ 14,578 $ 122,324

SUPPLEMENTAL CASH FLOW INFORM_2

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2023
Supplemental Cash Flow Information [Abstract]
Schedule of Net Changes in Components of Operating Assets and Liabilities	The following table provides information regarding the net changes in working capital (in thousands): Year Ended December 31, 2023 2022 2021 Accounts receivable $ 50,941 $ (67,462) $ (4,770) Prepaid expenses and other current assets (9,250) 5,801 (2,536) Accounts payable (17,950) 1,953 (5,514) Accounts payable due to related parties — — (910) Accrued liabilities 1 (2,851) 44,548 55,884 Other, net — (793) (1,137) Net changes in working capital $ 20,890 $ (15,953) $ 41,017
Supplemental Disclosure of Cash Flow Information	The following table provides supplemental disclosure of cash flow information (in thousands): Year Ended December 31, 2023 2022 2021 Non-cash accruals of property, plant and equipment and other non-current assets $ 48,096 $ 13,323 $ 56,305 Non-cash settlement of Embedded derivative $ 4,899 — — Non-cash settlement of withholding taxes associated with the 2019 bonus paid and vesting of certain awards — — 3,064 Non-cash settlement of the 2019 bonus paid — — 5,430 Asset retirement obligation additions and revisions — 1,533 76 The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the Consolidated Balance Sheets that sum to the total of such amounts shown in the Consolidated Statements of Cash Flows (in thousands): Year Ended December 31, 2023 2022 2021 Cash and cash equivalents $ 75,789 $ 474,205 $ 305,496 Current restricted cash 4,688 9,375 — Non-current restricted cash 24,900 24,888 1,778 Total cash, cash equivalents and restricted cash in the statement of cash flows $ 105,377 $ 508,468 $ 307,274

DISCLOSURE ABOUT SEGMENTS AND_2

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2023
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Year ended December 31, 2023 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 18,047 $ — $ 148,081 $ — $ 166,128 Intersegment revenues (purchases) (2) (3) 148,081 (7,969) (135,781) (4,331) — Segment operating income (loss) (4) (55,501) (55,289) (7,306) (30,566) (148,662) Interest expense, net 1,506 (1,007) 6 (18,552) (18,047) Loss on extinguishment of debt, net — — — (32,295) (32,295) Other income (loss), net 1,193 — 12,783 18,850 32,827 Consolidated loss before tax $ (166,177) Year ended December 31, 2022 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 15,993 $ — $ 375,933 $ — $ 391,926 Intersegment revenues (purchases) (2) (3) 254,984 (1,760) (241,229) (11,995) — Segment operating income (loss) (4) 130,663 (80,626) (31,192) (36,618) (17,773) Interest expense, net — (1,751) (454) (11,655) (13,860) Gain on extinguishment of debt, net — — — — — Other income (loss), net 3,770 — (22,912) 964 (18,177) Consolidated loss before tax $ (49,810) Year ended December 31, 2021 Upstream Midstream Marketing & Trading Corporate Consolidated Revenues from external customers (1) $ 2,317 $ — $ 68,958 $ — $ 71,275 Intersegment revenues (purchases) (2) (3) 49,182 — (44,755) (4,427) — Segment operating loss (4) (5,651) (42,040) (22,889) (42,153) (112,733) Interest expense, net (1,642) (4,722) — (3,014) (9,378) Gain on extinguishment of debt, net (665) 2,087 — — 1,422 Other (loss) income , net (1,284) (2,494) 9,460 269 5,951 Consolidated loss before tax $ (114,738) (1) The Marketing & Trading segment markets to third party-purchasers most of the Company's natural gas production from the Upstream segment. (2) The Marketing & Trading segment purchases most of the Company’s natural gas production from the Upstream segment. Intersegment revenues are eliminated at consolidation. (3) Intersegment revenues related to the Marketing & Trading segment are a result of cost allocations to the Corporate component using a cost plus transfer pricing methodology. Intersegment revenues related to the Corporate component are associated with intercompany interest charged to the Midstream segment. Intersegment revenues are eliminated at consolidation. (4) Operating profit (loss) is defined as operating revenues less operating costs and allocated corporate costs. Year Ended December 31, Capital expenditures 2023 2022 2021 Upstream $ 112,992 $ 347,240 $ 32,364 Midstream 200,127 199,283 25,501 Marketing & Trading 490 675 — Total capital expenditures for reportable segments 313,609 547,198 57,865 Corporate capital expenditures 3,896 5,690 — Consolidated capital expenditures $ 317,505 $ 552,888 $ 57,865

SUPPLEMENTAL DISCLOSURES ABOU_2

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES (Tables)	12 Months Ended
	Dec. 31, 2023
Extractive Industries [Abstract]
Summary of Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	Capitalized costs related to Tellurian’s natural gas producing activities are summarized as follows (in thousands): December 31, 2023 2022 2021 Proved properties $ 561,303 $ 468,351 $ 113,950 Unproved properties — — — Gross capitalized costs 561,303 468,351 113,950 Accumulated DD&A (187,171) (92,423) (48,637) Net capitalized costs $ 374,132 $ 375,928 $ 65,313
Summary of Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	Costs incurred in natural gas property acquisition (inclusive of producing well costs), exploration and development activities are summarized as follows (in thousands): Year Ended December 31, 2023 2022 2021 Property acquisitions: Proved $ — $ 135,974 $ 3,409 Unproved — — — Exploration costs — — — Development costs 116,045 210,546 28,955 Costs incurred $ 116,045 $ 346,520 $ 32,364
Summary of Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure	The following table includes revenues and expenses directly associated with our natural gas and condensate producing activities. It does not include any interest costs or indirect general and administrative costs and, therefore, is not necessarily indicative of the contribution to consolidated net operating results of our natural gas operations. Tellurian’s results of operations from natural gas and condensate producing activities for the periods presented are as follows (in thousands): Year Ended December 31, 2023 2022 2021 Natural gas sales $ 166,128 $ 270,977 $ 51,499 Operating costs 88,276 53,963 20,576 Depreciation, depletion and amortization 95,202 43,966 10,998 Total operating costs and expenses 183,478 97,929 31,574 Results of operations $ (17,350) $ 173,048 $ 19,925
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	Gas Gas Equivalent Proved reserves: December 31, 2020 99,508 99,508 Extensions, discoveries and other additions 202,897 202,897 Revisions of previous estimates 35,237 35,237 Production (14,306) (14,306) Sale of reserves-in-place — — Purchases of reserves-in-place — — December 31, 2021 323,336 323,336 Extensions, discoveries and other additions 113,047 113,047 Revisions of previous estimates (52,185) (52,185) Production (47,322) (47,322) Sale of reserves-in-place — — Purchases of reserves-in-place 108,017 108,017 December 31, 2022 444,893 444,893 Extensions, discoveries and other additions 983 983 Revisions of previous estimates (179,737) (179,737) Production (72,476) (72,476) Sale of reserves-in-place (15,627) (15,627) Purchases of reserves-in-place — — December 31, 2023 178,036 178,036 Proved developed reserves: December 31, 2021 73,927 73,927 December 31, 2022 218,382 218,382 December 31, 2023 178,036 178,036 Proved undeveloped reserves: December 31, 2021 249,409 249,409 December 31, 2022 226,511 226,511 December 31, 2023 — —
Summary of Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	The following summary sets forth our future net cash flows relating to proved natural gas and condensate reserves based on the standardized measure (in thousands): Year Ended December 31, 2023 2022 2021 Future cash inflows $ 326,246 $ 2,441,930 $ 945,651 Future production costs (102,356) (341,925) (133,909) Future development costs (56,207) (360,107) (211,836) Future income tax provisions — (257,908) (54,401) Future net cash flows 167,683 1,481,990 545,505 Less effect of a 10% discount factor (42,254) (445,686) (181,302) Standardized measure of discounted future net cash flows $ 125,429 $ 1,036,304 $ 364,203 The following sets forth the changes in the standardized measure of discounted future net cash flows (in thousands): December 31, 2020 $ 6,885 Sales and transfers of gas and condensate produced, net of production costs (39,806) Net changes in prices and production costs 110,850 Extensions, discoveries, additions and improved recovery, net of related costs 255,246 Development costs incurred — Revisions of estimated development costs 10,643 Revisions of previous quantity estimates 35,012 Accretion of discount 688 Net change in income taxes (27,455) Purchases of reserves in place — Sales of reserves in place — Changes in timing and other 12,140 December 31, 2021 $ 364,203 Sales and transfers of gas and condensate produced, net of production costs (236,374) Net changes in prices and production costs 503,099 Extensions, discoveries, additions and improved recovery, net of related costs 255,970 Development costs incurred 154,931 Revisions of estimated development costs (105,352) Revisions of previous quantity estimates (143,398) Accretion of discount 36,420 Net change in income taxes (127,154) Purchases of reserves in place 262,050 Sales of reserves in place — Changes in timing and other 71,909 December 31, 2022 $ 1,036,304 Sales and transfers of gas and condensate produced, net of production costs (101,438) Net changes in prices and production costs (660,129) Extensions, discoveries, additions and improved recovery, net of related costs 1,227 Development costs incurred 75,788 Revisions of estimated development costs (88,121) Revisions of previous quantity estimates (331,376) Accretion of discount 63,350 Net change in income taxes 154,609 Purchases of reserves in place — Sales of reserves in place (30,124) Changes in timing and other 5,339 December 31, 2023 $ 125,429

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) $ in Millions	2 Months Ended		12 Months Ended
	Feb. 21, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2023 USD ($) Segment	Dec. 31, 2022 USD ($)
Subsidiary, Sale of Stock [Line Items]
Revenue from contract with customer, required payment period from delivery			10 days
Number of operating segments | Segment			1
New At-the-Market Equity Offering Program
Subsidiary, Sale of Stock [Line Items]
Proceeds from sale of common stock, net of fees and commissions		$ 40.2	$ 112.1	$ 299.7
New At-the-Market Equity Offering Program | Subsequent Event
Subsidiary, Sale of Stock [Line Items]
Proceeds from sale of common stock, net of fees and commissions	$ 17.8

PREPAID EXPENSES AND OTHER CU_3

PREPAID EXPENSES AND OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid expenses	$ 1,788	$ 2,174
Restricted cash	4,688	9,375	$ 0
Derivative asset, net - current (Note 9)	0	10,463
Upstream pipe	4,278	978
Deposits and other current assets	5,197	365
Total prepaid expenses and other current assets	$ 15,951	$ 23,355

PROPERTY, PLANT AND EQUIPMENT -

PROPERTY, PLANT AND EQUIPMENT - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Finance lease assets, net of accumulated DD&A	$ 126,225	$ 56,708
Total property, plant and equipment, net	1,136,299	789,076
Upstream Natural Gas Assets
Property, Plant and Equipment [Line Items]
Accumulated DD&A	(187,171)	(92,423)
Property, plant and equipment, net	374,132	375,928
Proved properties
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	492,506	412,977
Wells in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	68,797	55,374
Driftwood Project
Property, Plant and Equipment [Line Items]
Finance lease assets, net of accumulated DD&A	55,534	56,708
Total property, plant and equipment, net	678,763	402,242
Terminal construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	533,316	292,734
Pipeline construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	35,939	0
Land and land improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	53,664	52,460
Buildings And Other Assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	310	340
Fixed assets and other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	12,713	10,906
Finance lease assets, net of accumulated DD&A	70,691	0
Total property, plant and equipment, net	$ 83,404	$ 10,906

PROPERTY, PLANT AND EQUIPMENT_2

PROPERTY, PLANT AND EQUIPMENT - Additional Information (Details) $ in Thousands	2 Months Ended	12 Months Ended
	Jun. 30, 2023 USD ($)	Dec. 31, 2023 USD ($) well	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization		$ 98,426	$ 44,357	$ 11,481
Number of operated natural gas wells put in production | well		5
Number of non-operated natural gas wells put in production | well		9
Terminal construction in progress
Property, Plant and Equipment [Line Items]
Amount transferred to construction in progress		$ 240,600
Capitalized interest		22,400
Pipeline construction in progress
Property, Plant and Equipment [Line Items]
Amount transferred to construction in progress	$ 14,600	21,400
Capitalized interest		$ 600

OTHER NON-CURRENT ASSETS (Detai

OTHER NON-CURRENT ASSETS (Details) - USD ($) $ in Thousands, shares in Millions	Dec. 31, 2023	Dec. 31, 2022	Feb. 24, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Restricted cash	$ 24,900	$ 24,888		$ 1,778
Note receivable	24,189	6,595
Right of use asset — operating leases	12,814	13,303
Investment in unconsolidated entity	6,089	6,089
Pipeline materials and rights of way	0	9,136
Permitting costs	0	916
Land lease and purchase options	0	300
Other	2,207	2,089
Total other non-current assets	70,199	$ 63,316
Number of shares purchased in unconsolidated company (in shares)			1.5
Investment in unconsolidated entity, cost			$ 6,100
Notes Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Note receivable	$ 24,200
Note receivable, interest rate	6%

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - USD ($)	11 Months Ended	12 Months Ended		13 Months Ended
	Nov. 30, 2022	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2023
Related Party Transaction [Line Items]
Related party transaction, contract term		1 year
Contractor Service Agreement
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction	$ 50,000			$ 55,000
Contractor Service Fees And Expenses
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction		$ 660,000	$ 625,000
Contractor Service Fees And Expenses | Board of Directors Chairman
Related Party Transaction [Line Items]
Accounts payable		$ 0	$ 0	$ 0

ACCRUED AND OTHER LIABILITIES_2

ACCRUED AND OTHER LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Payables and Accruals [Abstract]
Upstream accrued liabilities	$ 47,652	$ 71,977
Payroll and compensation	15,423	37,329
Accrued taxes	1,476	730
Driftwood Project development activities	24,455	4,423
Lease liabilities	4,710	2,875
Accrued interest	8,293	5,793
Embedded derivative (Note 9)	13,332	0
Other	8,309	6,053
Total accrued and other liabilities	$ 123,650	$ 129,180

BORROWINGS - Schedule of Borrow

BORROWINGS - Schedule of Borrowings (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Principal repayment obligation, non-current	$ 391,012
Unamortized Discount (DFC)	(29,610)	$ (11,914)
Borrowings	361,402	382,208
Borrowings	0	163,556
Principal repayment obligation		557,678
Carrying value		545,764
Convertible Debt
Debt Instrument [Line Items]
Principal repayment obligation, non-current		333,334
Unamortized Discount (DFC)		(6,219)
Borrowings		327,115
Principal repayment obligation, current		166,666
Unamortized DFC		(3,110)
Borrowings		163,556
Senior Secured Convertible Notes due 2025 | Secured Debt
Debt Instrument [Line Items]
Principal repayment obligation, non-current	83,334
Unamortized Discount (DFC)	(10,415)
Borrowings	72,919
Senior Secured Notes due 2025 | Secured Debt
Debt Instrument [Line Items]
Principal repayment obligation, non-current	250,000
Unamortized Discount (DFC)	(16,954)
Borrowings	233,046
Senior Unsecured Notes due 2028 | Unsecured Debt
Debt Instrument [Line Items]
Principal repayment obligation, non-current	57,678	57,678
Unamortized Discount (DFC)	(2,241)	(2,585)
Borrowings	$ 55,437	$ 55,093

BORROWINGS - Amortization (Deta

BORROWINGS - Amortization (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt Disclosure [Abstract]
Amortization of debt issuance costs, discounts and fees	$ 7,111	$ 2,424	$ 3,102

BORROWINGS - Senior Secured Con

BORROWINGS - Senior Secured Convertible Notes due 2025 (Details)					3 Months Ended	12 Months Ended
	Aug. 15, 2023 USD ($) d $ / shares	Mar. 28, 2023 USD ($)	Mar. 27, 2023 USD ($)	Jun. 03, 2022 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Debt Instrument [Line Items]
Loss on extinguishment of debt						$ (32,295,000)	$ 0	$ 1,422,000
6.00% Senior Secured Convertible Notes Due May 1, 2025 | Convertible Notes Payable
Debt Instrument [Line Items]
Principal amount				$ 500,000,000
Debt interest rate (as a percentage)				6%
Proceeds from debt, net of fees				$ 488,700,000
Debt issuance costs				$ 11,500,000
Principal amount redeemed			$ 166,700,000
Redemption amount deposited		$ 169,100,000
Prorated unamortized debt issuance costs written off		$ 2,800,000
Senior Secured Notes due 2025 | Secured Debt
Debt Instrument [Line Items]
Principal amount	$ 250,000,000
Debt interest rate (as a percentage)	10%
Debt issuance costs	$ 20,100,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are not outstanding	200,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are outstanding	$ 250,000,000
Convertible debt, principal amount redeemed (as a percentage)	100%
Debt covenant, minimum cash amount	$ 50,000,000
Notes payable, fair value					$ 215,300,000	215,300,000
6% Secured Convertible Notes Due October 1, 2025 | Convertible Notes Payable
Debt Instrument [Line Items]
Debt issuance costs	12,300,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are not outstanding	75,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are outstanding	250,000,000
Debt covenant, minimum cash amount	$ 50,000,000
Notes payable, fair value					70,100,000	$ 70,100,000
Conversion ratio	0.5128205
Conversion price (in dollars per share) | $ / shares	$ 1.95
Convertible debt, threshold percentage of stock price trigger	300%
Convertible debt, threshold consecutive trading days | d	20
6% Secured Convertible Notes Due October 1, 2025 | Secured Debt
Debt Instrument [Line Items]
Principal amount	$ 83,300,000
Debt interest rate (as a percentage)	6%
Replacement Notes | Secured Debt
Debt Instrument [Line Items]
Loss on extinguishment of debt					$ (29,500,000)

BORROWINGS - Replacement Notes

BORROWINGS - Replacement Notes Embedded Derivatives (Details) - Replacement Notes - Secured Debt shares in Millions	Aug. 15, 2023 $ / shares shares
Debt Instrument [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares	25.7
Average daily volume - weighted average price of common stock (in dollars per share) | $ / shares	$ 1.35

BORROWINGS - Senior Notes due 2

BORROWINGS - Senior Notes due 2028 (Details) - Senior Unsecured Notes due 2028 - Unsecured Debt	Dec. 07, 2021 USD ($)	Nov. 10, 2021 USD ($)	Dec. 31, 2023 $ / seniorNote
Debt Instrument [Line Items]
Principal amount	$ 6,500,000	$ 50,000,000
Debt interest rate (as a percentage)		8.25%
Proceeds from debt, net of fees	$ 6,200,000	$ 47,500,000
Underwriters option to purchase shares (up to)		$ 7,500,000
Underwriters option to purchase shares, period		30 days
Senior notes, closing market price (per senior note) | $ / seniorNote			12.25

BORROWINGS - At-the-Market Debt

BORROWINGS - At-the-Market Debt Offering Program (Details) - At-The-Market Debt Offering Program - Senior Notes - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 17, 2021
Debt Instrument [Line Items]
Principal amount		$ 200,000,000
Debt sold during period, aggregated principal amount	$ 1,200,000
Proceeds from debt, net of fees	$ 1,100,000

BORROWINGS - 2020 Senior Unsecu

BORROWINGS - 2020 Senior Unsecured Note (Details)	Apr. 29, 2020 USD ($)
2020 Term Loan | Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 56,000,000

BORROWINGS - 2019 Term Loan (De

BORROWINGS - 2019 Term Loan (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions		12 Months Ended
	Mar. 12, 2021	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Mar. 03, 2020	Jul. 16, 2019	May 23, 2019
Debt Instrument [Line Items]
Loss on extinguishment of debt		$ 32,295	$ 0	$ (1,422)
2019 Term Loan | Loans Payable
Debt Instrument [Line Items]
Principal amount								$ 60,000
Additional borrowing amount							$ 15,000
Final payment fee (as a percentage)								20%
Number of shares for purchase under warrant (in shares)					6
Loss on extinguishment of debt	$ (2,100)
Prorated unamortized debt issuance costs written off				$ 4,400
Warrants unvested (in shares)		3.5
Fair value of warrant	$ 6,300
2019 Term Loan | Loans Payable | Original Warrant
Debt Instrument [Line Items]
Number of shares for purchase under warrant (in shares)								1.5
Common stock purchase price (in dollars per share)								$ 10
2019 Term Loan | Loans Payable | Replacement Warrant
Debt Instrument [Line Items]
Number of shares for purchase under warrant (in shares)						9
Common stock purchase price (in dollars per share)						$ 1

BORROWINGS - 2018 Term Loan (De

BORROWINGS - 2018 Term Loan (Details) - USD ($)		12 Months Ended
	Sep. 28, 2018	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Loss on extinguishment of debt		$ 32,295,000	$ 0	$ (1,422,000)
2018 Term Loan | Loans Payable
Debt Instrument [Line Items]
Debt term (in years)	3 years
Principal amount	$ 60,000,000
Loss on extinguishment of debt				$ 700,000

FINANCIAL INSTRUMENTS - Narrati

FINANCIAL INSTRUMENTS - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 cargo	Aug. 18, 2022 USD ($)
Derivatives, Fair Value [Line Items]
Purchase commitment, quantity committed | cargo	2
Haynesville Shale
Derivatives, Fair Value [Line Items]
Contingent cash payment for asset acquisition | $		$ 7.5

FINANCIAL INSTRUMENTS - Schedul

FINANCIAL INSTRUMENTS - Schedule of Derivative Instruments in Statement of Financial Position, Fair Value (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative assets, current	$ 0	$ 10,463
Derivative liabilities, current	13,332	0
Natural gas financial instruments:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative assets, current	0	10,463
LNG financial futures contracts:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative assets, current	0	0
Contingent Consideration:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative liabilities, current	0	118
Embedded derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative liabilities, current	13,332	0
Derivative liabilities, noncurrent	$ 18,892	$ 0

FINANCIAL INSTRUMENTS - Sched_2

FINANCIAL INSTRUMENTS - Schedule of Derivative Instruments Effect On Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Natural gas financial instruments:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	$ 23,310	$ (27,179)
Unrealized gain (loss)	(10,463)	10,463
LNG financial futures contracts:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	0	3,532
Unrealized gain (loss)	0	5,161
Contingent Consideration:
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	118	0
Unrealized gain (loss)	0	3,770
Embedded derivatives
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	1,554	0
Unrealized gain (loss)	$ 17,041	$ 0

FINANCIAL INSTRUMENTS - Sched_3

FINANCIAL INSTRUMENTS - Schedule of Changes in Embedded Derivatives (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Changes In Embedded Derivative [Roll Forward]
Balance at January 1, 2023	$ 0
Issued	56,005
Settled	(5,186)
Total gains or losses (realized and unrealized) included in earnings	(18,594)	$ 0	$ 0
Balance at December 31, 2023	$ 32,225	$ 0

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) - USD ($)	Dec. 31, 2023	Dec. 07, 2021	Jul. 19, 2021
Debt Instrument [Line Items]
Minimum volume deficiency liability	$ 5,000,000
Trade Finance Credit Line
Debt Instrument [Line Items]
Line of credit facility, borrowing capacity (up to)		$ 150,000,000	$ 30,000,000
Line of credit outstanding	$ 0

STOCKHOLDERS_ EQUITY (Details)

STOCKHOLDERS’ EQUITY (Details) $ / shares in Units, shares in Millions			1 Months Ended	2 Months Ended	3 Months Ended	12 Months Ended
	Aug. 31, 2021 USD ($)	Aug. 06, 2021 USD ($) $ / shares shares	Mar. 31, 2018 shares	Dec. 31, 2023 USD ($)	Mar. 31, 2021 USD ($) shares	Dec. 31, 2023 USD ($) shares	Dec. 31, 2022 USD ($) shares	Dec. 31, 2021 USD ($)	Dec. 30, 2022 USD ($)	Mar. 12, 2021 USD ($)	Apr. 29, 2020 USD ($) $ / shares shares
Class of Stock [Line Items]
Proceeds from warrant exercise						$ 0	$ 0	$ 8,177,000
Conversion ratio						1
2020 Term Loan | Senior Notes
Class of Stock [Line Items]
Number of shares for purchase under warrant (in shares) | shares											20
Common stock purchase price (in dollars per share) | $ / shares											$ 1.542
Fair value of warrant											$ 16,100,000
2019 Term Loan | Loans Payable
Class of Stock [Line Items]
Number of shares for purchase under warrant (in shares) | shares					6
Fair value of warrant										$ 6,300,000
Proceeds from warrant exercise					$ 8,200,000
Convertible Preferred Stock
Class of Stock [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares			6.1
New At-the-Market Equity Offering Program
Class of Stock [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares						135.8	67.7
Proceeds from sale of common stock, net of fees and commissions				$ 40,200,000		$ 112,100,000	$ 299,700,000
Sale of stock, authorized aggregate sales proceeds amount									$ 500,000,000
Equity Offering In Aug 2021 | Common Stock
Class of Stock [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares		35
Proceeds from sale of common stock, net of fees and commissions		$ 100,800,000
Sale of stock, offering price (in USD per share) | $ / shares		$ 3
Option to purchase additional shares (in shares)		$ 5,300,000
Option to purchase additional shares, period		30 days
Over-allotment option | Common Stock
Class of Stock [Line Items]
Proceeds from sale of common stock, net of fees and commissions	$ 15,100,000

2020 SEVERANCE AND REORGANIZA_2

2020 SEVERANCE AND REORGANIZATION (Details)	1 Months Ended	12 Months Ended
	Jul. 31, 2020 USD ($) installment $ / shares	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($) installment
Restructuring and Related Activities [Abstract]
Employee retention plan pool | $	$ 12,000,000
Employee retention plan, number of vesting installments | installment	4
Employee retention plan, target measurement period	10 days
Employee retention plan, stock performance targets, stock price one (in USD per share)	$ 2.25
Employee retention plan, stock performance targets, stock price two (in USD per share)	3.25
Employee retention plan, stock performance targets, stock price three (in USD per share)	4.25
Employee retention plan, stock performance targets, stock price four (in USD per share)	$ 5.25
Employee retention plan, number of vesting installments, vested | installment			3
Employee retention plan charges | $			$ 7,900,000
Employee retention plan, payment | $		$ 3,600,000

SHARE-BASED COMPENSATION - Addi

SHARE-BASED COMPENSATION - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 1,500,000	$ 3,600,000	$ 6,000,000
Unrecognized compensation expense	$ 172,200,000
Options exercised (in shares)	0	0	0
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities excluded from computation of loss per share amount (in shares)	26,200,000
Performance-Based Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense	$ 0
Number of awards outstanding (in shares)	26,200,000
Performance-Based Restricted Stock | Tranche One
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of awards outstanding (in shares)	14,900,000
Performance-Based Restricted Stock | Tranche Two
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of awards outstanding (in shares)	10,800,000
Award vesting percentage	33.33%
Performance-Based Restricted Stock | Tranche Three
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of awards outstanding (in shares)	500,000
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of awards outstanding (in shares)	26,199,000	27,426,000
Total grant date fair value of restricted stock vested	$ 900,000	$ 1,700,000	$ 7,400,000
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Antidilutive securities excluded from computation of loss per share amount (in shares)	10,800,000
2016 Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of common stock authorized for issuance (in shares)	40,000,000

SHARE-BASED COMPENSATION - Summ

SHARE-BASED COMPENSATION - Summary of Restricted Stock Transactions (Details) - Restricted Stock - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested, beginning balance (in shares)	27,426
Granted (in shares)	1,993
Vested (in shares)	(352)
Forfeited (in shares)	(2,868)
Unvested, ending balance (in shares)	26,199	27,426
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Unvested, beginning balance (in dollars per share)	$ 6.52
Granted (in dollars per share)	1.19	$ 4.46	$ 2.90
Vested (in dollars per share)	2.57
Forfeited (in dollars per share)	2.91
Unvested, ending balance (in dollars per share)	$ 6.57	$ 6.52

SHARE-BASED COMPENSATION - Su_2

SHARE-BASED COMPENSATION - Summary of Stock Option Transactions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Stock Options
Granted (in shares)	0
Exercised (in shares)	0	0	0
Forfeited or Expired (in shares)	(138,000)
Outstanding, ending balance (in shares)	10,832,000
Exercisable (in shares)	10,832,000	10,970,000
Weighted Average Exercise Price
Granted (in dollars per share)	$ 0
Exercised (in dollars per share)	0
Forfeited or Expired (in dollars per share)	10.32
Outstanding, ending balance (in dollars per share)	4.95
Exercisable (in dollars per share)	$ 4.95	$ 5.01

SHARE-BASED COMPENSATION - Stoc

SHARE-BASED COMPENSATION - Stock Options Granted (Details) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2023 day	Dec. 31, 2021 USD ($) $ / shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options exercisable intrinsic value		$ 10,000
Options vesting term, number of consecutive trading days | day	10
Service Trigger One
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock price trigger (in dollars per share) | $ / shares		$ 3.50
Stock options exercisable intrinsic value		$ 3,333
Service Trigger Two
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock price trigger (in dollars per share) | $ / shares		$ 4.50
Stock options exercisable intrinsic value		$ 3,333
Service Trigger Three
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock price trigger (in dollars per share) | $ / shares		$ 5.50
Stock options exercisable intrinsic value		$ 3,334

SHARE-BASED COMPENSATION - Sche

SHARE-BASED COMPENSATION - Schedule of Valuation Assumptions of Stock Options (Details) - Stock Options	12 Months Ended
	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected volatility	113.60%
Expected dividend yields	0%
Risk-free rate	0.40%

INCENTIVE COMPENSATION PROGRA_2

INCENTIVE COMPENSATION PROGRAM - Narrative (Details)	12 Months Ended
	Dec. 31, 2023 USD ($) vesting_tranche shares	Dec. 31, 2022 USD ($)
Short-term incentive awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense | $	$ 0	$ 15,700,000
Long Term Incentive Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award conversion ratio (in shares) | shares	1
2021 LTI Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting tranches	3
2022 LTI Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting tranches	3

INCENTIVE COMPENSATION PROGRA_3

INCENTIVE COMPENSATION PROGRAM - Non-vested Tracking Unit Awards and Award Granted During Period (Details) shares in Thousands	12 Months Ended
	Dec. 31, 2023 $ / shares shares
2021 LTI Award
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested, beginning balance (in shares) | shares	12,719
Granted (in shares) | shares	0
Vested (in shares) | shares	(6,359)
Forfeited (in shares) | shares	(368)
Unvested, ending balance (in shares) | shares	5,992
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Unvested, beginning balance (in dollars per share) | $ / shares	$ 1.68
Granted (in dollars per share) | $ / shares	0
Vested (in dollars per share) | $ / shares	2.13
Forfeited (in dollars per share) | $ / shares	1.50
Unvested, ending balance (in dollars per share) | $ / shares	$ 0.76
2022 LTI Award
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested, beginning balance (in shares) | shares	0
Granted (in shares) | shares	14,802
Vested (in shares) | shares	(4,934)
Forfeited (in shares) | shares	(606)
Unvested, ending balance (in shares) | shares	9,262
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Unvested, beginning balance (in dollars per share) | $ / shares	$ 0
Granted (in dollars per share) | $ / shares	2.10
Vested (in dollars per share) | $ / shares	1.63
Forfeited (in dollars per share) | $ / shares	1.46
Unvested, ending balance (in dollars per share) | $ / shares	$ 0.76

INCENTIVE COMPENSATION PROGRA_4

INCENTIVE COMPENSATION PROGRAM - Schedule of Recognized Compensation Expenses Related to the 2021 LTI Award and the 2022 LTI Award (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
2022 LTI Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 5,280	$ 0
2021 LTI Award
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ (788)	$ 15,681

INCOME TAXES - Schedule of Comp

INCOME TAXES - Schedule of Components of Income Tax Benefit (Provision) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Current:
Federal	$ 0	$ 0	$ 0
State	0	0	0
Foreign	0	0	0
Total Current	0	0	0
Deferred:
Federal	0	0	0
State	0	0	0
Foreign	0	0	0
Total Deferred	0	0	0
Total income tax benefit (provision)	$ 0	$ 0	$ 0

INCOME TAXES - Schedule of Inco

INCOME TAXES - Schedule of Income before Income Tax, Domestic and Foreign (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Domestic	$ (166,694)	$ (36,591)	$ (111,114)
Foreign	517	(13,219)	(3,624)
Loss before income taxes	$ (166,177)	$ (49,810)	$ (114,738)

INCOME TAXES - Summary of Effec

INCOME TAXES - Summary of Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income tax benefit (provision) at U.S. statutory rate	$ 34,897	$ 10,460	$ 24,095
Share-based compensation	(126)	(126)	1,352
Executive compensation	(3,919)	(3,688)	(203)
Change in U.S. state tax rate	0	(1,313)	0
Change in foreign tax rate	0	1,816	0
Disallowed interest	(4,683)	0	0
U.S. state tax	5,494	792	4,333
Change in valuation allowance	(29,877)	(8,871)	(29,648)
R&D Credit	0	748	524
Foreign rate differential	(38)	516	(74)
Other	(1,748)	(334)	(379)
Total income tax benefit (provision)	$ 0	$ 0	$ 0

INCOME TAXES - Components of De

INCOME TAXES - Components of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Capitalized costs	$ 92,758	$ 85,875
Compensation and benefits	2,299	8,860
Lease liability	34,391	16,086
Disallowed interest expense carryforward	3,974	3,510
Federal	124,320	99,922
State	21,036	16,142
Foreign	10,760	11,023
Other, net	14,689	7,080
Deferred tax assets	304,227	248,498
Less valuation allowance	(241,034)	(211,157)
Deferred tax assets, net of valuation allowance	63,193	37,341
Property and equipment	(63,193)	(37,341)
Net deferred tax assets	$ 0	$ 0

INCOME TAXES - Additional Infor

INCOME TAXES - Additional Information (Details)	12 Months Ended
	Dec. 31, 2023 USD ($)
Income Tax Disclosure [Abstract]
Federal NOL carryforwards	$ 572,000,000
State NOL carryforwards	361,100,000
Foreign NOL carryforwards	44,700,000
NOLs with indefinite carryforward period	670,600,000
Increase in valuation allowance	29,900,000
Uncertain tax positions, interest or penalties	0
Unrecognized tax benefits	0
Undistributed earnings and profits	$ 0

LEASES - Additional Information

LEASES - Additional Information (Details)	12 Months Ended
	Dec. 31, 2023 option
Driftwood Project
Lessee, Lease, Description [Line Items]
Finance lease, number of option to extend	1
Finance lease renewal term (in years)	40 years
Finance lease, termination term (in years)	5 years
Land
Lessee, Lease, Description [Line Items]
Finance lease, number of option to extend	1
Finance lease renewal term (in years)	69 years
Finance lease, termination term (in years)	7 years
Office Building
Lessee, Lease, Description [Line Items]
Operating lease, number of option to extend	1
Operating lease renewal term (in years)	10 years

LEASES - Schedule of Right-of-U

LEASES - Schedule of Right-of-Use Asset and Lease Liability (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Right of use asset — operating leases	$ 12,814	$ 13,303
Right of use asset - financing	126,225	56,708
Total Leased Assets	139,039	70,011
Operating lease liability - current	3,835	2,734
Finance lease liability - current	875	140
Operating lease liability - non-current	10,743	12,148
Finance lease liabilities	121,450	49,963
Total leased liabilities	$ 136,903	$ 64,985
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Other non-current assets	Other non-current assets
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant and equipment, net	Property, plant and equipment, net
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Accrued and other liabilities	Accrued and other liabilities
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Accrued and other liabilities	Accrued and other liabilities
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other non-current liabilities	Other non-current liabilities

LEASES - Schedule of Lease, Cos

LEASES - Schedule of Lease, Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating lease cost	$ 3,915	$ 3,149	$ 2,519
Amortization of lease assets	3,461	1,174	788
Interest on lease liabilities	9,202	3,978	2,904
Finance lease cost	12,663	5,152	3,692
Total lease cost	$ 16,578	$ 8,301	$ 6,211

LEASES - Other Information abou

LEASES - Other Information about Lease (Details)	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Operating lease, weighted-average remaining lease term (in years)	3 years 6 months	4 years 6 months
Finance lease, weighted-average remaining lease term (in years)	36 years 1 month 6 days	48 years 4 months 24 days
Operating lease, weighted-average discount rate (as a percentage)	6.40%	6.20%
Finance lease, weighted-average discount rate (as a percentage)	8.70%	9.40%

LEASES - Other Quantitative Inf

LEASES - Other Quantitative Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Operating cash flows from operating leases	$ 4,333	$ 3,423	$ 2,953
Operating cash flows from finance leases	7,950	3,674	1,813
Financing cash flows from finance leases	$ 512	$ 132	$ 1,926

LEASES - Schedule of Lease Matu

LEASES - Schedule of Lease Maturity (Details) $ in Thousands	Dec. 31, 2023 USD ($)
Operating
2024	$ 4,666
2025	4,721
2026	4,756
2027	1,954
2028	275
After 2028	0
Total lease payments	16,372
Less: discount	1,794
Present value of lease liability	14,578
Finance
2024	10,491
2025	10,491
2026	10,491
2027	10,491
2028	10,491
After 2028	322,334
Total lease payments	374,789
Less: discount	252,465
Present value of lease liability	$ 122,324

SUPPLEMENTAL CASH FLOW INFORM_3

SUPPLEMENTAL CASH FLOW INFORMATION - Net Change in Components of Operating Assets and Liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Supplemental Cash Flow Elements [Abstract]
Accounts receivable	$ 50,941	$ (67,462)	$ (4,770)
Prepaid expenses and other current assets	(9,250)	5,801	(2,536)
Accounts payable	(17,950)	1,953	(5,514)
Accounts payable due to related parties	0	0	(910)
Accrued liabilities	(2,851)	44,548	55,884
Other, net	0	(793)	(1,137)
Net changes in working capital	$ 20,890	$ (15,953)	$ 41,017

SUPPLEMENTAL CASH FLOW INFORM_4

SUPPLEMENTAL CASH FLOW INFORMATION- Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Non-cash accruals of property, plant and equipment and other non-current assets	$ 48,096	$ 13,323	$ 56,305
Non-cash settlement of Embedded derivative	4,899	0	0
Non-cash settlement of withholding taxes associated with the 2019 bonus paid and vesting of certain awards	0	0	3,064
Non-cash settlement of the 2019 bonus paid	0	0	5,430
Asset retirement obligation additions and revisions	$ 0	$ 1,533	$ 76

SUPPLEMENTAL CASH FLOW INFORM_5

SUPPLEMENTAL CASH FLOW INFORMATION - Reconciliation of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents	$ 75,789	$ 474,205	$ 305,496
Current restricted cash	4,688	9,375	0
Non-current restricted cash	24,900	24,888	1,778
Total cash, cash equivalents and restricted cash in the statement of cash flows	$ 105,377	$ 508,468	$ 307,274	$ 81,737

DISCLOSURE ABOUT SEGMENTS AND_3

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Segment Reporting Information [Line Items]
Revenues from external customers	$ 166,128	$ 391,926	$ 71,275
Segment operating income (loss)	(148,662)	(17,773)	(112,733)
Interest expense, net	(18,047)	(13,860)	(9,378)
(Loss) gain on extinguishment of debt, net	(32,295)	0	1,422
Other (loss) income , net	32,827	(18,177)	5,951
Consolidated loss before tax	(166,177)	(49,810)	(114,738)
Consolidated capital expenditures	317,505	552,888	57,865
Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures	313,609	547,198	57,865
Corporate
Segment Reporting Information [Line Items]
Revenues from external customers	0	0	0
Segment operating income (loss)	(30,566)	(36,618)	(42,153)
Interest expense, net	(18,552)	(11,655)	(3,014)
(Loss) gain on extinguishment of debt, net	(32,295)	0	0
Other (loss) income , net	18,850	964	269
Consolidated capital expenditures	3,896	5,690	0
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues from external customers	(4,331)	(11,995)	(4,427)
Upstream | Operating Segments
Segment Reporting Information [Line Items]
Revenues from external customers	18,047	15,993	2,317
Segment operating income (loss)	(55,501)	130,663	(5,651)
Interest expense, net	1,506	0	(1,642)
(Loss) gain on extinguishment of debt, net	0	0	(665)
Other (loss) income , net	1,193	3,770	(1,284)
Consolidated capital expenditures	112,992	347,240	32,364
Upstream | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues from external customers	148,081	254,984	49,182
Midstream | Operating Segments
Segment Reporting Information [Line Items]
Revenues from external customers	0	0	0
Segment operating income (loss)	(55,289)	(80,626)	(42,040)
Interest expense, net	(1,007)	(1,751)	(4,722)
(Loss) gain on extinguishment of debt, net	0	0	2,087
Other (loss) income , net	0	0	(2,494)
Consolidated capital expenditures	200,127	199,283	25,501
Midstream | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues from external customers	(7,969)	(1,760)	0
Marketing & Trading | Operating Segments
Segment Reporting Information [Line Items]
Revenues from external customers	148,081	375,933	68,958
Segment operating income (loss)	(7,306)	(31,192)	(22,889)
Interest expense, net	6	(454)	0
(Loss) gain on extinguishment of debt, net	0	0	0
Other (loss) income , net	12,783	(22,912)	9,460
Consolidated capital expenditures	490	675	0
Marketing & Trading | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues from external customers	$ (135,781)	$ (241,229)	$ (44,755)

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) shares in Millions		2 Months Ended		12 Months Ended
	Aug. 15, 2023	Feb. 21, 2024	Dec. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Jan. 02, 2024
New At-the-Market Equity Offering Program
Subsequent Event [Line Items]
Number of shares issued in transaction (in shares)				135.8	67.7
Proceeds from sale of common stock, net of fees and commissions			$ 40,200,000	$ 112,100,000	$ 299,700,000
New At-the-Market Equity Offering Program | Subsequent Event
Subsequent Event [Line Items]
Number of shares issued in transaction (in shares)		29.6
Proceeds from sale of common stock, net of fees and commissions		$ 17,800,000
Sale of stock, available aggregate sales proceeds amount		$ 366,100,000
Replacement Notes | Secured Debt
Subsequent Event [Line Items]
Number of shares issued in transaction (in shares)	25.7
Replacement Notes | Secured Debt | Subsequent Event
Subsequent Event [Line Items]
Principal amount						$ 37,900,000
Debt covenant, minimum cash amount						40,000,000
Senior Secured Notes due 2025 | Secured Debt
Subsequent Event [Line Items]
Principal amount	$ 250,000,000
Debt covenant, minimum cash amount	50,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are not outstanding	200,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are outstanding	250,000,000
Senior Secured Notes due 2025 | Secured Debt | Subsequent Event
Subsequent Event [Line Items]
Debt instrument, redemption terms, liquidity benchmark if senior notes are outstanding						$ 212,100,000
6% Secured Convertible Notes Due October 1, 2025 | Secured Debt
Subsequent Event [Line Items]
Principal amount	83,300,000
6% Secured Convertible Notes Due October 1, 2025 | Convertible Notes Payable
Subsequent Event [Line Items]
Debt covenant, minimum cash amount	50,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are not outstanding	75,000,000
Debt instrument, redemption terms, liquidity benchmark if senior notes are outstanding	$ 250,000,000

SUPPLEMENTAL DISCLOSURES ABOU_3

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Capitalized Costs Related to Natural Gas Producing Activities (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Extractive Industries [Abstract]
Proved properties	$ 561,303	$ 468,351	$ 113,950
Unproved properties	0	0	0
Gross capitalized costs	561,303	468,351	113,950
Accumulated DD&A	(187,171)	(92,423)	(48,637)
Net capitalized costs	$ 374,132	$ 375,928	$ 65,313

SUPPLEMENTAL DISCLOSURES ABOU_4

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Costs Incurred in Property Acquisitions, Exploration and Development (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Property acquisitions:
Proved	$ 0	$ 135,974	$ 3,409
Unproved	0	0	0
Exploration costs	0	0	0
Development costs	116,045	210,546	28,955
Costs incurred	$ 116,045	$ 346,520	$ 32,364

SUPPLEMENTAL DISCLOSURES ABOU_5

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Results of Operations for Natural Gas & Condensate Producing Activities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Extractive Industries [Abstract]
Natural gas sales	$ 166,128	$ 270,977	$ 51,499
Operating costs	88,276	53,963	20,576
Depreciation, depletion and amortization	95,202	43,966	10,998
Total operating costs and expenses	183,478	97,929	31,574
Results of operations	$ (17,350)	$ 173,048	$ 19,925

SUPPLEMENTAL DISCLOSURES ABOU_6

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Natural Gas & Condensate Reserve Quantity Information (Details)	12 Months Ended
	Dec. 31, 2023 MMcfe MMcf	Dec. 31, 2022 MMcfe MMcf	Dec. 31, 2021 MMcfe MMcf
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Extensions, discoveries and other additions	1,000	113,000	203,000
Revisions of previous estimates	(180,000)	(52,000)	35,000
Purchases of reserves-in-place		108,000
Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Proved reserves, beginning balance | MMcf	444,893	323,336	99,508
Extensions, discoveries and other additions | MMcf	983	113,047	202,897
Revisions of previous estimates | MMcf	(179,737)	(52,185)	35,237
Production | MMcf	(72,476)	(47,322)	(14,306)
Sale of reserves-in-place | MMcf	(15,627)	0	0
Purchases of reserves-in-place | MMcf	0	108,017	0
Proved reserves, ending balance | MMcf	178,036	444,893	323,336
Proved developed reserves: | MMcf	178,036	218,382	73,927
Proved undeveloped reserves: | MMcf	0	226,511	249,409
Gas Equivalent
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved reserve (energy), beginning balance	444,893	323,336	99,508
Extensions, discoveries and other additions	983	113,047	202,897
Revisions of previous estimates	(179,737)	(52,185)	35,237
Production	(72,476)	(47,322)	(14,306)
Sale of reserves-in-place	(15,627)	0	0
Purchases of reserves-in-place	0	108,017	0
Proved reserve (energy), ending balance	178,036	444,893	323,336
Proved developed reserves:	178,036	218,382	73,927
Proved undeveloped reserves:	0	226,511	249,409

SUPPLEMENTAL DISCLOSURES ABOU_7

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Additional Information (Details) - MMcfe MMcfe in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Extractive Industries [Abstract]
Extensions, discoveries and other additions	1	113	203
Revisions of previous estimates	(180)	(52)	35
Proved developed and undeveloped reserves, revision from removing proved undeveloped locations (in Bcfe)	(170)	(38)
Proved developed and undeveloped reserves, positive (negative) revision due to change of prices (in Bcfe)	(12)	6	9
Proved undeveloped reserves, revision from well performance (in Bcfe)	(26)	5	6
Proved developed and undeveloped, revision from changes in ownership (in Bcfe)	27	(25)	15
Proved undeveloped reserves, added from additional locations (in Bcfe)	16	89	152
Additional proved undeveloped locations, discoveries (in Bcfe)		89	152
Additional proved undeveloped locations, drilling activities (in Bcfe)		24	51
Proved developed and undeveloped reserve, revision from increased operational costs (in Bcfe)		(3)
Proved developed and undeveloped, revision from well performance (in Bcfe)		8	11
Purchases of reserves-in-place		108
Proved undeveloped reserves, revision of previous estimate (in Bcfe)		(44)	25
Proved undeveloped reverses, revision from removing proved undeveloped locations (in Bcfe)		(38)
Proved undeveloped reverses, revision from changes in ownership (in Bcfe)		(13)	16
Proved undeveloped reserves, revision due to change in commodity prices (in Bcfe)		2	3
Proved undeveloped reserves, acquisition of natural gas assets (in Bcfe)		71
Proved undeveloped reserves, converted (in Bcfe)	41	138

SUPPLEMENTAL DISCLOSURES ABOU_8

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Standardized Measure of Discounted Future Net Cash Flows Related to Proved Natural Gas & Condensate Reserves (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Extractive Industries [Abstract]
Future cash inflows	$ 326,246	$ 2,441,930	$ 945,651
Future production costs	(102,356)	(341,925)	(133,909)
Future development costs	(56,207)	(360,107)	(211,836)
Future income tax provisions	0	(257,908)	(54,401)
Future net cash flows	167,683	1,481,990	545,505
Less effect of a 10% discount factor	(42,254)	(445,686)	(181,302)
Standardized measure of discounted future net cash flows	$ 125,429	$ 1,036,304	$ 364,203	$ 6,885

SUPPLEMENTAL DISCLOSURES ABOU_9

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Changes in Standardized Measure of Discounted Future Net Cash Flows Related to Proved Natural Gas & Condensate Reserves (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning balance	$ 1,036,304	$ 364,203	$ 6,885
Sales and transfers of gas and condensate produced, net of production costs	(101,438)	(236,374)	(39,806)
Net changes in prices and production costs	(660,129)	503,099	110,850
Extensions, discoveries, additions and improved recovery, net of related costs	1,227	255,970	255,246
Development costs incurred	75,788	154,931	0
Revisions of estimated development costs	(88,121)	(105,352)	10,643
Revisions of previous quantity estimates	(331,376)	(143,398)	35,012
Accretion of discount	63,350	36,420	688
Net change in income taxes	154,609	(127,154)	(27,455)
Purchases of reserves in place	0	262,050	0
Sales of reserves in place	(30,124)	0	0
Changes in timing and other	5,339	71,909	12,140
Ending balance	$ 125,429	$ 1,036,304	$ 364,203