Tellurian (TELZ) 8-K 30 Dec 22 2021 FY Other Events Financial data

Cover

Cover	12 Months Ended
	Dec. 31, 2021
Document Information [Line Items]
Document Type	8-K
Document Period End Date	Dec. 31, 2021
Entity File Number	001-5507
Entity Registrant Name	Tellurian Inc.
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 Emerging Growth Company	false
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Entity Central Index Key	0000061398
Written Communications	false
Soliciting Material	false
Pre-commencement Tender Offer	false
Pre-commencement Issuer Tender Offer	false
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 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

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 305,496	$ 78,297
Accounts receivable	9,270	4,500
Prepaid expenses and other current assets	12,952	2,105
Total current assets	327,718	84,902
Property, plant and equipment, net	150,545	61,257
Deferred engineering costs	110,025	110,499
Other non-current assets	33,518	36,337
Total assets	621,806	292,995
Current liabilities:
Accounts payable	2,852	23,573
Accounts payable due to related parties (Note 8)	0	910
Accrued and other liabilities	85,946	22,003
Borrowings	0	72,819
Total current liabilities	88,798	119,305
Borrowings	53,687	38,275
Other non-current liabilities	61,020	26,325
Total long-term liabilities	114,707	64,600
Commitments and Contingencies (Note 11)
Stockholders' equity:
Preferred stock, $0.01 par value, 100,000,000 authorized: 6,123,782 and 6,123,782 shares outstanding, respectively	61	61
Common stock, $0.01 par value, 800,000,000 and 800,000,000 authorized: 500,453,575 and 354,315,739 shares outstanding, respectively	4,774	3,309
Additional paid-in capital	1,344,526	922,042
Accumulated deficit	(931,060)	(816,322)
Total stockholders' equity	418,301	109,090
Total liabilities and stockholders' equity	$ 621,806	$ 292,995

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2021	Dec. 31, 2020
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)	800,000,000	800,000,000
Common stock, shares, outstanding (in shares)	500,453,575	354,315,739

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues:
Total revenue	$ 71,275	$ 37,434	$ 28,774
Operating costs and expenses:
Cost of sales	36,438	17,223	7,071
Development expenses	50,186	27,492	59,629
Depreciation, depletion and amortization	11,481	17,228	20,446
General and administrative expenses	85,903	47,349	87,487
Impairment charges	0	81,065	0
Severance and reorganization charges	0	6,359	0
Related party charges (Note 8)	0	7,357	0
Total operating costs and expenses	184,008	204,073	174,633
Loss from operations	(112,733)	(166,639)	(145,859)
Interest expense, net	(9,378)	(43,445)	(16,355)
Gain on extinguishment of debt, net	1,422	0	0
Other (expense) income, net	5,951	(612)	10,447
Total loss before income taxes	(114,738)	(210,696)	(151,767)
Income tax benefit (provision)	0	0	0
Net loss	$ (114,738)	$ (210,696)	$ (151,767)
Net loss per common share:
Basic (in dollars per share)	$ (0.28)	$ (0.79)	$ (0.69)
Diluted (in dollars per share)	$ (0.28)	$ (0.79)	$ (0.69)
Weighted average shares outstanding:
Basic (in shares)	407,615	267,615	218,548
Diluted (in shares)	407,615	267,615	218,548
Natural gas sales
Revenues:
Total revenue	$ 51,499	$ 30,441	$ 28,774
LNG sales
Revenues:
Total revenue	$ 19,776	$ 6,993	$ 0

CONSOLIDATED STATEMENT OF CHANG

CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY - USD ($) $ in Thousands	Preferred Stock	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Total
Beginning balance at Dec. 31, 2018		$ 2,195	$ 749,537	$ (453,859)	$ 297,934
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Share-based compensation, net		15	15,934
Shared-based payments		1	868
Warrants issued in connection with Borrowings (Note 12)			3,300
Net loss				(151,767)	(151,767)
Ending balance at Dec. 31, 2019	$ 61	2,211	769,639	(605,626)	166,285
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common stock issuance		808	98,867
Share-based compensation, net		55	8,589
Severance and reorganization charges		22	2,667
Shared-based payments			561
Settlement of Final Payment Fee (Note 10)		110	9,036
Warrants issued in connection with Borrowings (Note 12)			17,998
Borrowings principal repayment (Note 10)		93	13,695
Warrants exercised		10	990
Net loss				(210,696)	(210,696)
Ending balance at Dec. 31, 2020	61	3,309	922,042	(816,322)	109,090
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	$ 61	$ 4,774	$ 1,344,526	$ (931,060)	$ 418,301

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash flows from operating activities:
Net loss	$ (114,738)	$ (210,696)	$ (151,767)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, depletion and amortization	11,481	17,228	20,446
Amortization of debt issuance costs, discounts and fees	3,102	28,741	10,148
Share-based compensation	5,950	2,699	4,238
Severance and reorganization charges	0	2,689	0
Share-based payments	200	562	869
Interest elected to be paid-in-kind	508	3,317	0
Impairment charge and loss on transfer of assets	0	81,065	0
Gain on sale of assets	0	0	(4,218)
Unrealized loss (gain) on financial instruments not designated as hedges	(8,693)	2,618	(3,443)
Net gain on extinguishment of debt	(1,422)	0	0
Other	1,035	3,378	(459)
Net changes in working capital (Note 18)	41,017	(1,566)	11,178
Net cash used in operating activities	(61,560)	(69,965)	(113,008)
Cash flows from investing activities:
Acquisition and development of natural gas properties	(32,364)	(1,307)	(45,354)
Payment of engineering services	(15,208)	0	(25,997)
Proceeds from sale of assets	0	0	8,140
Purchase of property and equipment	(10,293)	0	(2,732)
Net cash used in investing activities	(57,865)	(1,307)	(65,943)
Cash flows from financing activities:
Proceeds from common stock issuances	421,809	103,664	0
Equity issuance costs	(13,955)	(3,989)	0
Proceeds from borrowings	56,500	50,000	75,000
Borrowings issuance costs	(2,854)	(2,612)	(2,246)
Borrowings principal repayments	(119,725)	(60,100)	0
Proceeds from warrant exercise	8,177	1,000	0
Tax payments for net share settlements of equity awards (Note 18)	(3,064)	(1,659)	(6,686)
Finance lease principal payments	(1,926)	(1,777)	(2,224)
Net cash provided by financing activities	344,962	84,527	63,844
Net increase (decrease) in cash, cash equivalents and restricted cash	225,537	13,255	(115,107)
Cash, cash equivalents and restricted cash, beginning of period	81,737	68,482	183,589
Cash, cash equivalents and restricted cash, end of period	307,274	81,737	68,482
Supplementary disclosure of cash flow information:
Interest paid	$ 4,105	$ 11,025	$ 8,414

ORGANIZATION AND NATURE OF OPER

ORGANIZATION AND NATURE OF OPERATIONS	12 Months Ended
	Dec. 31, 2021
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 which intends to create value for shareholders by building a low-cost, global natural gas business, profitably delivering natural gas to customers worldwide (the “Business”). We plan to develop, own and operate a global natural gas business and to deliver natural gas to customers worldwide. Tellurian is developing a portfolio of natural gas, LNG marketing, and infrastructure assets that includes an LNG terminal facility (the “Driftwood terminal”), an associated pipeline (the “Driftwood pipeline”), other related pipelines, and upstream natural gas assets. The Driftwood terminal and the Driftwood pipeline are collectively referred to as the “Driftwood Project.” 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, 2021
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. Liquidity 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. As of the date of the Consolidated Financial Statements, we have generated losses and negative cash flows from operations, and have an accumulated deficit. We have not yet established an ongoing source of revenues that is sufficient to cover our future operating costs and obligations as they become due during the twelve months following the issuance of the Consolidated Financial Statements. The Company has sufficient cash on hand and available liquidity to satisfy its obligations and fund its working capital needs for at least twelve months following the date of issuance of the Consolidated Financial Statements. The Company has the ability to generate additional proceeds from various other potential financing transactions. We are currently focused on securing financing for the construction of plants one and two of the Driftwood terminal. Segments Segment information is prepared on the same basis that our Chief Executive Officer, who is our Chief Operating Decision Maker, uses to manage the segments 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. 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 in Non-current 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 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 we deplete our natural gas reserves 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 expected 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 future undiscounted cash flows are written down to fair value. Leases The Company adopted Accounting Standards Update ASU 2016-02, Leases (Topic 842 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. Refer to Note 17 - Leases 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 As we have been in the preliminary stage of developing the Driftwood terminal, substantially all the costs related to such activities have been expensed. These costs primarily include 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 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. All amounts capitalized are periodically assessed for impairment and may be impaired if indicators are present. For additional details regarding capitalized amounts, please refer to Note 5, Deferred Engineering Costs Debt Discounts, fees and expenses incurred with the issuance of debt are amortized over the term of the debt. These amounts are presented as a reduction of our indebtedness on the accompanying Consolidated Balance Sheets. See Note 10, Borrowings 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. Postemployment 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 postemployment benefits is recognized when the obligation is probable of occurring and can be reasonably estimated. Net Loss Per Share (EPS) 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, 2021
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
PREPAID EXPENSES AND OTHER CURRENT ASSETS	NOTE 3 — PREPAID EXPENSES AND OTHER CURRENT ASSETS The components of prepaid expenses and other current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Prepaid expenses ​ $ 605 ​ $ 1,156 Deposits ​ 3,589 ​ 100 Derivative asset, net - current (Note 7) ​ 8,693 ​ 843 Other current assets ​ 65 ​ 6 Total prepaid expenses and other current assets ​ $ 12,952 ​ $ 2,105 ​

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT	NOTE 4 — PROPERTY, PLANT AND EQUIPMENT The components of property, plant and equipment consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Land and Land improvements ​ $ 25,399 ​ $ 13,808 Proved properties ​ 96,297 ​ 62,227 Wells in progress ​ 17,653 ​ 492 Corporate and other ​ 3,476 ​ 3,476 Total property, plant and equipment, at cost ​ 142,825 ​ 80,003 Accumulated depreciation, depletion and amortization ​ (50,163) ​ (38,764) Right of use asset — finance leases ​ 57,883 ​ 20,018 Total property, plant and equipment, net ​ $ 150,545 ​ $ 61,257 ​ Depreciation, depletion and amortization expenses for the years ended December 31, 2021, 2020 and 2019 were approximately $11.5 million, $17.2 million and $20.4 million, respectively. Land and Land improvements We own land in Louisiana for the purpose of constructing the Driftwood terminal. During the year ended December 31, 2021, we capitalized approximately $9.4 million in land improvement costs to prepare the land for its intended use. Proved Properties During the year ended December 31, 2021, we completed the drilling and put in production four new Haynesville operated natural gas wells. We also participated in the drilling of six Haynesville non-operated natural gas wells. During the year ended December 31, 2020, we recognized an Impairment charge of approximately $81.1 million primarily associated with our assets located in northern Louisiana.

DEFERRED ENGINEERING COSTS

DEFERRED ENGINEERING COSTS	12 Months Ended
	Dec. 31, 2021
Deferred Costs [Abstract]
DEFERRED ENGINEERING COSTS	NOTE 5 — DEFERRED ENGINEERING COSTS Deferred engineering costs of approximately $110.0 million and $110.5 million at December 31, 2021 and 2020, respectively, represent detailed engineering services related to the Driftwood terminal. The balance in this account will be transferred to construction in progress upon reaching an affirmative FID by the Company’s Board of Directors.

OTHER NON-CURRENT ASSETS

OTHER NON-CURRENT ASSETS	12 Months Ended
	Dec. 31, 2021
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
OTHER NON-CURRENT ASSETS	NOTE 6 — OTHER NON-CURRENT ASSETS Other non-current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Land lease and purchase options ​ $ 6,368 ​ $ 5,831 Permitting costs ​ 13,408 ​ 13,092 Right of use asset — operating leases ​ 10,166 ​ 11,884 Restricted cash ​ 1,778 ​ 3,440 Other ​ 1,798 ​ 2,090 Total other non-current assets ​ $ 33,518 ​ $ 36,337 ​ Land Lease and Purchase Options We hold lease and purchase option agreements (the “Options”) for certain tracts of land and associated river frontage. Upon exercise of the Options, the leases are subject to maximum terms of 50 years (inclusive of various renewals, at the option of the Company). Costs of the Options are amortized over the life of the lease once obtained or capitalized into the land if purchased. Permitting Costs Permitting costs primarily represent the purchase of wetland credits in connection with our permit application to the USACE in 2017 and 2018. These wetland credits will be applied to our permit in accordance with the Clean Water Act and the Rivers and Harbors Act, which require us to mitigate the impact to Louisiana wetlands caused by the construction of the Driftwood Project. In May 2019, we received the USACE permit. The permitting costs will be transferred to construction in progress upon reaching an affirmative FID by the Company’s Board of Directors. Restricted Cash Restricted cash as of December 31, 2021 represents cash collateralization of a letter of credit associated with a finance lease. Restricted cash as of December 31, 2020 represents unused proceeds from the 2018 Term Loan as described under Note 10 - Borrowings.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
FINANCIAL INSTRUMENTS	NOTE 7 — FINANCIAL INSTRUMENTS Natural Gas Financial Instruments During the year ended December 31, 2021, we entered into natural gas future options to economically hedge the commodity price exposure for a portion of our natural gas production. As of December 31, 2021, there were no open natural gas financial instruments positions. LNG Financial Futures During the fourth quarter of 2021, we entered into LNG financial future contracts to reduce our exposure to commodity price fluctuations, and to achieve more predictable cash flows relative to two LNG cargos that we are 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, 2021, the Company hedged approximately 2.4 million MMBtu of LNG, which represents a portion of its expected LNG cargo transactions. The open LNG financial futures positions at December 31, 2021 had maturities extending through April 2022. The following table summarizes the effect of the Company’s financial instruments on the consolidated Statements of Operations (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Year ended Year ended ​ ​ December 31, ​ December 31, ​ ​ 2021 ​ 2020 Natural Gas Financial Instruments ​ ​ Realized (loss) gain ​ $ (826) ​ $ 5,050 Unrealized loss ​ — ​ (2,618) LNG Financial Futures ​ ​ Realized gain ​ 1,010 ​ — Unrealized gain ​ 8,693 ​ — ​ The following table presents the classification of the Company’s financial derivative assets and liabilities that are required to be measured at fair value on a recurring basis on the Company’s Consolidated Balance Sheets (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Year ended Year ended ​ ​ December31, ​ December 31, ​ ​ 2021 ​ 2020 Current Assets: ​ ​ Natural Gas Financial Instruments ​ $ — ​ $ 843 LNG Financial Futures ​ 8,693 ​ — Non-Current Assets: ​ ​ Natural Gas Financial Instruments ​ — ​ 84 ​ The Company’s natural gas and LNG financial instruments are valued using quoted prices in active exchange markets as of the balance sheet date and are classified as Level 1 within the fair value hierarchy.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2021
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 8 — RELATED PARTY TRANSACTIONS Accounts Payable due to Related Parties In conjunction with the dismissal of prior litigation, we agreed to reimburse the Vice Chairman of our Board of Directors, Martin Houston, for reasonable attorneys’ fees and expenses he incurred during the litigation. We paid approximately $5.1 million to third parties to settle outstanding amounts incurred by Mr. Houston for reasonable attorneys’ fees and expenses for the year ended December 31, 2020. As of December 31, 2021 and 2020, we had also paid Mr. Houston approximately $0.9 million and $1.4 million, respectively, for other expenses he incurred in connection with the litigation. As of December 31, 2021, all amounts owed to Mr. Houston were fully settled. Other A member of our Board of Directors is a partner at a law firm that has provided legal services to the Company. Fees incurred for such services were $0.1 million and $0.4 million for the years ended December 31, 2020 and 2019, respectively. There were no fees incurred for such services for the year ended December 31, 2021.

ACCRUED AND OTHER LIABILITIES

ACCRUED AND OTHER LIABILITIES	12 Months Ended
	Dec. 31, 2021
Payables and Accruals [Abstract]
ACCRUED AND OTHER LIABILITIES	NOTE 9 — ACCRUED AND OTHER LIABILITIES The components of accrued and other liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Project development activities ​ 26,421 ​ 3,228 Payroll and compensation ​ 50,243 ​ 9,454 Accrued taxes ​ 991 ​ 1,057 Professional services (e.g., legal, audit) ​ 2,934 ​ 1,004 Warrant liabilities ​ — ​ 3,774 Lease liabilities ​ 2,279 ​ 1,950 Other ​ 3,078 ​ 1,536 Total accrued and other liabilities ​ $ 85,946 ​ $ 22,003 ​

BORROWINGS

BORROWINGS	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
BORROWINGS	NOTE 10 — BORROWINGS The following tables summarize the Company’s borrowings as of December 31, 2021, and December 31, 2020 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2021 ​ ​ ​ Unamortized debt ​ ​ ​ ​ Principal repayment ​ issuance costs and ​ ​ ​ ​ ​ obligation ​ discounts ​ Carrying value Senior Notes due 2028 ​ $ 56,500 ​ $ (2,813) ​ $ 53,687 2020 Unsecured Note ​ — ​ — ​ — 2019 Term Loan, due March 2022 ​ — ​ — ​ — 2018 Term Loan, due September 2021 ​ — ​ — ​ — Total borrowings ​ $ 56,500 ​ $ (2,813) ​ $ 53,687 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ ​ Principal repayment Unamortized debt ​ ​ ​ ​ obligation and ​ issuance costs and ​ ​ ​ ​ ​ other fees ​ discounts ​ Carrying value 2020 Unsecured Note ​ $ 16,000 ​ $ (2,376) ​ $ 13,624 2019 Term Loan, due March 2022 (a) ​ 43,217 ​ (4,942) ​ 38,275 2018 Term Loan, due September 2021 ​ 60,000 ​ (805) ​ 59,195 Total borrowings ​ $ 119,217 ​ $ (8,123) ​ $ 111,094 (a) Includes paid-in-kind interest on the 2019 Term Loan of $3.3 million. Senior Notes due 2028 On November 10, 2021, we sold in a registered public offering, $50.0 million aggregate principal amount of 8.25% Senior Notes due November 30, 2028 (the “Senior Notes”). Net proceeds from the Senior 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 Notes within 30 days. On December 7, 2021, the underwriter exercised the option and purchased an additional $6.5 million of the Senior Notes resulting in net proceeds of approximately $6.2 million after deducting fees. The Senior Notes have quarterly interest payments due on January 31, April 30, July 31, and October 31 of each year and on the maturity date. 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 Notes. During the year ended December 31, 2021, we did not sell any additional Senior Notes under the at-the-market debt offering program. See Note 20, Subsequent Events 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. Covenant Compliance As of December 31, 2021, the Company was in compliance with all covenants under the indentures governing the Senior Notes. Fair Value The Senior Notes are traded on the NYSE American under the symbol “TELZ,” and are classified as Level 1 within the fair value hierarchy. As of December 31, 2021, the closing market price of $25.02 per Senior Note was substantially the same as its carrying value. 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 the period ended December 31, 2021, no amounts were drawn under this credit line.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 11 — COMMITMENTS AND CONTINGENCIES Contractual Obligations In connection with our LNG trading activities, we have previously entered into agreements with unrelated third-party LNG merchants pursuant to which we are obligated to purchase one cargo of LNG per quarter through October 2022 at a price based on then-prevailing JKM prices. The volume of each cargo is expected to range from 3.3 to 3.6 million MMBtu, and each cargo will be purchased under DES terms.

STOCKHOLDERS' EQUITY

STOCKHOLDERS' EQUITY	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
STOCKHOLDERS' EQUITY	NOTE 12 — STOCKHOLDERS’ EQUITY At-the-Market Equity Offering Programs We maintain multiple at-the-market equity offering programs pursuant to which we may sell shares of our common stock from time to time on the NYSE American. For the year ended December 31, 2021, we issued approximately 95.9 million shares of our common stock under our at-the-market programs for net proceeds of approximately $292.0 million. As of December 31, 2021, we had remaining availability under the at-the-market programs to raise aggregate gross sales proceeds of up to approximately $432.8 million. See Note 20, Subsequent Events 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 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 Oil, Gas and Chemicals, Inc., a Delaware corporation, 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 one

2020 SEVERANCE AND REORGANIZATI

2020 SEVERANCE AND REORGANIZATION	12 Months Ended
	Dec. 31, 2021
Restructuring and Related Activities [Abstract]
2020 SEVERANCE AND REORGANIZATION	NOTE 13 — 2020 SEVERANCE AND REORGANIZATION We implemented a cost reduction and reorganization plan during the first quarter of 2020 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 and incurred approximately $6.4 million of severance and reorganization charges during the year ended December 31, 2020. Employee Retention Plan 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 vests 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”). Subject to continued employment, the Employee Retention Plan’s awards are payable over a period of twelve months commencing with the later of (i) the first month following the month in which the applicable Stock Performance Target is attained, and (ii) June 2021. The Employee Retention Plan will expire if the Stock Performance Targets are not attained by March 31, 2022. 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 $3.7 million will be paid during 2022.

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
SHARE-BASED COMPENSATION	NOTE 14 — 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, 2021, 2020 and 2019, Tellurian recognized approximately $6.0 million, $2.7 million and $4.2 million, respectively, of share-based compensation expense related to all share-based awards. As of December 31, 2021, unrecognized compensation expense, based on the grant date fair value, for all share-based awards totaled approximately $200.7 million. Restricted Stock As of December 31, 2021, we had approximately 30.8 million shares of performance-based Restricted Stock outstanding, of which approximately 19.2 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 will vest based on other criteria. As of December 31, 2021, no expense had been recognized in connection with performance-based Restricted Stock. The approximately 30.8 million shares of 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. The following table provides a summary of our Restricted Stock transactions for the year ended December 31, 2021 (shares and units in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Weighted- ​ ​ ​ ​ Average Grant ​ Shares Date Fair Value Unvested at January 1, 2021 34,961 ​ $ 5.78 Granted (1) 1,857 ​ 2.90 Vested (5,658) ​ 1.31 Forfeited (356) ​ 5.59 Unvested at December 31, 2021 30,804 ​ $ 6.43 (1) The weighted-average per share grant date fair values of Restricted Stock granted during the years ended December 31, 2020 and 2019 were $1.17 and $8.53 , respectively. The total grant date fair value of restricted stock vested during the years ended December 31, 2021, 2020 and 2019 were approximately $7.4 million, $11.7 million and $1.2 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. The following table provides a summary of our stock option transactions for the year ended December 31, 2021 (stock options in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ Average ​ Stock Options Exercise Price Outstanding at January 1, 2021 11,355 ​ $ 5.19 Granted (1) — ​ — Exercised — ​ — Forfeited or expired (276) ​ 10.32 Outstanding at December 31, 2021 11,079 ​ 5.07 Exercisable at December 31, 2021 4,413 ​ $ 5.17 ​ The stock options that were granted to a 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 ​ $ 4.50 3,333 December 15, 2023 ​ $ 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. The stock options granted during the year ended December 31, 2020, expire on the fifth anniversary of the date of its grant. There were no stock options granted during the years ended December 31, 2019 or 2018. 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. There were approximately zero, zero and seven thousand

INCENTIVE COMPENSATION PROGRAM

INCENTIVE COMPENSATION PROGRAM	12 Months Ended
	Dec. 31, 2021
Compensation Related Costs [Abstract]
INCENTIVE COMPENSATION PROGRAM	NOTE 15 — 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 in cash annually 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, 2021, we recognized approximately $26.2 million in compensation expenses for STI awards. Long-term incentive awards Long-term incentive (“LTI”) awards are granted in the form of “tracking units,” at the discretion of the Company’s Board of Directors. Each tracking unit will have 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. Tracking units will vest in three equal tranches at grant date, and the first and second anniversaries of the grant date. As of December 31, 2021, no tracking units for LTI awards had been granted under the ICP. 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 LTI award that vests at the grant date is recognized over the performance period when it is probable that the performance condition will be achieved. Compensation expense for the second and third tranches will be recognized on a straight-line basis over the requisite service period. Compensation expense for unvested tracking units is subsequently adjusted each reporting period to reflect the estimated payout levels based on the changes in the Company’s stock price and actual forfeitures. For the year ended December 31, 2021, we recognized approximately $19.9 million in compensation expenses for LTI awards that have been earned over the 2021 performance period.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
INCOME TAXES	NOTE 16 — INCOME TAXES Income tax benefit (provision) included in our reported net loss consisted of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 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, ​ 2021 2020 2019 Domestic ​ $ (111,114) ​ $ (202,831) ​ $ (139,654) Foreign ​ ​ (3,624) ​ ​ (7,865) ​ ​ (12,113) Total loss before income taxes ​ $ (114,738) ​ $ (210,696) ​ $ (151,767) ​ The reconciliation of the federal statutory income tax rate to our effective income tax rate is as follows: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Income tax benefit (provision) at U.S. statutory rate ​ $ 24,095 ​ $ 44,246 ​ $ 31,871 Share-based compensation ​ ​ 1,352 ​ ​ — ​ ​ — Impairment ​ — ​ — ​ — Change in U.S. tax rate ​ — ​ — ​ — Change in valuation allowance due to change in U.S. tax rate ​ — ​ — ​ — U.S. state tax ​ 4,333 ​ 8,563 ​ 7,529 Change in valuation allowance ​ (29,648) ​ (49,802) ​ (38,953) Other ​ (132) ​ (3,007) ​ (447) Total income tax benefit (provision) ​ $ — ​ $ — ​ $ — ​ Significant components of our deferred tax assets and liabilities are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Deferred tax assets: ​ ​ Capitalized engineering costs ​ $ 59,366 ​ $ 45,865 Capitalized start-up costs ​ 15,012 ​ 16,361 Compensation and benefits ​ 14,740 ​ 4,475 Property, plant and equipment ​ — ​ 10,569 Lease liability ​ 15,514 ​ 5,977 Net operating loss carryforwards and credits: ​ ​ Federal ​ 80,246 ​ 68,515 State ​ 13,406 ​ 11,449 Foreign ​ 5,687 ​ 5,242 Other, net ​ 1,593 ​ 3,329 Deferred tax assets ​ 205,564 ​ 171,782 Less valuation allowance ​ (201,366) ​ (171,782) Deferred tax assets, net of valuation allowance ​ 4,198 ​ — ​ ​ ​ ​ ​ ​ ​ Deferred tax liabilities ​ ​ Property and equipment ​ (4,198) ​ — Net deferred tax assets ​ $ — ​ $ — ​ As of December 31, 2021, we had federal, state and international net operating loss (“NOL”) carryforwards of approximately $360.8 million, $253.7 million and $31.4 million, respectively. Approximately $270.5 million of these NOLs have an indefinite carryforward period. All other NOLs will expire between 2036 and 2037. 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, 2021 and 2020. We will continue to evaluate the realizability of our deferred tax assets in the future. The increase in the valuation allowance was approximately $29.6 million for the year ended December 31, 2021. 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, 2021, 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. We are not currently under audit by any taxing authority. 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, 2021, 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, 2021
Leases [Abstract]
LEASES	NOTE 17 — LEASES Our 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 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, ​ ​ Consolidated Balance Sheets ​ 2021 ​ 2020 Leases Classification ​ ​ ​ ​ Right of use asset ​ ​ Operating Other Non-Current Assets ​ $ 10,166 ​ $ 11,884 Finance Property, plant and equipment, net ​ 57,883 ​ 20,018 Total Leased Assets ​ ​ ​ $ 68,049 ​ $ 31,902 Liabilities ​ ​ ​ Current ​ ​ ​ Operating ​ Accrued and other liabilities ​ $ 2,147 ​ $ 1,947 Finance ​ Accrued and other liabilities ​ 132 ​ 3 Non-Current ​ ​ ​ Operating ​ Other non-current liabilities ​ 9,563 ​ 11,709 Finance ​ Other non-current liabilities ​ 50,103 ​ 13,506 Total leased liabilities ​ ​ ​ $ 61,945 ​ $ 27,165 ​ Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Lease Costs ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating lease cost ​ $ 2,519 ​ $ 2,741 ​ $ 3,616 Finance lease cost ​ ​ ​ Amortization of lease assets ​ 788 ​ 367 ​ 44 Interest on lease liabilities ​ 2,904 ​ 1,694 ​ 197 Finance lease cost ​ $ 3,692 ​ $ 2,061 ​ $ 241 Total lease cost ​ $ 6,211 ​ $ 4,802 ​ $ 3,857 ​ Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Lease term and discount rate ​ ​ ​ ​ ​ Weighted average remaining lease term (years) ​ Operating lease 4.7 5.7 ​ Finance lease 49.4 50.2 ​ Weighted average discount rate ​ Operating lease 8.0 % 8.0 % Finance lease 9.4 % 13.5 % ​ The following table includes other quantitative information for our operating and finance leases (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ Operating cash flows from operating leases ​ $ 2,953 ​ $ 2,847 ​ $ 3,173 Operating cash flows from finance leases ​ $ 1,813 ​ $ 1,056 ​ $ — Financing cash flows from finance leases ​ $ 1,926 ​ $ 1,777 ​ $ 2,224 ​ The table below presents a maturity analysis of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Operating Finance 2022 ​ $ 3,006 ​ $ 4,111 2023 ​ 3,044 ​ 4,111 2024 ​ 3,081 ​ 4,111 2025 ​ 3,119 ​ 4,111 2026 ​ 1,261 ​ 4,111 After 2026 ​ 600 ​ 182,222 Total lease payments ​ $ 14,111 ​ $ 202,777 Less: discount ​ 2,401 ​ 152,542 Present value of lease liability ​ $ 11,710 ​ $ 50,235 ​
LEASES	NOTE 17 — LEASES Our 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 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, ​ ​ Consolidated Balance Sheets ​ 2021 ​ 2020 Leases Classification ​ ​ ​ ​ Right of use asset ​ ​ Operating Other Non-Current Assets ​ $ 10,166 ​ $ 11,884 Finance Property, plant and equipment, net ​ 57,883 ​ 20,018 Total Leased Assets ​ ​ ​ $ 68,049 ​ $ 31,902 Liabilities ​ ​ ​ Current ​ ​ ​ Operating ​ Accrued and other liabilities ​ $ 2,147 ​ $ 1,947 Finance ​ Accrued and other liabilities ​ 132 ​ 3 Non-Current ​ ​ ​ Operating ​ Other non-current liabilities ​ 9,563 ​ 11,709 Finance ​ Other non-current liabilities ​ 50,103 ​ 13,506 Total leased liabilities ​ ​ ​ $ 61,945 ​ $ 27,165 ​ Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Lease Costs ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating lease cost ​ $ 2,519 ​ $ 2,741 ​ $ 3,616 Finance lease cost ​ ​ ​ Amortization of lease assets ​ 788 ​ 367 ​ 44 Interest on lease liabilities ​ 2,904 ​ 1,694 ​ 197 Finance lease cost ​ $ 3,692 ​ $ 2,061 ​ $ 241 Total lease cost ​ $ 6,211 ​ $ 4,802 ​ $ 3,857 ​ Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Lease term and discount rate ​ ​ ​ ​ ​ Weighted average remaining lease term (years) ​ Operating lease 4.7 5.7 ​ Finance lease 49.4 50.2 ​ Weighted average discount rate ​ Operating lease 8.0 % 8.0 % Finance lease 9.4 % 13.5 % ​ The following table includes other quantitative information for our operating and finance leases (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ Operating cash flows from operating leases ​ $ 2,953 ​ $ 2,847 ​ $ 3,173 Operating cash flows from finance leases ​ $ 1,813 ​ $ 1,056 ​ $ — Financing cash flows from finance leases ​ $ 1,926 ​ $ 1,777 ​ $ 2,224 ​ The table below presents a maturity analysis of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Operating Finance 2022 ​ $ 3,006 ​ $ 4,111 2023 ​ 3,044 ​ 4,111 2024 ​ 3,081 ​ 4,111 2025 ​ 3,119 ​ 4,111 2026 ​ 1,261 ​ 4,111 After 2026 ​ 600 ​ 182,222 Total lease payments ​ $ 14,111 ​ $ 202,777 Less: discount ​ 2,401 ​ 152,542 Present value of lease liability ​ $ 11,710 ​ $ 50,235

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION	12 Months Ended
	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	NOTE 18 — SUPPLEMENTAL CASH FLOW INFORMATION The following table provides information regarding the net changes in working capital (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Accounts receivable ​ $ (4,770) ​ $ 506 ​ $ (3,508) Prepaid expenses and other current assets ​ (2,536) ​ 6,915 ​ 1,147 Accounts payable ​ (5,514) ​ (1,069) ​ (699) Accounts payable due to related parties ​ (910) ​ 910 ​ — Accrued liabilities ​ 55,884 ​ (6,842) ​ 18,167 Other, net ​ (1,137) ​ (1,986) ​ (3,929) Net changes in working capital ​ $ 41,017 ​ $ (1,566) ​ $ 11,178 ​ The following table provides supplemental disclosure of cash flow information (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Non-cash accruals of property, plant and equipment and other non-current assets ​ $ 56,305 8,370 11,759 Non-cash settlement of Final Payment Fee ​ — 8,539 — Future proceeds from sale of Magellan Petroleum UK ​ — — 1,384 Tradable equity securities ​ — — 5,069 Non-cash settlement of withholding taxes associated with the 2019 and 2018 bonus paid and vesting of certain awards, respectively ​ 3,064 1,659 6,686 Non-cash settlement of the 2019 and 2018 bonus paid, respectively ​ 5,430 7,602 18,396 Asset retirement obligation additions and revisions ​ 76 — 182 ​ For the year ended December 31, 2020, the statement of cash flows reflects approximately $78.5 million and $2.1 million in non-cash movements related to the 2019 Term Loan and the Replacement Warrant, respectively. For the year ended December 31, 2019, t he statement of cash flows reflects a non-cash movement of approximately $ 0.4 million associated with funds deposited in escrow in December 2018 that were cleared in March 2019 for the purchase of land. 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, ​ 2021 2020 2019 Cash and cash equivalents ​ $ 305,496 ​ 78,297 ​ 64,615 Non-current restricted cash ​ 1,778 ​ 3,440 ​ 3,867 Total cash, cash equivalents and restricted cash in the statement of cash flows ​ $ 307,274 ​ $ 81,737 ​ $ 68,482 ​

DISCLOSURE ABOUT SEGMENTS AND R

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION	NOTE 19 — DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION During the quarter ended June 30, 2022, the Company commenced construction of the Driftwood terminal under the Phase 1 EPC Agreement with Bechtel. The Company also continued to increase its natural gas presence in the Haynesville Shale basin in northern Louisiana through the acquisition of mineral rights and natural gas drilling and marketing activities. The Company’s Chief Operating Decision Maker (“CODM”) determined to place additional emphasis on operating cash flows generated by our upstream and natural gas marketing business activities. Consequently, we identified the Upstream, Midstream and Marketing & Trading components as the Company’s operating segments. The Company’s prior period information was retrospectively revised to reflect this change in reportable segments. These functions have been defined as the operating segments of the Company because (1) they are engaged in business activities from which revenues are recognized and expenses are incurred, (2) their operating results are regularly reviewed by the Company’s CODM to make decisions about resources to be allocated to the segment and to assess its performance, and (3) they are segments for which discrete financial information is available. Factors used to identify these operating segments are based on the nature of the business activities that are undertaken by each component. The Upstream segment is organized and operates to produce and gather natural gas. 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, 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 CODM 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. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ ​ Year ended December 31, 2021 Upstream Midstream 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) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ ​ Year ended December 31, 2020 Upstream Midstream Trading Corporate Consolidated Revenues from external customers (1) 2,358 — 35,076 — ​ $ 37,434 Intersegment revenues (purchases) (2) 28,083 — (28,083) — ​ — Segment operating loss (4) (100,788) (15,027) (13,886) (36,938) ​ (166,639) Interest expense, net (6,215) (14,424) — (22,806) ​ (43,445) Other income (loss), net 2,452 195 (408) (2,851) ​ (612) Consolidated loss before tax ​ ​ ​ $ (210,696) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ Year ended December 31, 2019 Upstream Midstream Trading Corporate Consolidated Revenues from external customers (1) 7,716 — 21,058 — ​ $ 28,774 Intersegment revenues (purchases) (2) 21,058 — (21,058) — ​ — Segment operating loss (4) (39,104) (41,380) (17,687) (47,688) ​ (145,859) Interest (expense) income, net (5,460) (12,818) — 1,923 ​ (16,355) Other income, net 7,176 — — 3,271 ​ 10,447 Consolidated loss before tax ​ ​ ​ $ (151,767) (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 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 2021 2020 2019 Upstream ​ $ 32,364 ​ $ 1,307 ​ $ 45,354 Midstream ​ 25,501 ​ — ​ 26,177 Marketing & Trading ​ — ​ — ​ 1,104 Total capital expenditures for reportable segments ​ 57,865 ​ 1,307 ​ 72,635 Corporate capital expenditures ​ — ​ — ​ 1,447 Consolidated capital expenditures ​ $ 57,865 ​ $ 1,307 ​ $ 74,082 ​

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2021
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	NOTE 20 — SUBSEQUENT EVENTS At-the-Market Programs Since January 1, 2022, and through February 7, 2022, we sold approximately $1.2 million aggregate principal amount of Senior Notes for total proceeds of approximately $1.1 million after fees and commissions and 17.9 million shares of common stock for total proceeds of approximately $48.2 million, net of approximately $1.5 million in fees and commissions under our at-the-market debt and equity offering programs, respectively. As of the date of this filing, we have remaining availability to raise aggregate gross sales proceeds of approximately $581.9 million under our at-the-market debt and equity offering programs. Cancellation of a Commitment to Purchase LNG Cargos On January 26, 2022, our wholly owned subsidiary Tellurian Trading UK Ltd entered into an agreement to cancel three LNG cargos that the Company was committed to purchase in April, July and October 2022. The Company will be required to pay a cancellation fee of approximately $1.0 million for all three LNG cargos. Refer to Note 11, Commitments and Contingencies

SUPPLEMENTAL DISCLOSURES ABOUT

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES	12 Months Ended
	Dec. 31, 2021
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, ​ 2021 2020 2019 Proved properties ​ $ 113,950 ​ $ 62,718 ​ $ 142,494 Unproved properties ​ — ​ — ​ — Gross capitalized costs ​ 113,950 ​ 62,718 ​ 142,494 Accumulated DD&A ​ (48,637) ​ (37,639) ​ (21,010) Net capitalized costs ​ $ 65,313 ​ $ 25,079 ​ $ 121,484 ​ Table II — Costs Incurred in Exploration, Property Acquisitions 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, ​ 2021 2020 2019 Property acquisitions: ​ ​ ​ Proved ​ $ 3,409 ​ $ 1,307 ​ $ 45,484 Unproved ​ — ​ — ​ — Exploration costs ​ — ​ — ​ — Development ​ 28,955 ​ — ​ 800 Costs incurred ​ $ 32,364 ​ $ 1,307 ​ $ 46,284 ​ 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, ​ 2021 2020 2019 Natural gas sales ​ $ 51,499 ​ $ 30,441 ​ $ 28,774 Operating costs ​ 20,576 ​ 15,814 ​ 14,923 Depreciation, depletion and amortization ​ 10,998 ​ 16,703 ​ 19,736 Impairment charge ​ — ​ 81,065 ​ — Total operating costs and expenses ​ 31,574 ​ 113,582 ​ 34,659 Results of operations ​ $ 19,925 ​ $ (83,141) ​ $ (5,885) ​ 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, 2021, 2020 and 2019 have been prepared by Netherland, Sewell & Associates, Inc., independent petroleum consultants. ​ ​ ​ ​ ​ ​ ​ ​ ​ Gas Condensate Gas Equivalent ​ ​ (MMcf) ​ (Mbbl) ​ (MMcfe) Proved reserves: ​ ​ ​ December 31, 2018 264,854 7 264,899 Extensions, discoveries and other additions 12,848 — 12,848 Revisions of previous estimates 4,737 (6) 4,696 Production (13,901) (1) (13,905) Sale of reserves-in-place — — — Purchases of reserves-in-place — — — December 31, 2019 268,538 — 268,538 Extensions, discoveries and other additions — — — Revisions of previous estimates (152,132) — (152,132) Production (16,898) — (16,898) Sale of reserves-in-place — — — Purchases of reserves-in-place — — — 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 Proved developed reserves: December 31, 2019 30,699 — 30,699 December 31, 2020 26,593 — 26,593 December 31, 2021 73,927 — 73,927 Proved undeveloped reserves: December 31, 2019 237,839 — 237,839 December 31, 2020 72,915 — 72,915 December 31, 2021 249,409 — 249,409 ​ 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. 2019 to 2020 Overall Reserve Changes ● Had total negative revisions of approximately 152 Bcfe, comprised primarily of a 149 Bcfe negative revision due to the downturn in commodity prices and a 17 Bcfe negative revision from the loss of leases. These downward revisions were offset by a 14 Bcfe positive revision due to improved well performance. 2019 to 2020 PUD Changes ● Had total negative revisions of approximately 165 Bcfe, comprised of a 148 Bcfe negative revision due to the downturn in commodity prices and a 17 Bcfe negative revision from lease expirations. 2018 to 2019 Overall Reserve Changes ● Added approximately 13 Bcfe of proved reserves, comprised of 12 Bcfe from additional proved undeveloped locations and 1 Bcfe from drilling activities. ● Had total positive revisions of approximately 4 Bcfe, comprised of a 4 Bcfe negative revision due to prices, a 2 Bcfe negative revision from changes in operating expenses, a 9 Bcfe positive revision from well performance and a 1 Bcfe positive revision from changes in ownership. 2018 to 2019 PUD Changes ● Converted approximately 29 Bcfe to proved developed reserves. ● Added approximately 12 Bcfe from additional proved undeveloped locations. ● Had total positive revisions of approximately 8 Bcfe, comprised primarily of a 9 Bcfe positive revision from well performance, a 2 Bcfe negative revision due to prices and a 1 Bcfe positive revision from changes in ownership. ​ 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, 2021, 2020 and 2019 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, ​ ​ 2021 2020 2019 Future cash inflows ​ $ 945,651 ​ $ 132,563 ​ $ 534,577 Future production costs ​ (133,909) ​ (34,624) ​ (102,268) Future development costs ​ (211,836) ​ (71,557) ​ (287,111) Future income tax provisions ​ (54,401) ​ — ​ (6,612) Future net cash flows ​ 545,505 ​ 26,382 ​ 138,586 Less effect of a 10% discount factor ​ (181,302) ​ (19,497) ​ (85,415) Standardized measure of discounted future net cash flows ​ $ 364,203 ​ $ 6,885 ​ $ 53,171 ​ ​ Table VI — Changes in Standardized Measure of Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves The following table sets forth the changes in the standardized measure of discounted future net cash flows (in thousands): ​ ​ ​ ​ December 31, 2018 $ 145,811 Sales and transfers of gas and condensate produced, net of production costs ​ ​ (21,704) Net changes in prices and production costs ​ ​ (134,366) Extensions, discoveries, additions and improved recovery, net of related costs ​ 2,019 Development costs incurred ​ 23,485 Revisions of estimated development costs ​ 6,165 Revisions of previous quantity estimates ​ (12,660) Accretion of discount ​ 17,821 Net change in income taxes ​ 28,316 Purchases of reserves in place ​ — Sales of reserves in place ​ — Changes in timing and other ​ (1,716) December 31, 2019 ​ $ 53,171 Sales and transfers of gas and condensate produced, net of production costs ​ (20,211) Net changes in prices and production costs ​ (58,136) Extensions, discoveries, additions and improved recovery, net of related costs ​ — Development costs incurred ​ — Revisions of estimated development costs ​ — Revisions of previous quantity estimates ​ 26,133 Accretion of discount ​ 5,725 Net change in income taxes ​ 4,077 Purchases of reserves in place ​ — Sales of reserves in place ​ — Changes in timing and other ​ (3,874) 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 ​

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2021
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.
Liquidity	Liquidity 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. As of the date of the Consolidated Financial Statements, we have generated losses and negative cash flows from operations, and have an accumulated deficit. We have not yet established an ongoing source of revenues that is sufficient to cover our future operating costs and obligations as they become due during the twelve months following the issuance of the Consolidated Financial Statements. The Company has sufficient cash on hand and available liquidity to satisfy its obligations and fund its working capital needs for at least twelve months following the date of issuance of the Consolidated Financial Statements. The Company has the ability to generate additional proceeds from various other potential financing transactions. We are currently focused on securing financing for the construction of plants one and two of the Driftwood terminal.
Segments	Segments Segment information is prepared on the same basis that our Chief Executive Officer, who is our Chief Operating Decision Maker, uses to manage the 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.
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 in Non-current 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 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	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 we deplete our natural gas reserves 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 expected 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 future undiscounted cash flows are written down to fair value.
Leases	Leases The Company adopted Accounting Standards Update ASU 2016-02, Leases (Topic 842 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. Refer to Note 17 - Leases 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 As we have been in the preliminary stage of developing the Driftwood terminal, substantially all the costs related to such activities have been expensed. These costs primarily include 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 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. All amounts capitalized are periodically assessed for impairment and may be impaired if indicators are present. For additional details regarding capitalized amounts, please refer to Note 5, Deferred Engineering Costs
Debt	Debt Discounts, fees and expenses incurred with the issuance of debt are amortized over the term of the debt. These amounts are presented as a reduction of our indebtedness on the accompanying Consolidated Balance Sheets. See Note 10, Borrowings
Share-Based Compensation	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	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.
Postemployment benefits	Postemployment 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 postemployment benefits is recognized when the obligation is probable of occurring and can be reasonably estimated.
Net Loss Per Share (EPS)	Net Loss Per Share (EPS) 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, 2021
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Prepaid Expenses and Other Current Assets	The components of prepaid expenses and other current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Prepaid expenses ​ $ 605 ​ $ 1,156 Deposits ​ 3,589 ​ 100 Derivative asset, net - current (Note 7) ​ 8,693 ​ 843 Other current assets ​ 65 ​ 6 Total prepaid expenses and other current assets ​ $ 12,952 ​ $ 2,105

PROPERTY, PLANT AND EQUIPMENT (

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Summary of Property, Plant and Equipment Comprised of Fixed Assets and Oil and Gas Properties	The components of property, plant and equipment consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Land and Land improvements ​ $ 25,399 ​ $ 13,808 Proved properties ​ 96,297 ​ 62,227 Wells in progress ​ 17,653 ​ 492 Corporate and other ​ 3,476 ​ 3,476 Total property, plant and equipment, at cost ​ 142,825 ​ 80,003 Accumulated depreciation, depletion and amortization ​ (50,163) ​ (38,764) Right of use asset — finance leases ​ 57,883 ​ 20,018 Total property, plant and equipment, net ​ $ 150,545 ​ $ 61,257

OTHER NON-CURRENT ASSETS (Table

OTHER NON-CURRENT ASSETS (Tables)	12 Months Ended
	Dec. 31, 2021
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Other Non-Current Assets	Other non-current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Land lease and purchase options ​ $ 6,368 ​ $ 5,831 Permitting costs ​ 13,408 ​ 13,092 Right of use asset — operating leases ​ 10,166 ​ 11,884 Restricted cash ​ 1,778 ​ 3,440 Other ​ 1,798 ​ 2,090 Total other non-current assets ​ $ 33,518 ​ $ 36,337

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments, Gain (Loss)	The following table summarizes the effect of the Company’s financial instruments on the consolidated Statements of Operations (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Year ended Year ended ​ ​ December 31, ​ December 31, ​ ​ 2021 ​ 2020 Natural Gas Financial Instruments ​ ​ Realized (loss) gain ​ $ (826) ​ $ 5,050 Unrealized loss ​ — ​ (2,618) LNG Financial Futures ​ ​ Realized gain ​ 1,010 ​ — Unrealized gain ​ 8,693 ​ —
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the classification of the Company’s financial derivative assets and liabilities that are required to be measured at fair value on a recurring basis on the Company’s Consolidated Balance Sheets (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Year ended Year ended ​ ​ December31, ​ December 31, ​ ​ 2021 ​ 2020 Current Assets: ​ ​ Natural Gas Financial Instruments ​ $ — ​ $ 843 LNG Financial Futures ​ 8,693 ​ — Non-Current Assets: ​ ​ Natural Gas Financial Instruments ​ — ​ 84

ACCRUED AND OTHER LIABILITIES (

ACCRUED AND OTHER LIABILITIES (Tables)	12 Months Ended
	Dec. 31, 2021
Payables and Accruals [Abstract]
Schedule of Components of Accrued and Other Liabilities	The components of accrued and other liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Project development activities ​ 26,421 ​ 3,228 Payroll and compensation ​ 50,243 ​ 9,454 Accrued taxes ​ 991 ​ 1,057 Professional services (e.g., legal, audit) ​ 2,934 ​ 1,004 Warrant liabilities ​ — ​ 3,774 Lease liabilities ​ 2,279 ​ 1,950 Other ​ 3,078 ​ 1,536 Total accrued and other liabilities ​ $ 85,946 ​ $ 22,003

BORROWINGS (Tables)

BORROWINGS (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Borrowings	The following tables summarize the Company’s borrowings as of December 31, 2021, and December 31, 2020 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2021 ​ ​ ​ Unamortized debt ​ ​ ​ ​ Principal repayment ​ issuance costs and ​ ​ ​ ​ ​ obligation ​ discounts ​ Carrying value Senior Notes due 2028 ​ $ 56,500 ​ $ (2,813) ​ $ 53,687 2020 Unsecured Note ​ — ​ — ​ — 2019 Term Loan, due March 2022 ​ — ​ — ​ — 2018 Term Loan, due September 2021 ​ — ​ — ​ — Total borrowings ​ $ 56,500 ​ $ (2,813) ​ $ 53,687 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2020 ​ ​ Principal repayment Unamortized debt ​ ​ ​ ​ obligation and ​ issuance costs and ​ ​ ​ ​ ​ other fees ​ discounts ​ Carrying value 2020 Unsecured Note ​ $ 16,000 ​ $ (2,376) ​ $ 13,624 2019 Term Loan, due March 2022 (a) ​ 43,217 ​ (4,942) ​ 38,275 2018 Term Loan, due September 2021 ​ 60,000 ​ (805) ​ 59,195 Total borrowings ​ $ 119,217 ​ $ (8,123) ​ $ 111,094 (a) Includes paid-in-kind interest on the 2019 Term Loan of $3.3 million.

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Summary of Restricted Stock Transactions	The following table provides a summary of our Restricted Stock transactions for the year ended December 31, 2021 (shares and units in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Weighted- ​ ​ ​ ​ Average Grant ​ Shares Date Fair Value Unvested at January 1, 2021 34,961 ​ $ 5.78 Granted (1) 1,857 ​ 2.90 Vested (5,658) ​ 1.31 Forfeited (356) ​ 5.59 Unvested at December 31, 2021 30,804 ​ $ 6.43 (1) The weighted-average per share grant date fair values of Restricted Stock granted during the years ended December 31, 2020 and 2019 were $1.17 and $8.53 , respectively.
Summary of Stock Option Transactions	The following table provides a summary of our stock option transactions for the year ended December 31, 2021 (stock options in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted ​ ​ ​ ​ Average ​ Stock Options Exercise Price Outstanding at January 1, 2021 11,355 ​ $ 5.19 Granted (1) — ​ — Exercised — ​ — Forfeited or expired (276) ​ 10.32 Outstanding at December 31, 2021 11,079 ​ 5.07 Exercisable at December 31, 2021 4,413 ​ $ 5.17
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	The stock options that were granted to a 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 ​ $ 4.50 3,333 December 15, 2023 ​ $ 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.
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 %

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2021
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, ​ 2021 2020 2019 Current: ​ ​ ​ ​ ​ ​ Federal ​ $ — ​ $ — ​ $ — State ​ — ​ — ​ — Foreign ​ — ​ — ​ — Total Current ​ — ​ — ​ — Deferred: ​ ​ ​ Federal ​ — ​ — ​ — State ​ — ​ — ​ — Foreign ​ — ​ — ​ — Total Deferred ​ — ​ — ​ — Total income tax benefit (provision) ​ $ — ​ $ — ​ $ —
Schedule of Income before Income Tax, Domestic and Foreign	The sources of loss from operations before income taxes were as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Domestic ​ $ (111,114) ​ $ (202,831) ​ $ (139,654) Foreign ​ ​ (3,624) ​ ​ (7,865) ​ ​ (12,113) Total loss before income taxes ​ $ (114,738) ​ $ (210,696) ​ $ (151,767)
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, ​ 2021 2020 2019 Income tax benefit (provision) at U.S. statutory rate ​ $ 24,095 ​ $ 44,246 ​ $ 31,871 Share-based compensation ​ ​ 1,352 ​ ​ — ​ ​ — Impairment ​ — ​ — ​ — Change in U.S. tax rate ​ — ​ — ​ — Change in valuation allowance due to change in U.S. tax rate ​ — ​ — ​ — U.S. state tax ​ 4,333 ​ 8,563 ​ 7,529 Change in valuation allowance ​ (29,648) ​ (49,802) ​ (38,953) Other ​ (132) ​ (3,007) ​ (447) 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, ​ 2021 2020 Deferred tax assets: ​ ​ Capitalized engineering costs ​ $ 59,366 ​ $ 45,865 Capitalized start-up costs ​ 15,012 ​ 16,361 Compensation and benefits ​ 14,740 ​ 4,475 Property, plant and equipment ​ — ​ 10,569 Lease liability ​ 15,514 ​ 5,977 Net operating loss carryforwards and credits: ​ ​ Federal ​ 80,246 ​ 68,515 State ​ 13,406 ​ 11,449 Foreign ​ 5,687 ​ 5,242 Other, net ​ 1,593 ​ 3,329 Deferred tax assets ​ 205,564 ​ 171,782 Less valuation allowance ​ (201,366) ​ (171,782) Deferred tax assets, net of valuation allowance ​ 4,198 ​ — ​ ​ ​ ​ ​ ​ ​ Deferred tax liabilities ​ ​ Property and equipment ​ (4,198) ​ — Net deferred tax assets ​ $ — ​ $ —

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
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, ​ ​ Consolidated Balance Sheets ​ 2021 ​ 2020 Leases Classification ​ ​ ​ ​ Right of use asset ​ ​ Operating Other Non-Current Assets ​ $ 10,166 ​ $ 11,884 Finance Property, plant and equipment, net ​ 57,883 ​ 20,018 Total Leased Assets ​ ​ ​ $ 68,049 ​ $ 31,902 Liabilities ​ ​ ​ Current ​ ​ ​ Operating ​ Accrued and other liabilities ​ $ 2,147 ​ $ 1,947 Finance ​ Accrued and other liabilities ​ 132 ​ 3 Non-Current ​ ​ ​ Operating ​ Other non-current liabilities ​ 9,563 ​ 11,709 Finance ​ Other non-current liabilities ​ 50,103 ​ 13,506 Total leased liabilities ​ ​ ​ $ 61,945 ​ $ 27,165 Other information about lease amounts recognized in our Consolidated Financial Statements is as follows: ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2021 2020 Lease term and discount rate ​ ​ ​ ​ ​ Weighted average remaining lease term (years) ​ Operating lease 4.7 5.7 ​ Finance lease 49.4 50.2 ​ Weighted average discount rate ​ Operating lease 8.0 % 8.0 % Finance lease 9.4 % 13.5 %
Schedule of Lease, Cost	Lease costs recognized in our Consolidated Statements of Operations is summarized as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Lease Costs ​ ​ ​ ​ ​ ​ ​ ​ ​ Operating lease cost ​ $ 2,519 ​ $ 2,741 ​ $ 3,616 Finance lease cost ​ ​ ​ Amortization of lease assets ​ 788 ​ 367 ​ 44 Interest on lease liabilities ​ 2,904 ​ 1,694 ​ 197 Finance lease cost ​ $ 3,692 ​ $ 2,061 ​ $ 241 Total lease cost ​ $ 6,211 ​ $ 4,802 ​ $ 3,857 The following table includes other quantitative information for our operating and finance leases (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: ​ ​ ​ Operating cash flows from operating leases ​ $ 2,953 ​ $ 2,847 ​ $ 3,173 Operating cash flows from finance leases ​ $ 1,813 ​ $ 1,056 ​ $ — Financing cash flows from finance leases ​ $ 1,926 ​ $ 1,777 ​ $ 2,224
Schedule of Finance Lease, Liability, Maturity	The table below presents a maturity analysis of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Operating Finance 2022 ​ $ 3,006 ​ $ 4,111 2023 ​ 3,044 ​ 4,111 2024 ​ 3,081 ​ 4,111 2025 ​ 3,119 ​ 4,111 2026 ​ 1,261 ​ 4,111 After 2026 ​ 600 ​ 182,222 Total lease payments ​ $ 14,111 ​ $ 202,777 Less: discount ​ 2,401 ​ 152,542 Present value of lease liability ​ $ 11,710 ​ $ 50,235
Schedule of Operating Lease Maturity	​ The table below presents a maturity analysis of our lease liability on an undiscounted basis and reconciles those amounts to the present value of the lease liability as of December 31, 2021 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Operating Finance 2022 ​ $ 3,006 ​ $ 4,111 2023 ​ 3,044 ​ 4,111 2024 ​ 3,081 ​ 4,111 2025 ​ 3,119 ​ 4,111 2026 ​ 1,261 ​ 4,111 After 2026 ​ 600 ​ 182,222 Total lease payments ​ $ 14,111 ​ $ 202,777 Less: discount ​ 2,401 ​ 152,542 Present value of lease liability ​ $ 11,710 ​ $ 50,235

SUPPLEMENTAL CASH FLOW INFORM_2

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2021
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, ​ 2021 2020 2019 Accounts receivable ​ $ (4,770) ​ $ 506 ​ $ (3,508) Prepaid expenses and other current assets ​ (2,536) ​ 6,915 ​ 1,147 Accounts payable ​ (5,514) ​ (1,069) ​ (699) Accounts payable due to related parties ​ (910) ​ 910 ​ — Accrued liabilities ​ 55,884 ​ (6,842) ​ 18,167 Other, net ​ (1,137) ​ (1,986) ​ (3,929) Net changes in working capital ​ $ 41,017 ​ $ (1,566) ​ $ 11,178
Supplemental Disclosure of Cash Flow Information	The following table provides supplemental disclosure of cash flow information (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2021 2020 2019 Non-cash accruals of property, plant and equipment and other non-current assets ​ $ 56,305 8,370 11,759 Non-cash settlement of Final Payment Fee ​ — 8,539 — Future proceeds from sale of Magellan Petroleum UK ​ — — 1,384 Tradable equity securities ​ — — 5,069 Non-cash settlement of withholding taxes associated with the 2019 and 2018 bonus paid and vesting of certain awards, respectively ​ 3,064 1,659 6,686 Non-cash settlement of the 2019 and 2018 bonus paid, respectively ​ 5,430 7,602 18,396 Asset retirement obligation additions and revisions ​ 76 — 182 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, ​ 2021 2020 2019 Cash and cash equivalents ​ $ 305,496 ​ 78,297 ​ 64,615 Non-current restricted cash ​ 1,778 ​ 3,440 ​ 3,867 Total cash, cash equivalents and restricted cash in the statement of cash flows ​ $ 307,274 ​ $ 81,737 ​ $ 68,482

DISCLOSURE ABOUT SEGMENTS AND_2

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Summary of segment disclosure	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ ​ Year ended December 31, 2021 Upstream Midstream 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) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ ​ Year ended December 31, 2020 Upstream Midstream Trading Corporate Consolidated Revenues from external customers (1) 2,358 — 35,076 — ​ $ 37,434 Intersegment revenues (purchases) (2) 28,083 — (28,083) — ​ — Segment operating loss (4) (100,788) (15,027) (13,886) (36,938) ​ (166,639) Interest expense, net (6,215) (14,424) — (22,806) ​ (43,445) Other income (loss), net 2,452 195 (408) (2,851) ​ (612) Consolidated loss before tax ​ ​ ​ $ (210,696) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Marketing & ​ ​ Year ended December 31, 2019 Upstream Midstream Trading Corporate Consolidated Revenues from external customers (1) 7,716 — 21,058 — ​ $ 28,774 Intersegment revenues (purchases) (2) 21,058 — (21,058) — ​ — Segment operating loss (4) (39,104) (41,380) (17,687) (47,688) ​ (145,859) Interest (expense) income, net (5,460) (12,818) — 1,923 ​ (16,355) Other income, net 7,176 — — 3,271 ​ 10,447 Consolidated loss before tax ​ ​ ​ $ (151,767) (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 are eliminated at consolidation. (4) Operating profit (loss) is defined as operating revenues less operating costs and allocated corporate costs.
Schedule of capital expenditures	​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, Capital expenditures 2021 2020 2019 Upstream ​ $ 32,364 ​ $ 1,307 ​ $ 45,354 Midstream ​ 25,501 ​ — ​ 26,177 Marketing & Trading ​ — ​ — ​ 1,104 Total capital expenditures for reportable segments ​ 57,865 ​ 1,307 ​ 72,635 Corporate capital expenditures ​ — ​ — ​ 1,447 Consolidated capital expenditures ​ $ 57,865 ​ $ 1,307 ​ $ 74,082

SUPPLEMENTAL DISCLOSURES ABOU_2

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES (Tables)	12 Months Ended
	Dec. 31, 2021
Extractive Industries [Abstract]
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, ​ 2021 2020 2019 Proved properties ​ $ 113,950 ​ $ 62,718 ​ $ 142,494 Unproved properties ​ — ​ — ​ — Gross capitalized costs ​ 113,950 ​ 62,718 ​ 142,494 Accumulated DD&A ​ (48,637) ​ (37,639) ​ (21,010) Net capitalized costs ​ $ 65,313 ​ $ 25,079 ​ $ 121,484
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, ​ 2021 2020 2019 Property acquisitions: ​ ​ ​ Proved ​ $ 3,409 ​ $ 1,307 ​ $ 45,484 Unproved ​ — ​ — ​ — Exploration costs ​ — ​ — ​ — Development ​ 28,955 ​ — ​ 800 Costs incurred ​ $ 32,364 ​ $ 1,307 ​ $ 46,284
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, ​ 2021 2020 2019 Natural gas sales ​ $ 51,499 ​ $ 30,441 ​ $ 28,774 Operating costs ​ 20,576 ​ 15,814 ​ 14,923 Depreciation, depletion and amortization ​ 10,998 ​ 16,703 ​ 19,736 Impairment charge ​ — ​ 81,065 ​ — Total operating costs and expenses ​ 31,574 ​ 113,582 ​ 34,659 Results of operations ​ $ 19,925 ​ $ (83,141) ​ $ (5,885)
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	​ ​ ​ ​ ​ ​ ​ ​ ​ Gas Condensate Gas Equivalent ​ ​ (MMcf) ​ (Mbbl) ​ (MMcfe) Proved reserves: ​ ​ ​ December 31, 2018 264,854 7 264,899 Extensions, discoveries and other additions 12,848 — 12,848 Revisions of previous estimates 4,737 (6) 4,696 Production (13,901) (1) (13,905) Sale of reserves-in-place — — — Purchases of reserves-in-place — — — December 31, 2019 268,538 — 268,538 Extensions, discoveries and other additions — — — Revisions of previous estimates (152,132) — (152,132) Production (16,898) — (16,898) Sale of reserves-in-place — — — Purchases of reserves-in-place — — — 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 Proved developed reserves: December 31, 2019 30,699 — 30,699 December 31, 2020 26,593 — 26,593 December 31, 2021 73,927 — 73,927 Proved undeveloped reserves: December 31, 2019 237,839 — 237,839 December 31, 2020 72,915 — 72,915 December 31, 2021 249,409 — 249,409
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, ​ ​ 2021 2020 2019 Future cash inflows ​ $ 945,651 ​ $ 132,563 ​ $ 534,577 Future production costs ​ (133,909) ​ (34,624) ​ (102,268) Future development costs ​ (211,836) ​ (71,557) ​ (287,111) Future income tax provisions ​ (54,401) ​ — ​ (6,612) Future net cash flows ​ 545,505 ​ 26,382 ​ 138,586 Less effect of a 10% discount factor ​ (181,302) ​ (19,497) ​ (85,415) Standardized measure of discounted future net cash flows ​ $ 364,203 ​ $ 6,885 ​ $ 53,171 The following table sets forth the changes in the standardized measure of discounted future net cash flows (in thousands): ​ ​ ​ ​ December 31, 2018 $ 145,811 Sales and transfers of gas and condensate produced, net of production costs ​ ​ (21,704) Net changes in prices and production costs ​ ​ (134,366) Extensions, discoveries, additions and improved recovery, net of related costs ​ 2,019 Development costs incurred ​ 23,485 Revisions of estimated development costs ​ 6,165 Revisions of previous quantity estimates ​ (12,660) Accretion of discount ​ 17,821 Net change in income taxes ​ 28,316 Purchases of reserves in place ​ — Sales of reserves in place ​ — Changes in timing and other ​ (1,716) December 31, 2019 ​ $ 53,171 Sales and transfers of gas and condensate produced, net of production costs ​ (20,211) Net changes in prices and production costs ​ (58,136) Extensions, discoveries, additions and improved recovery, net of related costs ​ — Development costs incurred ​ — Revisions of estimated development costs ​ — Revisions of previous quantity estimates ​ 26,133 Accretion of discount ​ 5,725 Net change in income taxes ​ 4,077 Purchases of reserves in place ​ — Sales of reserves in place ​ — Changes in timing and other ​ (3,874) 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

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	12 Months Ended
	Dec. 31, 2021 segment
Accounting Policies [Abstract]
Number of operating segments	1
Revenue from contract with customer, required payment period from delivery	10 days

PREPAID EXPENSES AND OTHER CU_3

PREPAID EXPENSES AND OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid expenses	$ 605	$ 1,156
Deposits	3,589	100
Derivative asset, net - current	8,693	843
Other current assets	65	6
Total prepaid expenses and other current assets	$ 12,952	$ 2,105

PROPERTY, PLANT AND EQUIPMENT -

PROPERTY, PLANT AND EQUIPMENT - Summary of Property, Plant and Equipment Comprised of Fixed Assets and Oil and Gas Properties (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Total property, plant and equipment, at cost	$ 142,825	$ 80,003
Accumulated depreciation, depletion and amortization	(50,163)	(38,764)
Right of use asset - finance leases	57,883	20,018
Total property, plant and equipment, net	150,545	61,257
Land and Land improvements
Property, Plant and Equipment [Line Items]
Total property, plant and equipment, at cost	25,399	13,808
Proved properties
Property, Plant and Equipment [Line Items]
Total property, plant and equipment, at cost	96,297	62,227
Wells in progress
Property, Plant and Equipment [Line Items]
Total property, plant and equipment, at cost	17,653	492
Corporate and other
Property, Plant and Equipment [Line Items]
Total property, plant and equipment, at cost	$ 3,476	$ 3,476

PROPERTY, PLANT AND EQUIPMENT_2

PROPERTY, PLANT AND EQUIPMENT - Additional Information (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2021 USD ($) item	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Property, Plant and Equipment [Abstract]
Depreciation, depletion and amortization	$ 11,481	$ 17,228	$ 20,446
Capitalized land improvement costs	$ 9,400
Number of natural gas wells put in production | item	4
Number of natural gas wells participated drilling | item	6
Impairment charge	$ 0	$ 81,065	$ 0

DEFERRED ENGINEERING COSTS (Det

DEFERRED ENGINEERING COSTS (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Deferred Costs [Abstract]
Deferred engineering costs	$ 110,025	$ 110,499

OTHER NON-CURRENT ASSETS (Detai

OTHER NON-CURRENT ASSETS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Land lease and purchase options	$ 6,368	$ 5,831
Permitting costs	13,408	13,092
Right of use asset - operating leases	10,166	11,884
Restricted cash	1,778	3,440	$ 3,867
Other	1,798	2,090
Total other non-current assets	$ 33,518	$ 36,337
Land lease and purchase option agreements, maximum terms (in years)	50 years

FINANCIAL INSTRUMENTS - Narrati

FINANCIAL INSTRUMENTS - Narrative (Details) - LNG Financial Futures MMBTU in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021 item	Dec. 31, 2021 MMBTU
Derivatives, Fair Value [Line Items]
Purchase commitment, quantity committed | item	2
Derivative notional amount (in MMBtu) | MMBTU		2.4

FINANCIAL INSTRUMENTS - Schedul

FINANCIAL INSTRUMENTS - Schedule of Derivative Instruments Effect On Income (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Natural Gas Financial Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	$ (826)	$ 5,050
Unrealized loss (gain)	0	(2,618)
LNG Financial Futures
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Realized (loss) gain	1,010	0
Unrealized loss (gain)	$ 8,693	$ 0

FINANCIAL INSTRUMENTS - Sched_2

FINANCIAL INSTRUMENTS - Schedule of Derivative Instruments in Statement of Financial Position, Fair Value (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative asset, current	$ 8,693	$ 843
Natural Gas Financial Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative asset, current	0	843
Derivative asset, noncurrent	0	84
LNG Financial Futures
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative asset, current	$ 8,693	$ 0

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Board of Directors Chairman
Related Party Transaction [Line Items]
Payments for legal settlements	$ 5,100,000
Related party transaction, amounts of transaction	900,000	$ 1,400,000
Board Of Directors
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction	$ 0	$ 100,000	$ 400,000

ACCRUED AND OTHER LIABILITIES_2

ACCRUED AND OTHER LIABILITIES (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Payables and Accruals [Abstract]
Project development activities	$ 26,421	$ 3,228
Payroll and compensation	50,243	9,454
Accrued taxes	991	1,057
Professional services (e.g., legal, audit)	2,934	1,004
Warrant liabilities	0	3,774
Lease liabilities	2,279	1,950
Other	3,078	1,536
Total accrued and other liabilities	$ 85,946	$ 22,003

BORROWINGS - Schedule of Borrow

BORROWINGS - Schedule of Borrowings (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Principal repayment obligation	$ 56,500	$ 119,217
Unamortized debt issuance costs and discounts	(2,813)	(8,123)
Carrying value	53,687	111,094
Paid-in-kind interest	508	3,317	$ 0
Senior Notes due 2028
Debt Instrument [Line Items]
Principal repayment obligation	56,500
Unamortized debt issuance costs and discounts	(2,813)
Carrying value	53,687
2020 Unsecured Note
Debt Instrument [Line Items]
Principal repayment obligation	0	16,000
Unamortized debt issuance costs and discounts	0	(2,376)
Carrying value	0	13,624
2019 Term Loan
Debt Instrument [Line Items]
Principal repayment obligation	0	43,217
Unamortized debt issuance costs and discounts	0	(4,942)
Carrying value	0	38,275
Paid-in-kind interest		3,300
2018 Term Loan
Debt Instrument [Line Items]
Principal repayment obligation	0	60,000
Unamortized debt issuance costs and discounts	0	(805)
Carrying value	$ 0	$ 59,195

BORROWINGS - Senior Notes due 2

BORROWINGS - Senior Notes due 2028 (Details) - Senior Notes due 2028 - Senior Notes - USD ($)	Dec. 07, 2021	Nov. 10, 2021
Debt Instrument [Line Items]
Principal amount	$ 6,500,000	$ 50,000,000
Debt interest rate (as a percentage)		8.25%
Net proceeds from debt	$ 6,200,000	$ 47,500,000
Underwriters option to purchase shares (up to)		$ 7,500,000
Underwriters option to purchase shares, period		30 days

BORROWINGS - At-the-Market Debt

BORROWINGS - At-the-Market Debt Offering Program (Details)	Dec. 17, 2021 USD ($)
At-the-Market Debt Offering Program | Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 200,000,000

BORROWINGS - 2020 Senior Unsecu

BORROWINGS - 2020 Senior Unsecured Note (Details)	Apr. 29, 2020 USD ($)
2020 Unsecured Note | 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, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 03, 2020	Jul. 16, 2019	May 23, 2019
Debt Instrument [Line Items]
Gain on extinguishment of debt, net		$ 1,422	$ 0	$ 0
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
Gain on extinguishment of debt, net	$ 2,100
Debt issuance discount		$ 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, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Gain on extinguishment of debt, net		$ 1,422,000	$ 0	$ 0
2018 Term Loan | Loans Payable
Debt Instrument [Line Items]
Debt term (in years)	3 years
Principal amount	$ 60,000,000
Gain on extinguishment of debt, net		$ (700,000)

BORROWINGS - Fair Value (Detail

BORROWINGS - Fair Value (Details)	Dec. 31, 2021 $ / shares
Senior Notes | Senior Notes due 2028
Debt Instrument [Line Items]
Closing market price, fair value (in dollars per share)	$ 25.02

BORROWINGS - Trade Finance Cred

BORROWINGS - Trade Finance Credit Line (Details) - Trade Finance Credit Line - USD ($)	Dec. 31, 2021	Dec. 07, 2021	Jul. 19, 2021
Debt Instrument [Line Items]
Line of credit facility, borrowing capacity (up to)		$ 150,000,000	$ 30,000,000
Line of credit outstanding	$ 0

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) MMBTU in Millions	12 Months Ended
	Dec. 31, 2021 MMBTU item
Commitments and Contingencies Disclosure [Abstract]
Long-term purchase commitment, minimum quantity required (in cargo) | item	1
Each cargo quantity, minimum (in MMBtu)	3.3
Each cargo quantity, maximum (in MMBtu)	3.6

STOCKHOLDERS' EQUITY (Details)

STOCKHOLDERS' EQUITY (Details) $ / shares in Units, $ in Thousands, shares in Millions			1 Months Ended	3 Months Ended	12 Months Ended
	Aug. 31, 2021 USD ($)	Aug. 06, 2021 USD ($) $ / shares shares	Mar. 31, 2018 shares	Mar. 31, 2021 USD ($) shares	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Apr. 29, 2020 USD ($) $ / shares shares
STOCKHOLDERS' EQUITY
Proceeds from warrant exercise					$ 8,177	$ 1,000	$ 0
Conversion ratio					1
2020 Unsecured Note | Senior Notes
STOCKHOLDERS' EQUITY
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
2019 Term Loan | Loans Payable
STOCKHOLDERS' EQUITY
Number of shares for purchase under warrant (in shares) | shares				6
Fair value of warrant					$ 6,300
Proceeds from warrant exercise				$ 8,200
Convertible preferred stock
STOCKHOLDERS' EQUITY
Sale of stock, number of shares issued in transaction (in shares) | shares			6.1
At-the-Market Equity Offering Programs
STOCKHOLDERS' EQUITY
Sale of stock, number of shares issued in transaction (in shares) | shares					95.9
Proceeds from sale of common stock, net of fees and commissions					$ 292,000
Remaining availability of aggregate gross sales proceeds from financing programs					$ 432,800
Equity Offering In Aug 2021 | Common Stock
STOCKHOLDERS' EQUITY
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
Sale of stock, offering price (in USD per share) | $ / shares		$ 3
Option to purchase additional shares (in shares)		$ 5,300
Option to purchase additional shares, period		30 days
Over-allotment option | Common Stock
STOCKHOLDERS' EQUITY
Proceeds from sale of common stock, net of fees and commissions	$ 15,100

2020 SEVERANCE AND REORGANIZA_2

2020 SEVERANCE AND REORGANIZATION (Details)	1 Months Ended	12 Months Ended
	Jul. 31, 2021 USD ($) installment $ / shares	Dec. 31, 2021 USD ($) installment	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Restructuring and Related Activities [Abstract]
Severance and reorganization charges | $		$ 0	$ 6,359,000	$ 0
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) | $ / shares	$ 2.25
Employee retention plan, stock performance targets, stock price two (in USD per share) | $ / shares	3.25
Employee retention plan, stock performance targets, stock price three (in USD per share) | $ / shares	4.25
Employee retention plan, stock performance targets, stock price four (in USD per share) | $ / shares	$ 5.25
Employee retention plan, payable period	12 months
Employee retention plan, number of vesting installments, vested | installment		3
Employee retention plan charges | $		$ 7,900,000
Employee retention plan, expected future payment | $		$ 3,700,000

SHARE-BASED COMPENSATION - Addi

SHARE-BASED COMPENSATION - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
SHARE-BASED COMPENSATION
Share-based compensation expense	$ 6,000,000	$ 2,700,000	$ 4,200,000
Unrecognized compensation expense	$ 200,700,000
Options granted (in shares)	0		0	0
Options exercised (in shares)	0	0	7,000
2016 Plan
SHARE-BASED COMPENSATION
Number of common stock authorized for issuance (in shares)	40,000,000
Performance-Based Restricted Stock
SHARE-BASED COMPENSATION
Share-based compensation expense	$ 0
Number of awards outstanding (in shares)	30,800,000
Performance-Based Restricted Stock | Director
SHARE-BASED COMPENSATION
Number of awards outstanding (in shares)	19,200,000
Performance-Based Restricted Stock | FID
SHARE-BASED COMPENSATION
Number of awards outstanding (in shares)	10,800,000
Award vesting percentage	33.33%
Performance-Based Restricted Stock | Other Criteria
SHARE-BASED COMPENSATION
Number of awards outstanding (in shares)	800,000
Restricted Stock
SHARE-BASED COMPENSATION
Number of awards outstanding (in shares)	30,804,000	34,961,000
Antidilutive securities excluded from computation of loss per share amount (in shares)	30,800,000
Total grant date fair value of restricted stock vested	$ 7,400,000	$ 11,700,000	$ 1,200,000
Stock Options
SHARE-BASED COMPENSATION
Antidilutive securities excluded from computation of loss per share amount (in shares)	11,100,000

SHARE-BASED COMPENSATION - Summ

SHARE-BASED COMPENSATION - Summary of Restricted Stock Transactions (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Weighted-Average Grant Date Fair Value
Granted (in dollars per share)		$ 1.17	$ 8.53
Restricted Stock
Shares
Unvested, beginning balance (in shares)	34,961
Granted (in shares)	1,857
Vested (in shares)	(5,658)
Forfeited (in shares)	(356)
Unvested, ending balance (in shares)	30,804	34,961
Weighted-Average Grant Date Fair Value
Unvested, beginning balance (in dollars per share)	$ 5.78
Granted (in dollars per share)	2.90
Vested (in dollars per share)	1.31
Forfeited (in dollars per share)	5.59
Unvested, ending balance (in dollars per share)	$ 6.43	$ 5.78

SHARE-BASED COMPENSATION - Su_2

SHARE-BASED COMPENSATION - Summary of Stock Option Transactions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning balance (in shares)	11,355,000
Granted (in shares)	0		0	0
Exercised (in shares)	0	0	(7,000)
Forfeited or Expired (in shares)	(276,000)
Outstanding, ending balance (in shares)	11,079,000	11,355,000
Exercisable (in shares)	4,413,000
Weighted Average Exercise Price
Outstanding, beginning balance (in dollars per share)	$ 5.19
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)	5.07	$ 5.19
Exercisable (in dollars per share)	$ 5.17

SHARE-BASED COMPENSATION - Stoc

SHARE-BASED COMPENSATION - Stock Options Granted (Details) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2021 segment	Dec. 31, 2020 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 | segment	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 PROGRAM

INCENTIVE COMPENSATION PROGRAM (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) tranche shares
Short-term incentive awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense | $	$ 26.2
Long-term incentive awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense | $	$ 19.9
Award conversion ratio (in shares) | shares	1
Award vesting tranches | tranche	3
Granted (in shares) | shares	0

INCOME TAXES - Schedule of Comp

INCOME TAXES - Schedule of Components of Income Tax Benefit (Provision) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
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, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Domestic	$ (111,114)	$ (202,831)	$ (139,654)
Foreign	(3,624)	(7,865)	(12,113)
Total loss before income taxes	$ (114,738)	$ (210,696)	$ (151,767)

INCOME TAXES - Summary of Effec

INCOME TAXES - Summary of Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income tax benefit (provision) at U.S. statutory rate	$ 24,095	$ 44,246	$ 31,871
Share-based compensation	1,352	0	0
Impairment	0	0	0
Change in U.S. tax rate	0	0	0
Change in valuation allowance due to change in U.S. tax rate	0	0	0
U.S. state tax	4,333	8,563	7,529
Change in valuation allowance	(29,648)	(49,802)	(38,953)
Other	(132)	(3,007)	(447)
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, 2021	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Capitalized engineering costs	$ 59,366	$ 45,865
Capitalized start-up costs	15,012	16,361
Compensation and benefits	14,740	4,475
Property, plant and equipment	0	10,569
Lease liability	15,514	5,977
Federal	80,246	68,515
State	13,406	11,449
Foreign	5,687	5,242
Other, net	1,593	3,329
Deferred tax assets	205,564	171,782
Less valuation allowance	(201,366)	(171,782)
Deferred tax assets, net of valuation allowance	4,198	0
Deferred tax liabilities, property and equipment	(4,198)	0
Net deferred tax assets	$ 0	$ 0

INCOME TAXES - Additional Infor

INCOME TAXES - Additional Information (Details)	12 Months Ended
	Dec. 31, 2021 USD ($)
Income Tax Disclosure [Abstract]
Federal	$ 360,800,000
State	253,700,000
Foreign	31,400,000
NOLs with indefinite carryforward period	270,500,000
Undistributed earnings and profits	0
Uncertain tax positions, interest or penalties	0
Unrecognized tax benefits	$ 0

LEASES - Additional Information

LEASES - Additional Information (Details)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Finance lease renewal term (in years)	40 years
Finance lease, termination term (in years)	5 years
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, 2021	Dec. 31, 2020
Leases [Abstract]
Right of use asset - operating leases	$ 10,166	$ 11,884
Right of use asset - financing	57,883	20,018
Total Leased Assets	68,049	31,902
Operating lease liability - current	2,147	1,947
Finance lease liability - current	132	3
Operating lease liability - non-current	9,563	11,709
Finance lease liability - non-current	50,103	13,506
Total leased liabilities	$ 61,945	$ 27,165
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
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	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, 2021	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease cost	$ 2,519	$ 2,741	$ 3,616
Amortization of lease assets	788	367	44
Interest on lease liabilities	2,904	1,694	197
Finance lease cost	3,692	2,061	241
Total lease cost	$ 6,211	$ 4,802	$ 3,857

LEASES - Other Information abou

LEASES - Other Information about Lease (Details)	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease, weighted-average remaining lease term (in years)	4 years 8 months 12 days	5 years 8 months 12 days
Finance lease, weighted-average remaining lease term (in years)	49 years 4 months 24 days	50 years 2 months 12 days
Operating lease, weighted-average discount rate (as a percentage)	8%	8%
Finance lease, weighted-average discount rate (as a percentage)	9.40%	13.50%

LEASES - Other Quantitative Inf

LEASES - Other Quantitative Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating cash flows from operating leases	$ 2,953	$ 2,847	$ 3,173
Operating cash flows from finance leases	1,813	1,056	0
Financing cash flows from finance leases	$ 1,926	$ 1,777	$ 2,224

LEASES - Schedule of Lease Matu

LEASES - Schedule of Lease Maturity (Details) $ in Thousands	Dec. 31, 2021 USD ($)
Operating
2022	$ 3,006
2023	3,044
2024	3,081
2025	3,119
2026	1,261
After 2026	600
Total lease payments	14,111
Less: discount	2,401
Present value of lease liability	11,710
Finance
2022	4,111
2023	4,111
2024	4,111
2025	4,111
2026	4,111
After 2026	182,222
Total lease payments	202,777
Less: discount	152,542
Present value of lease liability	$ 50,235

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Accounts receivable	$ (4,770)	$ 506	$ (3,508)
Prepaid expenses and other current assets	(2,536)	6,915	1,147
Accounts payable	(5,514)	(1,069)	(699)
Accounts payable due to related parties	(910)	910	0
Accrued liabilities	55,884	(6,842)	18,167
Other, net	(1,137)	(1,986)	(3,929)
Net changes in working capital	$ 41,017	$ (1,566)	$ 11,178

SUPPLEMENTAL CASH FLOW INFORM_4

SUPPLEMENTAL CASH FLOW INFORMATION- Supplemental Disclosure of Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Supplemental Cash Flow Information [Abstract]
Non-cash accruals of property, plant and equipment and other non-current assets	$ 56,305	$ 8,370	$ 11,759
Non-cash settlement of Final Payment Fee	0	8,539	0
Future proceeds from sale of Magellan Petroleum UK	0	0	1,384
Tradable equity securities	0	0	5,069
Non-cash settlement of withholding taxes associated with the 2019 and 2018 bonus paid and vesting of certain awards, respectively	3,064	1,659	6,686
Non-cash settlement of the 2019 and 2018 bonus paid, respectively	5,430	7,602	18,396
Asset retirement obligation additions and revisions	$ 76	0	182
Noncash activities related to debt amendment		78,500
Noncash activities related to replacement warrant		$ 2,100
Escrow deposit			$ 400

SUPPLEMENTAL CASH FLOW INFORM_5

SUPPLEMENTAL CASH FLOW INFORMATION - Reconciliation of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Supplemental Cash Flow Elements [Abstract]
Cash and cash equivalents	$ 305,496	$ 78,297	$ 64,615
Non-current restricted cash	1,778	3,440	3,867
Total cash, cash equivalents and restricted cash in the statement of cash flows	$ 307,274	$ 81,737	$ 68,482	$ 183,589

DISCLOSURE ABOUT SEGMENTS AND_3

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION - Segment disclosure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Segment operating loss	$ (112,733)	$ (166,639)	$ (145,859)
Interest expense, net	(9,378)	(43,445)	(16,355)
Gain on extinguishment of debt, net	1,422	0	0
Other (expense) income, net	5,951	(612)	10,447
Total loss before income taxes	(114,738)	(210,696)	(151,767)
Operating Segments [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Revenues from external customers	71,275	37,434	28,774
Segment operating loss	(112,733)	(166,639)	(145,859)
Interest expense, net	(9,378)	(43,445)	(16,355)
Gain on extinguishment of debt, net	1,422
Other (expense) income, net	5,951	(612)	10,447
Total loss before income taxes	(114,738)	(210,696)	(151,767)
Upstream [Member] | Operating Segments [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Revenues from external customers	2,317	2,358	7,716
Intersegment revenues (purchases)	49,182	28,083	21,058
Segment operating loss	(5,651)	(100,788)	(39,104)
Interest expense, net	(1,642)	(6,215)	(5,460)
Gain on extinguishment of debt, net	(665)
Other (expense) income, net	(1,284)	2,452	7,176
Midstream [Member] | Operating Segments [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Segment operating loss	(42,040)	(15,027)	(41,380)
Interest expense, net	(4,722)	(14,424)	(12,818)
Gain on extinguishment of debt, net	2,087
Other (expense) income, net	(2,494)	195
Marketing And Trading [Member] | Operating Segments [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Revenues from external customers	68,958	35,076	21,058
Intersegment revenues (purchases)	(44,755)	(28,083)	(21,058)
Segment operating loss	(22,889)	(13,886)	(17,687)
Other (expense) income, net	9,460	(408)
Corporate Segment [Member] | Operating Segments [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Intersegment revenues (purchases)	(4,427)
Segment operating loss	(42,153)	(36,938)	(47,688)
Interest expense, net	(3,014)	(22,806)	1,923
Other (expense) income, net	$ 269	$ (2,851)	$ 3,271

DISCLOSURE ABOUT SEGMENTS AND_4

DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION - Capital expenditures (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Total capital expenditures for reportable segments	$ 57,865	$ 1,307	$ 72,635
Corporate capital expenditures			1,447
Consolidated capital expenditures	57,865	1,307	74,082
Upstream [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Total capital expenditures for reportable segments	32,364	$ 1,307	45,354
Midstream [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Total capital expenditures for reportable segments	$ 25,501		26,177
Marketing And Trading [Member]
DISCLOSURE ABOUT SEGMENTS AND RELATED INFORMATION
Total capital expenditures for reportable segments			$ 1,104

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) shares in Millions		1 Months Ended	12 Months Ended
	Jan. 26, 2022 USD ($) item	Feb. 07, 2022 USD ($) shares	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Feb. 23, 2022 USD ($)	Dec. 17, 2021 USD ($)
Subsequent Event [Line Items]
Fees and commissions on sale of stock			$ 13,955,000	$ 3,989,000	$ 0
Subsequent Event
Subsequent Event [Line Items]
Remaining availability of aggregate gross sales proceeds from financing programs						$ 581,900,000
Purchase commitment, cancellation fee	$ 1,000,000
Purchase commitment, quantity cancelled | item	3
At-the-Market Debt Offering Program | Senior Notes
Subsequent Event [Line Items]
Principal amount							$ 200,000,000
At-the-Market Debt Offering Program | Subsequent Event | Senior Notes
Subsequent Event [Line Items]
Principal amount		$ 1,200,000
Proceeds from Notes Payable		$ 1,100,000
At-the-Market Equity Offering Programs
Subsequent Event [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares			95.9
Net proceeds from sale of stock			$ 292,000,000
Remaining availability of aggregate gross sales proceeds from financing programs			$ 432,800,000
At-the-Market Equity Offering Programs | Subsequent Event
Subsequent Event [Line Items]
Sale of stock, number of shares issued in transaction (in shares) | shares		17.9
Net proceeds from sale of stock		$ 48,200,000
Fees and commissions on sale of stock		$ 1,500,000

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Proved properties	$ 113,950	$ 62,718	$ 142,494
Unproved properties	0	0	0
Gross capitalized costs	113,950	62,718	142,494
Accumulated DD&A	(48,637)	(37,639)	(21,010)
Net capitalized costs	$ 65,313	$ 25,079	$ 121,484

SUPPLEMENTAL DISCLOSURES ABOU_4

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Costs Incurred in Exploration, Property Acquisitions and Development (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property acquisitions:
Proved	$ 3,409	$ 1,307	$ 45,484
Unproved	0	0	0
Exploration costs	0	0	0
Development	28,955	0	800
Costs incurred	$ 32,364	$ 1,307	$ 46,284

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Natural gas sales	$ 51,499	$ 30,441	$ 28,774
Operating costs	20,576	15,814	14,923
Depreciation, depletion and amortization	10,998	16,703	19,736
Impairment charge	0	81,065	0
Total operating costs and expenses	31,574	113,582	34,659
Results of operations	$ 19,925	$ (83,141)	$ (5,885)

SUPPLEMENTAL DISCLOSURES ABOU_6

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Natural Gas & Condensate Reserve Quantity Information (Details) bbl in Thousands, Mcf in Thousands, MMcfe in Thousands	12 Months Ended
	Dec. 31, 2021 MMcfe Bcfe Mcf bbl	Dec. 31, 2020 Bcfe MMcfe bbl Mcf	Dec. 31, 2019 MMcfe Bcfe Mcf bbl
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Extensions, discoveries and other additions | Bcfe	203		13
Revisions of previous estimates | Bcfe	35	152	4
Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Proved reserves, beginning balance | Mcf	99,508	268,538	264,854
Extensions, discoveries and other additions | Mcf	202,897	0	12,848
Revisions of previous estimates | Mcf	35,237	(152,132)	4,737
Production | Mcf	(14,306)	(16,898)	(13,901)
Sale of reserves-in-place | Mcf	0	0	0
Purchases of reserves-in-place | Mcf	0	0	0
Proved reserves, ending balance | Mcf	323,336	99,508	268,538
Proved developed reserves: | Mcf	73,927	26,593	30,699
Proved undeveloped reserves: | Mcf	249,409	72,915	237,839
Condensate
Proved Developed and Undeveloped Reserves [Roll Forward]
Proved reserves, beginning balance | bbl	0	0	7
Extensions, discoveries and other additions | bbl	0	0	0
Revisions of previous estimates | bbl	0	0	(6)
Production | bbl	0	0	(1)
Sale of reserves-in-place | bbl	0	0	0
Purchases of reserves-in-place | bbl	0	0	0
Proved reserves, ending balance | bbl	0	0	0
Proved developed reserves: | bbl	0	0	0
Proved undeveloped reserves: | bbl	0	0	0
Gas Equivalent
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved reserve (energy), beginning balance | MMcfe	99,508	268,538	264,899
Extensions, discoveries and other additions | MMcfe	202,897	0	12,848
Revisions of previous estimates | MMcfe	35,237	(152,132)	4,696
Production | MMcfe	(14,306)	(16,898)	(13,905)
Sale of reserves-in-place | MMcfe	0	0	0
Purchases of reserves-in-place | MMcfe	0	0	0
Proved reserve (energy), ending balance | MMcfe	323,336	99,508	268,538
Proved developed reserves: | MMcfe	73,927	26,593	30,699
Proved undeveloped reserves: | MMcfe	249,409	72,915	237,839

SUPPLEMENTAL DISCLOSURES ABOU_7

SUPPLEMENTAL DISCLOSURES ABOUT NATURAL GAS PRODUCING ACTIVITIES - Additional Information (Details) - Bcfe	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Extensions, discoveries and other additions	203		13
Additional proved undeveloped locations, discoveries (in Bcfe)	152		12
Additional proved undeveloped locations, drilling activities (in Bcfe)	51		1
Revisions of previous estimates	35	152	4
Proved developed and undeveloped reserves, positive (negative) revision due to change of prices (in Bcfe)	9	149	4
Proved developed and undeveloped, revision from changes in ownership (in Bcfe)	15		1
Proved developed and undeveloped, revision from well performance (in Bcfe)	11	14	9
Proved undeveloped reserves, added from additional locations (in Bcfe)	152		12
Proved undeveloped reserves, revision of previous estimate (in Bcfe)	25		8
Proved developed and undeveloped reserves, revisions due to loss of leases (in Bcfe)		17
Proved undeveloped reserve, revision of previous estimate (in Bcfe)		165
Proved undeveloped reserves, revision due to change in commodity prices (in Bcfe)	3	148	2
Proved undeveloped reverses, revision from changes in ownership (in Bcfe)	16		1
Proved undeveloped reserves, revision from well performance (in Bcfe)	6
Proved undeveloped reserves, revision from lease expirations (in Bcfe)		17
Proved developed and undeveloped reserves, revision due to changes in operating expenses (in Bcfe)			2
Proved undeveloped reserves, converted (in Bcfe)			29

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, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Future cash inflows	$ 945,651	$ 132,563	$ 534,577
Future production costs	(133,909)	(34,624)	(102,268)
Future development costs	(211,836)	(71,557)	(287,111)
Future income tax provisions	(54,401)	0	(6,612)
Future net cash flows	545,505	26,382	138,586
Less effect of a 10% discount factor	(181,302)	(19,497)	(85,415)
Standardized measure of discounted future net cash flows	$ 364,203	$ 6,885	$ 53,171	$ 145,811

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning balance	$ 6,885	$ 53,171	$ 145,811
Sales and transfers of gas and condensate produced, net of production costs	(39,806)	(20,211)	(21,704)
Net changes in prices and production costs	110,850	(58,136)	(134,366)
Extensions, discoveries, additions and improved recovery, net of related costs	255,246	0	2,019
Development costs incurred	0	0	23,485
Revisions of estimated development costs	10,643	0	6,165
Revisions of previous quantity estimates	35,012	26,133	(12,660)
Accretion of discount	688	5,725	17,821
Net change in income taxes	(27,455)	4,077	28,316
Purchases of reserves in place	0	0	0
Sales of reserves in place	0	0	0
Changes in timing and other	12,140	(3,874)	(1,716)
Ending balance	$ 364,203	$ 6,885	$ 53,171