UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549


FORM			10-Q


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~September~~June 30, ~~2022~~2023


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number 001-5507

Tellurian Inc.

(Exact name of registrant as specified in its charter)

Delaware

06-0842255

(State or other jurisdiction of
incorporation or organization)

(I.R.S. Employer Identification No.)

1201 Louisiana Street,

Suite 3100,

Houston,

77002

(Address of principal executive offices)

(Zip Code)

(832) 962-4000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading symbol

Name of each exchange on which registered

Common stock, par value $0.01 per share

TELL

NYSE

American LLC

8.25% Senior Notes due 2028

TELZ

NYSE

American LLC

Securities registered pursuant to Section 12(g) of the Act:

None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes x No ¨

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

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No x

As of ~~October 28, 2022,~~August 7, 2023, there were ~~564,817,568~~581,819,726 shares of common stock, $0.01 par value, issued and outstanding.

Tellurian Inc.

TABLE OF CONTENTS

Page

Part I — Financial Information (Unaudited)

Item 1.

Condensed Consolidated Financial Statements

Condensed Consolidated Balance Sheets

Condensed Consolidated Statements of Operations

Condensed Consolidated Statement of Changes in Stockholders’ Equity

Condensed Consolidated Statements of Cash Flows

Notes to Condensed Consolidated Financial Statements

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

2122

Item 4.

Controls and Procedures

2122

Part II — Other Information

Item 1.

Legal Proceedings

2122

Item 1A.

Risk Factors

2122

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

2223

Item 5.

Other Information

2223

Item 6.

Exhibits

2324

Signatures

2425

Cautionary Information About Forward-Looking Statements

The information in this report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical facts, that address activity, events, or developments with respect to our financial condition, results of operations, or economic performance that we expect, believe or anticipate will or may occur in the future, or that address plans and objectives of management for future operations, are forward-looking statements. The words “anticipate,” “assume,” “believe,” “budget,” “contemplate,” “continue,” “could,” “estimate,” “expect,” “forecast,” ~~“future,”~~ “initial,” “intend,” “likely,” “may,~~” “might,~~” “plan,” “possible,” “potential,” “predict,” “project,” “proposed,” “should,” “will,” “would” and similar terms, phrases, and expressions are intended to identify forward-looking statements. These forward-looking statements relate to, among other things:

•our businesses and prospects and our overall strategy;

•planned or estimated costs or capital expenditures;

•availability of liquidity and capital resources;

•our ability to obtain financing as needed and the terms of financing transactions, including for the Driftwood Project;

•revenues and expenses;

•progress in developing our projects and the timing of that progress;

•attributes and future values of the Company’s projects or other interests, operations or rights; and

•government regulations, including our ability to obtain, and the timing of, necessary governmental permits and approvals.

Our forward-looking statements are based on assumptions and analyses made by us in light of our experience and our perception of historical trends, current conditions, expected future developments and other factors that we believe are appropriate under the circumstances. These statements are subject to a number of known and unknown risks and uncertainties, which may cause our actual results and performance to be materially different from any future results or performance expressed or implied by the forward-looking statements. Factors that could cause actual results and performance to differ materially from any future results or performance expressed or implied by the forward-looking statements include, but are not limited to, the following:

•the uncertain nature of demand for and price of natural gas and LNG;

•risks related to shortages of LNG vessels worldwide;

•technological innovation which may render our anticipated competitive advantage obsolete;

•risks related to a terrorist or military incident involving an LNG carrier;

•changes in legislation and regulations relating to the LNG industry, including environmental laws and regulations that impose significant compliance costs and liabilities;

•governmental interventions in the LNG industry, including increases in barriers to international trade;

•uncertainties regarding our ability to maintain sufficient liquidity and attract sufficient capital resources to implement our projects;

•our limited operating history;

•our ability to attract and retain key personnel;

•risks related to doing business in, and having counterparties in, foreign countries;

•our reliance on the skill and expertise of third-party service providers;

•the ability of our vendors, customers and other counterparties to meet their contractual obligations;

•risks and uncertainties inherent in management estimates of future operating results and cash flows;

•our ability to maintain compliance with our debt arrangements;

•changes in competitive factors, including the development or expansion of LNG, pipeline and other projects that are competitive with ours;

•development risks, operational hazards and regulatory approvals;

•our ability to enter into and consummate planned financing and other transactions;

•risks related to pandemics or disease outbreaks;

•risks of potential impairment charges and reductions in our reserves; and

•risks and uncertainties associated with litigation matters.

The forward-looking statements in this report speak as of the date hereof. Although we may from time to time voluntarily update our prior forward-looking statements, we disclaim any commitment to do so except as required by securities laws.

DEFINITIONS

To the extent applicable, and as used in this quarterly report, the terms listed below have the following meanings:


Bcf						Billion cubic feet of natural gas
DD&A						Depreciation, depletion and amortization
DFC						Deferred financing costs
EPC						Engineering, procurement and construction
FID						Final investment decision as it pertains to the Driftwood Project
FERC						U.S. Federal Energy Regulatory Commission
GAAP						Generally accepted accounting principles in the U.S.
LNG						Liquefied natural gas
LSTK						Lump sum turnkey
Mtpa						Million tonnes per annum
~~MmBtu~~						~~Million British thermal unit~~
NYSE American						NYSE American LLC
~~NYMEX~~						~~New York Mercantile Exchange, Inc.~~
Phase 1						Plants one and two of the Driftwood terminal
Train						An industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
U.S.						United States
~~USACE~~						~~U.S. Army Corps of Engineers~~

PART I. FINANCIAL INFORMATION

ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


TELLURIAN INC. AND SUBSIDIARIES	TELLURIAN INC. AND SUBSIDIARIES					TELLURIAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS	CONDENSED CONSOLIDATED BALANCE SHEETS					CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands, except share and per share amounts, unaudited)	(in thousands, except share and per share amounts, unaudited)					(in thousands, except share and per share amounts, unaudited)

		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	$	607,498	$	305,496	Cash and cash equivalents	$	106,706	$	474,205
Accounts receivable	Accounts receivable	62,609		9,270		Accounts receivable	15,731		76,731
Prepaid expenses and other current assets	Prepaid expenses and other current assets	31,457		12,952		Prepaid expenses and other current assets	17,700		23,355
Total current assets	Total current assets	701,564		327,718		Total current assets	140,137		574,291

Property, plant and equipment, net	Property, plant and equipment, net	670,913		150,545		Property, plant and equipment, net	1,048,880		789,076
Deferred engineering costs		—		110,025

Other non-current assets	Other non-current assets	57,805		33,518		Other non-current assets	71,233		63,316
Total assets	Total assets	$	1,430,282	$	621,806	Total assets	$	1,260,250	$	1,426,683

LIABILITIES AND STOCKHOLDERS’ EQUITY	LIABILITIES AND STOCKHOLDERS’ EQUITY					LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:	Current liabilities:					Current liabilities:
Accounts payable	Accounts payable	$	17,407	$	2,852	Accounts payable	$	49,955	$	4,805

Accrued and other liabilities	Accrued and other liabilities	149,874		85,946		Accrued and other liabilities	83,808		129,180
Borrowings	Borrowings	163,274		—		Borrowings	—		163,556
Total current liabilities	Total current liabilities	330,555		88,798		Total current liabilities	133,763		297,541

Long-term liabilities:	Long-term liabilities:					Long-term liabilities:
Borrowings	Borrowings	381,561		53,687		Borrowings	383,571		382,208
Finance lease liabilities	Finance lease liabilities	49,998		50,103		Finance lease liabilities	121,895		49,963
Other non-current liabilities	Other non-current liabilities	27,570		10,917		Other non-current liabilities	21,647		24,428
Total long-term liabilities	Total long-term liabilities	459,129		114,707		Total long-term liabilities	527,113		456,599

Commitments and Contingencies (Note 9)						Commitments and Contingencies (Note 9)

Stockholders’ equity:	Stockholders’ equity:					Stockholders’ equity:
Preferred stock, $0.01 par value, 100,000,000 authorized: 6,123,782 and 6,123,782 shares outstanding, respectively	Preferred stock, $0.01 par value, 100,000,000 authorized: 6,123,782 and 6,123,782 shares outstanding, respectively	61		61		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 authorized: 564,856,629 and 500,453,575 shares outstanding, respectively		5,456		4,774
Common stock, $0.01 par value, 1,600,000,000 authorized: 573,268,037 and 564,567,568 shares outstanding, respectively						Common stock, $0.01 par value, 1,600,000,000 authorized: 573,268,037 and 564,567,568 shares outstanding, respectively	5,560		5,456
Additional paid-in capital	Additional paid-in capital	1,647,015		1,344,526		Additional paid-in capital	1,661,735		1,647,896
Accumulated deficit	Accumulated deficit	(1,011,934)		(931,060)		Accumulated deficit	(1,067,982)		(980,870)
Total stockholders’ equity	Total stockholders’ equity	640,598		418,301		Total stockholders’ equity	599,374		672,543
Total liabilities and stockholders’ equity	Total liabilities and stockholders’ equity	$	1,430,282	$	621,806	Total liabilities and stockholders’ equity	$	1,260,250	$	1,426,683

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.


TELLURIAN INC. AND SUBSIDIARIES	TELLURIAN INC. AND SUBSIDIARIES									TELLURIAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS	CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS									CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per share amounts, unaudited)	(in thousands, except per share amounts, unaudited)									(in thousands, except per share amounts, unaudited)

		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Revenues:	Revenues:									Revenues:
Natural gas sales	Natural gas sales	$	81,103	$	15,638	$	168,442	$	29,922	Natural gas sales	$	31,987	$	61,350	$	82,922	$	87,339
LNG sales	LNG sales	—		—		120,951		19,776		LNG sales	—		—		—		120,951
Total revenues		81,103		15,638		289,393		49,698
Total revenue										Total revenue	31,987		61,350		82,922		208,290

Operating costs and expenses:	Operating costs and expenses:									Operating costs and expenses:
Operating expenses										Operating expenses	20,848		5,943		38,293		10,108
LNG cost of sales	LNG cost of sales	—		339		131,663		23,186		LNG cost of sales	—		—		—		131,663
Operating expenses		8,428		2,729		18,536		7,655
Development expenses	Development expenses	12,891		8,823		48,244		26,327		Development expenses	11,530		17,687		23,587		35,352
Depreciation, depletion and amortization	Depreciation, depletion and amortization	12,860		3,735		22,735		8,720		Depreciation, depletion and amortization	25,210		5,854		47,397		9,875
General and administrative expenses	General and administrative expenses	41,495		14,528		97,334		47,065		General and administrative expenses	31,290		23,514		63,540		55,839
Total operating costs and expenses	Total operating costs and expenses	75,674		30,154		318,512		112,953		Total operating costs and expenses	88,878		52,998		172,817		242,837
Income (loss) from operations		5,429		(14,516)		(29,119)		(63,255)

(Loss) income from operations										(Loss) income from operations	(56,891)		8,352		(89,895)		(34,547)

Interest expense, net	Interest expense, net	(6,944)		(968)		(13,790)		(7,689)		Interest expense, net	(4,182)		(4,566)		(8,192)		(6,846)
Gain on extinguishment of debt, net		—		—		—		1,422
Other expense, net		(12,718)		(448)		(37,966)		(3,993)
Loss on extinguishment of debt, net										Loss on extinguishment of debt, net	—		—		(2,822)		—
Other income (expense), net										Other income (expense), net	1,454		(3,821)		13,797		(25,249)

Loss before income taxes	Loss before income taxes	(14,233)		(15,932)		(80,875)		(73,515)		Loss before income taxes	(59,619)		(35)		(87,112)		(66,642)
Income tax	Income tax	—		—		—		—		Income tax	—		—		—		—
Net loss	Net loss	$	(14,233)	$	(15,932)	$	(80,875)	$	(73,515)	Net loss	$	(59,619)	$	(35)	$	(87,112)	$	(66,642)

Net loss per common share(1):	Net loss per common share(1):									Net loss per common share(1):
Basic and diluted	Basic and diluted	$	(0.03)	$	(0.04)	$	(0.15)	$	(0.19)	Basic and diluted	$	(0.11)	$	0.00	$	(0.16)	$	(0.13)

Weighted-average shares outstanding:	Weighted-average shares outstanding:									Weighted-average shares outstanding:
Basic and diluted	Basic and diluted	538,549		427,204		523,189		390,233		Basic and diluted	540,365		534,521		539,039		515,338

(1) The numerator for both basic and diluted loss per share is net loss. The denominator for both basic and diluted loss per share is the weighted-average shares outstanding during the period.	(1) The numerator for both basic and diluted loss per share is net loss. The denominator for both basic and diluted loss per share is the weighted-average shares outstanding during the period.									(1) The numerator for both basic and diluted loss per share is net loss. The denominator for both basic and diluted loss per share is the weighted-average shares outstanding during the period.

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.


TELLURIAN INC. AND SUBSIDIARIES	TELLURIAN INC. AND SUBSIDIARIES									TELLURIAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY	CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY									CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY
(in thousands, unaudited)	(in thousands, unaudited)									(in thousands, unaudited)

		Three Months Ended September 30,				Nine Months Ended September 30,									Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021							2023		2022		2023	2022
Total shareholders’ equity, beginning balance	Total shareholders’ equity, beginning balance	653,734		247,019		418,301		109,090		Total shareholders’ equity, beginning balance	$	645,543	$	524,655	$	672,543	$	418,301

Preferred stock	Preferred stock	61		61		61		61		Preferred stock	61		61		61		61

Common stock:	Common stock:									Common stock:
Beginning balance	Beginning balance	5,454		4,048		4,774		3,309		Beginning balance	5,458		5,229		5,456		4,774
Common stock issuances	Common stock issuances	—		428		677		1,066		Common stock issuances	101		223		101		677
Share-based compensation, net	Share-based compensation, net	1		1		3		42		Share-based compensation, net	1		2		3		2
Share-based payment	Share-based payment	1				2				Share-based payment	—		—		—		1
Warrant exercises		—		—		—		60

Ending balance	Ending balance	5,456		4,477		5,456		4,477		Ending balance	5,560		5,454		5,560		5,454

Additional paid-in capital:	Additional paid-in capital:									Additional paid-in capital:
Beginning balance	Beginning balance	1,645,920		1,116,815		1,344,526		922,042		Beginning balance	1,648,387		1,517,031		1,647,896		1,344,526
Common stock issuances	Common stock issuances	—		126,313		299,063		308,039		Common stock issuances	12,663		127,859		12,663		299,063
Share-based compensation, net	Share-based compensation, net	1,033		1,372		2,750		6,520		Share-based compensation, net	685		811		1,176		1,716

Share-based payments	Share-based payments	62		—		676		—		Share-based payments	—		219		—		616
Warrant exercises		—		—		—		8,117
Warrant cancellation		—		—		—		(218)

Ending balance	Ending balance	1,647,015		1,244,500		1,647,015		1,244,500		Ending balance	1,661,735		1,645,920		1,661,735		1,645,920

Accumulated deficit:	Accumulated deficit:									Accumulated deficit:
Beginning balance	Beginning balance	(997,701)		(873,905)		(931,059)		(816,322)		Beginning balance	(1,008,363)		(997,666)		(980,870)		(931,059)
Net loss	Net loss	(14,233)		(15,932)		(80,875)		(73,515)		Net loss	(59,619)		(35)		(87,112)		(66,642)
Ending balance	Ending balance	(1,011,934)		(889,837)		(1,011,934)		(889,837)		Ending balance	(1,067,982)		(997,701)		(1,067,982)		(997,701)

Total shareholders’ equity, ending balance	Total shareholders’ equity, ending balance	$	640,598	$	359,201	$	640,598	$	359,201	Total shareholders’ equity, ending balance	$	599,374	$	653,734	$	599,374	$	653,734

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.


TELLURIAN INC. AND SUBSIDIARIES	TELLURIAN INC. AND SUBSIDIARIES					TELLURIAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS	CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS					CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands, unaudited)	(in thousands, unaudited)					(in thousands, unaudited)

		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Cash flows from operating activities:	Cash flows from operating activities:					Cash flows from operating activities:
Net loss	Net loss	(80,875)		(73,515)		Net loss	$	(87,112)	$	(66,642)
Adjustments to reconcile net loss to net cash used in operating activities:
Adjustments to reconcile Net loss to Net cash provided by (used in) operating activities:						Adjustments to reconcile Net loss to Net cash provided by (used in) operating activities:
Depreciation, depletion and amortization	Depreciation, depletion and amortization	22,735		8,720		Depreciation, depletion and amortization	47,397		9,875
Amortization of debt issuance costs, discounts and fees	Amortization of debt issuance costs, discounts and fees	1,494		3,061		Amortization of debt issuance costs, discounts and fees	1,652		580
Share-based compensation	Share-based compensation	2,753		4,577		Share-based compensation	1,179		1,718

Share-based payments	Share-based payments	678		—		Share-based payments	—		616
Interest elected to be paid-in-kind		—		508
Loss on financial instruments not designated as hedges		13,553		927

Gain on extinguishment of debt, net		—		(1,422)
Net unrealized loss on financial instruments not designated as hedges						Net unrealized loss on financial instruments not designated as hedges	10,346		13,472
Loss on extinguishment of debt, net						Loss on extinguishment of debt, net	2,822		—
Other	Other	745		800		Other	2,142		555
Net changes in working capital (Note 15)	Net changes in working capital (Note 15)	(26,802)		17,174		Net changes in working capital (Note 15)	37,654		(43,672)
Net cash used in operating activities		(65,719)		(39,170)
Net cash provided by (used in) operating activities						Net cash provided by (used in) operating activities	16,080		(83,498)

Cash flows from investing activities:	Cash flows from investing activities:					Cash flows from investing activities:
Acquisition and development of natural gas properties		(236,558)		(23,416)
Development of natural gas properties						Development of natural gas properties	(95,231)		(66,500)
Driftwood Project construction costs	Driftwood Project construction costs	(117,793)		—		Driftwood Project construction costs	(112,565)		(68,725)
Land purchases and land improvements	Land purchases and land improvements	(19,412)		(1,000)		Land purchases and land improvements	—		(17,425)
Investments in unconsolidated entities		(11,089)		—
Other		(1,278)		—
Investment in unconsolidated entity						Investment in unconsolidated entity	—		(6,089)
Note receivable						Note receivable	(18,000)		—
Capitalized internal use software and other assets						Capitalized internal use software and other assets	(3,530)		—
Net cash used in investing activities	Net cash used in investing activities	(386,130)		(24,416)		Net cash used in investing activities	(229,326)		(158,739)

Cash flows from financing activities:	Cash flows from financing activities:					Cash flows from financing activities:
Proceeds from common stock issuances	Proceeds from common stock issuances	309,021		319,998		Proceeds from common stock issuances	13,163		309,021
Equity issuance costs	Equity issuance costs	(9,281)		(10,893)		Equity issuance costs	(399)		(9,281)
Borrowing proceeds	Borrowing proceeds	501,178		—		Borrowing proceeds	—		501,178
Borrowing issuance costs	Borrowing issuance costs	(11,487)		—		Borrowing issuance costs	—		(11,488)
Borrowing principal repayments	Borrowing principal repayments	—		(119,725)		Borrowing principal repayments	(166,666)		—
Tax payments for net share settlement of equity awards (Note 15)		—		(3,064)
Proceeds from warrant exercises		—		8,177
Other	Other	(98)		(1,833)		Other	(344)		(3,063)
Net cash provided by financing activities		789,333		192,660
Net cash (used in) provided by financing activities						Net cash (used in) provided by financing activities	(154,246)		786,367

Net increase in cash, cash equivalents and restricted cash		337,484		129,074
Net (decrease) increase in cash, cash equivalents and restricted cash						Net (decrease) increase in cash, cash equivalents and restricted cash	(367,492)		544,130
Cash, cash equivalents and restricted cash, beginning of period	Cash, cash equivalents and restricted cash, beginning of period	307,274		81,738		Cash, cash equivalents and restricted cash, beginning of period	508,468		307,274
Cash, cash equivalents and restricted cash, end of period	Cash, cash equivalents and restricted cash, end of period	$	644,758	$	210,812	Cash, cash equivalents and restricted cash, end of period	$	140,976	$	851,404

Supplementary disclosure of cash flow information:	Supplementary disclosure of cash flow information:					Supplementary disclosure of cash flow information:
Interest paid		$	11,152	$	3,299
Interest paid, net of capitalized interest						Interest paid, net of capitalized interest	$	13,681	$	4,928

The accompanying notes are an integral part of these Condensed Consolidated Financial Statements.

Tellurian Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements (unaudited)

NOTE 1 — GENERAL

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.

~~Nature of Operations~~

Tellurian is developing and plans to own and operate 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.”

Basis of Presentation

The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the ~~consolidated financial statements~~Consolidated Financial Statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, ~~2021.~~2022. The Condensed Consolidated Financial Statements, in the opinion of management, reflect all adjustments necessary for the fair presentation of the results for the periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

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.

To conform with GAAP, we make estimates and assumptions that affect the amounts reported in our Condensed Consolidated Financial Statements and the accompanying notes. Although these estimates and assumptions are based on our best available knowledge at the time, actual results may differ.

Liquidity

Our Condensed 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 Condensed Consolidated Financial Statements, we have historically 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 Condensed Consolidated Financial Statements.

~~The Company has sufficient~~We are planning to meet our liquidity needs from cash on hand and ~~available~~the combined proceeds generated by our Upstream operations and the sale of common stock under our at-the-market equity offering program. On August 8, 2023, we entered into a private placement securities purchase agreement (the “SPA”) with an institutional investor to refinance the Company’s existing convertible notes. See Note 17, Subsequent Events, for additional information. The SPA is expected to close in the near future, subject to the satisfaction of customary closing conditions. We have determined that it is probable that the closing of the SPA will occur and that such sources of liquidity towill satisfy ~~its~~our obligations, ~~and~~ fund ~~its~~ working capital needs and allow us to remain compliant with our debt covenants for at least twelve months following the ~~date of~~ issuance of the ~~Condensed Consolidated Financial Statements. The Company has the ability~~financial statements.

We also continue to ~~generate~~evaluate generating additional proceeds from various other potential financing ~~transactions.~~transactions, such as issuances of equity, equity-linked and debt securities, or similar transactions to fund our obligations and working capital needs. We ~~are currently~~remain focused on the financing and construction of the Driftwood ~~terminal~~Project while managing our marketing & trading operations and ~~continuing to expand our~~ upstream ~~activities.~~assets.

NOTE 2 — PREPAID EXPENSES AND OTHER CURRENT ASSETS

Prepaid expenses and other current assets consist of the following (in thousands):


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
Prepaid expenses	Prepaid expenses	$	349	$	605	Prepaid expenses	$	1,957	$	2,174
Deposits	Deposits	18,640		3,589		Deposits	273		172
Restricted cash	Restricted cash	12,375		—		Restricted cash	9,375		9,375
Derivative assets, net current		—		8,693
Derivative asset, net current (Note 5)						Derivative asset, net current (Note 5)	—		10,463
Other current assets	Other current assets	93		65		Other current assets	6,095		1,171
Total prepaid expenses and other current assets	Total prepaid expenses and other current assets	$	31,457	$	12,952	Total prepaid expenses and other current assets	$	17,700	$	23,355

~~Deposits~~

Margin deposits posted with a third-party financial institution related to our financial instrument contracts were approximately $17.4 million and $2.1 million as of September 30, 2022 and December 31, 2021, respectively.

Restricted Cash

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

Restricted cash as of ~~September~~June 30, 2023 and December 31, 2022 consists of ~~$3.0 million held in escrow under the terms of an agreement to purchase land for the Driftwood Project as well as~~ approximately $9.4 million held in escrow under the terms of the purchase and sale agreement for the acquisition of certain natural gas assets in the Haynesville Shale. ~~See Note 3,~~ ~~Property, Plant and Equipment, for further information.~~

NOTE 3 — PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment, net consist of the following (in thousands):


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
Upstream natural gas assets:	Upstream natural gas assets:					Upstream natural gas assets:
Proved properties	Proved properties	$	299,589	$	96,297	Proved properties	$	489,608	$	412,977
Wells in progress	Wells in progress	91,759		17,653		Wells in progress	66,071		55,374
Accumulated DD&A	Accumulated DD&A	(70,997)		(48,638)		Accumulated DD&A	(138,177)		(92,423)
Total upstream natural gas assets, net	Total upstream natural gas assets, net	320,351		65,312		Total upstream natural gas assets, net	417,502		375,928

Driftwood Project assets:	Driftwood Project assets:					Driftwood Project assets:
Terminal construction in progress						Terminal construction in progress	414,625		292,734
Pipeline construction in progress						Pipeline construction in progress	21,071		—
Land and land improvements	Land and land improvements	49,086		25,222		Land and land improvements	53,664		52,460
Driftwood terminal construction in progress		238,830		—
Finance lease assets, net of accumulated DD&A	Finance lease assets, net of accumulated DD&A	57,002		57,883		Finance lease assets, net of accumulated DD&A	56,121		56,708
Buildings and other assets, net of accumulated DD&A	Buildings and other assets, net of accumulated DD&A	348		371		Buildings and other assets, net of accumulated DD&A	325		340
Total Driftwood Project, net		345,266		83,476
Total Driftwood Project assets, net						Total Driftwood Project assets, net	545,806		402,242

Fixed assets and other:	Fixed assets and other:					Fixed assets and other:
Finance lease assets, net of accumulated DD&A						Finance lease assets, net of accumulated DD&A	71,939		—
Leasehold improvements and other assets	Leasehold improvements and other assets	6,924		3,104		Leasehold improvements and other assets	16,867		12,672
Accumulated DD&A	Accumulated DD&A	(1,628)		(1,347)		Accumulated DD&A	(3,234)		(1,766)
Total fixed assets and other, net	Total fixed assets and other, net	5,296		1,757		Total fixed assets and other, net	85,572		10,906

Total property, plant and equipment, net	Total property, plant and equipment, net	$	670,913	$	150,545	Total property, plant and equipment, net	$	1,048,880	$	789,076

~~Land~~

~~We own land in Louisiana intended for the construction of the Driftwood Project.~~

~~Driftwood~~ Terminal Construction in Progress

During the year ended December 31, 2021, the Company initiated certain owner construction activities necessary to proceed under our LSTK EPC agreement with Bechtel Energy Inc., formerly known as Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”), for Phase 1 of the Driftwood terminal dated as of November 10, 2017 (the “Phase 1 EPC Agreement”). On March 24, 2022, the Company issued a limited notice to proceed to Bechtel under the Phase 1 EPC Agreement and commenced construction of Phase 1 of the Driftwood terminal on April 4, 2022. As the Company commenced construction activities, Deferred engineering costs and Permitting Costs of approximately $110.0 million and $13.4 million, respectively, were transferred to construction in progress as of March 31, 2022. During the ninesix months ended ~~September~~June 30, ~~2022,~~2023, we capitalized approximately ~~$115.4~~$121.9 million of directly identifiable project costs as Driftwood terminal construction in progress.

~~Asset Acquisition~~Pipeline Construction in Progress

On ~~August 18, 2022,~~April 21, 2023, the Company completed the acquisition of certain natural gas assets in the Haynesville Shale basin. The purchase price of $125.0 million was subject to adjustments of approximately $9.9 million, for an adjusted purchase price at closing of approximately $134.9 million. The sellers may receive an additional cash payment of $7.5 million if the average NYMEX Henry Hub Gas Pricereceived FERC approval for the ~~contract delivery months beginning with August 2022 through March 2023 exceeds a specific threshold per MmBtu (the “Contingent Consideration”). See Note 6,~~ ~~Financial Instruments, for further information.~~

~~NOTE 4 — DEFERRED ENGINEERING COSTS~~

~~Deferred engineering costs related to the planned~~ construction of the Driftwood ~~terminal~~pipelines. During the second quarter of 2023, pipeline materials and rights of way of approximately $14.6 million were transferred to construction in progress ~~upon issuing~~in accordance with our accounting policies. During the ~~limited notice to proceed to Bechtel~~three months ended June 30, 2023, we also capitalized approximately $6.4 million of directly identifiable project costs as Pipeline construction in ~~March 2022. See Note 3,~~ ~~Property, Plant and Equipment, for further information.~~

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

progress.

NOTE 54 — OTHER NON-CURRENT ASSETS

Other non-current assets consist of the following (in thousands):


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
Land lease and purchase options	Land lease and purchase options	$	795	$	6,368	Land lease and purchase options	$	8	$	300
Permitting costs	Permitting costs	—		13,408		Permitting costs	—		916
Right of use asset — operating leases	Right of use asset — operating leases	13,932		10,166		Right of use asset — operating leases	14,477		13,303
Restricted cash	Restricted cash	24,885		1,778		Restricted cash	24,895		24,888
Investments in unconsolidated entities		11,089		—
Driftwood pipeline materials		5,229		—
Investment in unconsolidated entity						Investment in unconsolidated entity	6,089		6,089
Note receivable						Note receivable	24,189		6,595
Pipeline materials and rights of way						Pipeline materials and rights of way	—		9,136
Other	Other	1,875		1,798		Other	1,575		2,089
Total other non-current assets	Total other non-current assets	$	57,805	$	33,518	Total other non-current assets	$	71,233	$	63,316

~~Land Lease and Purchase Options~~

During the first quarter of 2022, we exercised the final land purchase options related to the Driftwood terminal. Land purchase options held by the Company as of September 30, 2022 are related to the Driftwood pipeline and other related pipelines.

~~Permitting Costs~~

Permitting costs primarily represented the purchase of wetland credits in connection with our permit application to the USACE in 2017 and 2018. These wetland credits were transferred to construction in progress upon issuing the limited notice to proceed to Bechtel in March 2022. See Note 3,

~~Property, Plant and Equipment~~
, for further information. 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 potential impact to Louisiana wetlands that might be caused by the construction of the Driftwood Project.

Restricted Cash

Restricted cash as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021,~~2022 represents ~~the~~ cash collateralization of ~~letters~~a letter of credit associated with a finance ~~leases.~~

lease.

~~Investments in unconsolidated entities~~Note Receivable

OnIn February ~~24, 2022,~~2023, the Company ~~purchased 1.5 million ordinary shares of~~issued an unaffiliated entity that provides renewable energy services for a total cost of approximately $6.1 million. This investment does not provide the Company with a controlling financial interest in or significant influence over the operating or financial decisions of the unaffiliated entity. The Company’s investment was recorded at cost.

~~The Company issued a $5.0 million~~amended and restated promissory note due June 14, ~~2024~~2031 (the ~~“Promissory Note”~~“Note Receivable”) to an unaffiliated entity ~~(“Borrower”)~~ engaged in the development of infrastructure projects in the energy industry. The ~~Promissory~~outstanding principal balance of the Note Receivable as of June 30, 2023 was approximately $24.2 million. The promissory note bears interest at a rate of 6.00%, which ~~will be~~is capitalized into the outstanding principal balance annually.

Pipeline materials and rights of way

Pipeline materials and rights of way were transferred to construction in progress as of June 30, 2023. See Note 3 Property, Plant and Equipment.

NOTE 65 — FINANCIAL INSTRUMENTS

Natural Gas Financial Instruments

The primary purpose of our commodity risk management activities is to hedge our exposure to cash flow variability from commodity price risk due to fluctuations in commodity prices. The Company uses natural gas financial futures and option contracts to economically hedge the commodity price risks associated with a portion of our expected natural gas production. ~~The Company’s~~As of June 30, 2023, there were no open ~~positions as of September 30, 2022, had notional volumes of approximately 14.7 Bcf, with maturities extending through October 2023.~~natural gas financial instrument positions.

LNG Financial ~~Instruments~~Futures

During the ~~three~~ ~~months~~year ended December 31, 2021, we entered into LNG financial futures contracts to reduce our exposure to commodity price fluctuations and to achieve more predictable cash flows relative to two LNG cargos that we were committed to purchase from and sell to unrelated third-party LNG merchants in the normal course of business in January and April 2022. As of ~~September~~June 30, ~~2022,~~2023, there were no open LNG financial instrument positions.

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

Contingent Consideration

~~The purchase price~~On August 18, 2022, the Company completed the acquisition of certain natural gas assets ~~acquired~~ in the Haynesville Shale basin ~~includes Contingent Consideration~~(the “Asset Acquisition”). The Asset Acquisition included cash consideration payable to the sellers of $7.5 million (the “Contingent Consideration”) if ~~natural~~the average NYMEX Henry Hub gas ~~commodity prices exceed~~price for the contract delivery months beginning with August 2022 through March 2023 exceeded a specific threshold ~~refer~~(the “Threshold”) per MMBtu. The Threshold was not met and, therefore, the Company is not obligated to ~~Note 3,~~ ~~Property, Plant and Equipment~~, for further information. The Contingent Consideration was determined to be an embedded derivative that is recorded at fair value in the Condensed Consolidated Balance Sheets. As of the date of the acquisition, the fair value ofpay the Contingent Consideration was approximately $3.9 million, which was recorded as part of the basis in proved natural gas properties with a corresponding embedded derivative liability. Changes in the fair value of the Contingent Consideration are recognized in the period they occur and included within Other expense, net on the Condensed Consolidated Statements of Operations.Consideration.

The following table summarizes the effect of the Company’s financial instruments ~~which are included within Other expense, net~~ on the Condensed Consolidated Statements of Operations (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Natural gas financial instruments:
Realized gain (loss)	$	11,444	$	(10,536)	$	23,310	$	(11,251)
Unrealized (loss) gain	(10,891)		6,790		(10,463)		(8,311)
LNG financial futures:
Realized gain	—		—		—		3,532
Unrealized loss	—		—		—		5,161
Contingent Consideration:
Realized gain	—		—		118		—

Three Months Ended September 30, Nine Months Ended September 30,
2022 2021 2022 2021
Natural gas financial instruments:
Realized loss $ 12,547 $ — $ 23,798 $ 1,202
Unrealized loss 390 — 8,701 —
LNG financial futures contracts:
Realized gain — — 3,532 —
Unrealized loss — — 5,161 —
Contingent Consideration
Unrealized gain 309 — 309 —

The following table presents the classification of the Company’s financial ~~instruments~~derivative assets and liabilities that are required to be measured at fair value on a recurring basis on the Company’s Condensed Consolidated Balance Sheets (in thousands):


	~~September~~June 30, ~~2022~~2023		December 31, ~~2021~~2022
Current ~~assets:~~
~~LNG financial futures contracts~~	$	—	$	~~8,693~~
~~Non-current~~ assets:
Natural gas financial instruments	~~685~~$	—	$	10,463
LNG financial futures	—		—
Current liabilities:
~~Natural gas financial instruments~~Contingent Consideration	~~9,386~~		—
~~Contingent Consideration~~	~~3,579~~		—118

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.

NOTE 6 — RELATED PARTY TRANSACTIONS

Related Party Contractor Service Fees and Expenses

The ~~fair value~~Company entered into a one-year independent contractor agreement, effective January 1, 2022, with Mr. Martin Houston, the Vice Chairman of the ~~Contingent Consideration was determined using Monte Carlo simulations including inputs such as quoted future natural gas price curves, natural gas price volatility,~~Company’s Board of Directors. Pursuant to the terms and ~~discount rates. These inputs are substantially observable in active markets throughout~~conditions of this agreement, the ~~full term~~Company paid Mr. Houston a monthly fee of $50.0 thousand plus approved expenses. In December 2022, the Company amended the independent contractor agreement to expire on the earlier of (i) termination of Mr. Houston and (ii) December 31, 2023, and to increase the monthly fee to $55.0 thousand plus approved expenses. For the three and six months ended June 30, 2023, the Company paid Mr. Houston $220.0 thousand and $330.0 thousand, respectively, for contractor service fees and expenses. For each of the ~~Contingent Consideration arrangement~~three and ~~are therefore designated as Level 2 within~~six months ended June 30, 2022, the ~~valuation hierarchy.~~Company paid Mr. Houston $325.0 thousand for contractor service fees and expenses. As of June 30, 2023 and 2022, there were no amounts owed to Mr. Houston.

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

NOTE 7 — ACCRUED AND OTHER LIABILITIES

Accrued and other liabilities consist of the following (in thousands):


		September 30, 2022		December 31, 2021			June 30, 2023		December 31, 2022
Upstream accrued liabilities	Upstream accrued liabilities	$	90,942	$	26,421	Upstream accrued liabilities	$	39,696	$	71,977

Payroll and compensation	Payroll and compensation	24,937		50,243		Payroll and compensation	20,367		37,329
Accrued taxes	Accrued taxes	396		991		Accrued taxes	909		730
Driftwood Project and related pipelines development activities		5,815		435
Driftwood Project development activities						Driftwood Project development activities	6,162		4,423
Lease liabilities	Lease liabilities	2,708		2,279		Lease liabilities	4,310		2,875
Current natural gas derivative liabilities		9,386		—
Accrued interest	Accrued interest	5,793		660		Accrued interest	4,126		5,793
Other	Other	9,897		4,917		Other	8,238		6,053
Total accrued and other liabilities	Total accrued and other liabilities	$	149,874	$	85,946	Total accrued and other liabilities	$	83,808	$	129,180

NOTE 8 — BORROWINGS

The Company’s borrowings consist of the following (in thousands):


		September 30, 2022							June 30, 2023
		Principal repayment obligation		Unamortized DFC		Carrying value			Principal repayment obligation		Unamortized DFC		Carrying value
Senior Secured Convertible Notes, current	Senior Secured Convertible Notes, current	$	166,666	$	(3,392)	$	163,274	Senior Secured Convertible Notes, current	$	—	$	—	$	—
Senior Secured Convertible Notes, non-current	Senior Secured Convertible Notes, non-current	333,334		(6,785)		326,549		Senior Secured Convertible Notes, non-current	333,334		(5,024)		328,310
Senior Notes due 2028	Senior Notes due 2028	57,678		(2,666)		55,012		Senior Notes due 2028	57,678		(2,417)		55,261
Total borrowings	Total borrowings	$	557,678	$	(12,843)	$	544,835	Total borrowings	$	391,012	$	(7,441)	$	383,571

December 31, 2021
Principal repayment obligation Unamortized DFC Carrying value
Senior Notes due 2028 $ 56,500 $ (2,813) $ 53,687
Total borrowings $ 56,500 $ (2,813) $ 53,687


	December 31, 2022
	Principal repayment obligation		Unamortized DFC		Carrying value
Senior Secured Convertible Notes, current	$	166,666	$	(3,110)	$	163,556
Senior Secured Convertible Notes, non-current	333,334		(6,219)		327,115
Senior Notes due 2028	57,678		(2,585)		55,093
Total borrowings	$	557,678	$	(11,914)	$	545,764

Amortization of the Company’s DFC is a component of Interest expense, net in the Company’s Condensed Consolidated Statements of Operations. The Company amortized approximately $0.7 million and $1.7 million during the three and six months ended June 30, 2023, respectively. For each of the three and six months ended June 30, 2022, the Company amortized approximately $0.6 million.

Senior Secured Convertible Notes due 2025

On June 3, 2022, we issued and sold $500.0 million aggregate principal amount of 6.00% Senior Secured Convertible Notes due May 1, 2025 (the “Convertible Notes” or the “Notes”). Net proceeds from the Convertible Notes were approximately $488.7 million after deducting fees and expenses. The Convertible Notes have quarterly interest payments due on February 1, May 1, August 1, and November 1 of each year and on the maturity date. Debt issuance costs of approximately $11.5 million were capitalized and are being amortized over the full term of the Notes using the effective interest rate method.

The holders of the Convertible Notes have the right to convert the Notes into shares of our common stock at an initial conversion rate of 174.703 shares per $1,000 principal amount of Notes (equivalent to a conversion price of approximately $5.724 per share of common stock) (the “Conversion Price”), subject to adjustment in certain circumstances. Holders of the Convertible Notes may force the Company to redeem the Notes for cash upon (i) a fundamental change or (ii) an event of default.

The Company will force the holders of the Convertible Notes to convert all of the Notes if the trading price of our common stock closes above 200% of the Conversion Price for 20 consecutive trading days and certain other conditions are satisfied. The Company may provide written notice to each holder of the Notes calling all of such holder’s Notes for a cash purchase price equal to 120% of the principal amount being redeemed, plus accrued and unpaid interest (the “Optional Redemption”), and each holder will have the right to accept or reject such Optional Redemption.

On each of May 1, 2023 and May 1, 2024, the holders of the Convertible Notes may redeem up to ~~$166.6~~$166.7 million of the initial principal amount of the Notes at par, plus accrued and unpaid interest (the “Redemption Amount”). ~~The~~On March 27, 2023, the holders of the Convertible Notes delivered to the Company ~~classified~~notice to redeem $166.7 million of the ~~potential~~initial principal amount of the Notes at par, plus accrued interest (the “Redemption Amount”). On March 28, 2023, the Company irrevocably deposited the Redemption Amount of approximately $169.1 million in ~~respect~~order to satisfy the redemption and retirement of ~~May 1, 2023 as~~$166.7 million principal amount of the Convertible Notes, plus accrued interest. As a ~~current borrowing~~result of the Company’s payment of the Redemption Amount prior to the Convertible Notes’ contractual maturity, the Company wrote off approximately $2.8 million of prorated unamortized debt issuance costs, which was recognized within Loss on ~~the~~extinguishment of debt, net, in our Condensed Consolidated ~~Balance Sheet as~~Statements of ~~September 30, 2022.~~

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

Operations.

Our borrowing obligations under the Convertible Notes are collateralized by a first priority lien on the Company’s equity interests in Tellurian Production Holdings LLC (“Tellurian Production Holdings”), a wholly owned subsidiary of Tellurian Inc. Tellurian Production Holdings owns all of the Company’s upstream natural gas assets described in Note 3, Property, Plant and Equipment. Upon the Company’s compliance with its obligations in respect of an Optional Redemption (regardless of whether holders accept or reject the redemption), the lien on the equity interests in Tellurian Production Holdings will be automatically released. The Notes contain a minimum cash ~~balance requirement~~covenant of $100.0 million and non-financial covenants. The Company and the holders of the Convertible Notes entered into supplemental indentures in June, July and August 2023, which decreased the minimum cash covenant from $100.0 million to $60.0 million during the period from June 16, 2023 to August 18, 2023. As of ~~September~~June 30, ~~2022,~~2023, we remained in compliance with ~~the minimum cash balance requirement and~~ all ~~other~~ covenants under the Notes. See Note 17, Subsequent Events, for further information.

As of ~~September~~June 30, ~~2022,~~2023, the estimated fair value of the Convertible Notes was approximately ~~$453.3~~$289.4 million. The Level 3 fair value was estimated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and inputs that are not observable in the market.

Senior 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. As of ~~September~~June 30, ~~2022,~~2023, the Company was in compliance with all covenants under the indenture governing the Senior Notes. The Senior Notes are ~~traded~~listed and trade on the NYSE American under the symbol “TELZ,” and are classified as Level 1 within the fair value hierarchy. As of ~~September~~June 30, ~~2022,~~2023, the closing market price was ~~$18.28~~$17.39 per Senior Note.

At-the-Market Debt Offering Program

On December 17, 2021, we entered into an at-the-market debt offering program under which the Company may offer and sell, from time to time on the NYSE American, up to an aggregate principal amount of $200.0 million of additional Senior Notes. ~~For~~During the ~~nine~~six months ended ~~September~~June 30, 2022, we sold approximately $1.2 million aggregate principal amount of additional Senior Notes for total proceeds of approximately $1.1 million after fees and commissions under our at-the-market debt offering program. ~~The Company has not sold any Senior Notes under~~On December 30, 2022, we terminated the at-the-market debt offering ~~program since January 2022 and is restricted from doing so under an agreement entered into in connection with the issuance of the Convertible Notes.~~program.

~~Extinguishment of the 2019 Term Loan~~

On May 23, 2019, Driftwood Holdings LP, 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 March 12, 2021, we finalized a voluntary repayment of the remaining outstanding principal balance of the 2019 Term Loan. A total of approximately $43.7 million was repaid to the lender during the first quarter of 2021 to satisfy the outstanding borrowing obligation. 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 Condensed Consolidated Statements of Operations.

~~2018 Term Loan~~

On September 28, 2018, Tellurian Production Holdings 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 February 18, 2021, we voluntarily repaid approximately $43.0 million of the 2018 Term Loan outstanding principal balance. Then, on April 23, 2021, we voluntarily repaid the remaining outstanding principal balance of $17.0 million.

These voluntary repayments resulted in losses of approximately $0.7 million for the nine months ended September 30, 2021, which were recognized within Gain on extinguishment of debt, net, on our Condensed Consolidated Statements of Operations.NOTE 9 — COMMITMENTS AND CONTINGENCIES

Trade Finance Credit Line

On July 19, 2021, we entered into an uncommitted trade finance credit line for up to $30.0 million that is intended to finance the purchase of LNG cargos for ultimate resale in the normal course of business. On December 7, 2021, the uncommitted trade finance credit line was amended and increased to $150.0 million. As of ~~September~~June 30, ~~2022,~~2023, no amounts were drawn under this credit line.

Minimum Volume Commitments

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

~~NOTE 9 — COMMITMENTS AND CONTINGENCIES~~

~~Related Party Contractor Service Fees and Expenses~~

The Company ~~entered into~~is expected to be subject to gas gathering commitments in the near-term with unrelated companies that are constructing gathering systems in the Haynesville Shale. Upon the in-service date of these gathering systems, the Company will have dedicated gathering capacity from a ~~one-year independent contractor agreement, effective January 1, 2022, with Mr. Martin Houston, who serves as Vice Chairman and a member~~portion of the ~~Company’s Board of Directors. Pursuant~~Upstream segment’s future natural gas production. The gas gathering agreements will require us to make deficiency payments to the ~~terms and conditions of this agreement,~~extent the Company ~~pays Mr. Houston a monthly fee~~does not meet the minimum volume commitments per the terms of ~~$50.0 thousand plus approved expenses. For the three and nine months ended September 30, 2022, the Company paid Mr. Houston $150.0 thousand and $475.0 thousand, respectively, for contractor service fees and expenses.~~each contract. As of ~~September~~June 30, ~~2022, there~~2023, we were ~~no balances due~~not subject to ~~Mr. Houston.~~any material volume delivery commitments.

NOTE 10 — 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. During the ~~nine~~six months ended ~~September~~June 30, 2022, we issued 67.7 million shares of our common stock under our at-the-market equity offering programs for net proceeds of approximately $299.7 million. ~~As of September~~On December 30, 2022, we ~~had remaining availability under such~~terminated the Company’s then-existing at-the-market ~~programs~~equity offering programs.

On December 30, 2022, we entered into a new at-the-market equity offering program pursuant to ~~raise~~which the Company may sell shares of its common stock from time to time on the NYSE American for aggregate ~~gross~~ sales proceeds of up to ~~approximately $323.7~~$500.0 million. ~~The Company has not sold any common stock under the at-the-market equity offering programs since April 2022.~~

~~Common Stock Purchase Warrants~~

~~2019 Term Loan~~

During ~~the first quarter of 2021, the lender~~each of the ~~2019 Term Loan exercised warrants to purchase approximately 6.0~~three and six months ended June 30, 2023, we issued 10.1 million shares of our common stock under our at-the-market equity offering program for ~~total~~net proceeds of approximately ~~$8.2~~$12.8 million. ~~As discussed in~~See Note 8,17, ~~Borrowings~~Subsequent Events, ~~the 2019 Term Loan has been repaid in full and the lender no longer holds any warrants.~~for further information.

Preferred Stock

In March 2018, we entered into a preferred stock purchase agreement with BDC Oil and Gas Holdings, LLC (“Bechtel Holdings”), a Delaware limited liability company and an affiliate of Bechtel Energy Inc., pursuant to which we sold to Bechtel Holdings approximately 6.1 million shares of our Series C convertible preferred stock (the “Preferred Stock”).

The holders of the Preferred Stock do not have dividend rights but do have a liquidation preference over holders of our common stock. The holders of the Preferred Stock may convert all or any portion of their shares into shares of our common stock on a one-for-one basis. At any time after “Substantial Completion” of “Project 1,” each as defined in and pursuant to the LSTK EPC Agreement for the Driftwood LNG Phase 1 ~~EPC Agreement,~~Liquefaction Facility, dated as of November 10, 2017, or at any time after March 21, 2028, we have the right to cause all of the Preferred Stock to be converted into shares of our common stock on a one-for-one basis. The Preferred Stock has been excluded from the computation of diluted loss per share because including it in the computation would have been antidilutive for the periods presented.

NOTE 11 — 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 ~~(collectively, the “grantees”)~~ 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 ~~granted~~made under the Legacy Plan.

Upon the vesting of restricted stock, shares of common stock will be released to the grantee. Upon the vesting of restricted stock units, the units will be converted into either cash, stock, or a combination thereof. As of ~~September~~June 30, ~~2022,~~2023, there was no Restricted Stock that would be required to be settled in cash.

As of ~~September~~June 30, ~~2022,~~2023, we had approximately ~~28.0~~26.5 million shares of primarily performance-based Restricted Stock outstanding, of which approximately ~~15.9~~15.0 million shares will vest entirely at FID, as defined in the award agreements, and approximately ~~11.2~~11.0 million shares will vest in one-third increments at FID and the first and second anniversaries of FID. The remaining shares of primarily performance-based Restricted Stock, totaling approximately ~~0.9~~0.5 million shares, will vest based on other criteria. As of ~~September~~June 30, ~~2022,~~2023, no expense had been recognized in connection with performance-based Restricted Stock.

For the three and nine months ended September 30, 2022, the recognized share-based compensation expenses related to all share-based awards totaled approximately $1.0 million and $2.8 million, respectively. As of ~~September~~June 30, ~~2022,~~2023, unrecognized compensation expenses, based on the grant date fair value, for all share-based awards totaled approximately ~~$184.3~~$174.5 million. Further, approximately ~~27.7~~26.5 million shares of primarily performance-based Restricted Stock, as well as

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

approximately ~~11.1~~10.9 million stock options outstanding, 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 Company recognized share-based compensation expenses as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
Share-based compensation expense	$	686	$	813	$	1,179	$	1,718

NOTE 12 — 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.~~employees. ICP awards may be earned with respect to each calendar year and are determined based on guidelines established by the Compensation Committee of the Company’s Board of ~~Directors, as administrator of the ICP.~~

Directors.

Long-term incentive awards

Long-term incentive (“LTI”) awards under the ICP were granted in January 2022 in the form of “tracking units,” at the discretion of the Compensation Committee of the Company’s Board of Directors (the “2021 LTI ~~Award”~~Awards”). Each such tracking unit has a value equal to one share of Tellurian common stock and entitles the grantee to receive, upon vesting, a cash payment equal to the closing price of our common stock on the trading day prior to the vesting date. These tracking units will vest in three equal tranches at the grant date and the first and second anniversaries of the grant date. Non-vested ~~tracking unit awards~~2021 LTI Awards as of ~~September~~June 30, ~~2022,~~2023 and awards granted during the period were as follows:


		Number of Tracking Units (in thousands)	Price per Tracking Unit			Number of Tracking Units (in thousands)	Price per Tracking Unit
Balance at January 1, 2022		—	—
Balance at January 1, 2023					Balance at January 1, 2023	12,719	$	1.68
Granted	Granted	19,332	$	3.09	Granted	—	—
Vested	Vested	(6,444)	3.38		Vested	(6,359)	2.13
Forfeited	Forfeited	(159)	3.46		Forfeited	(327)	1.49
Unvested balance at September 30, 2022		12,729	$	2.39
Unvested balance at June 30, 2023					Unvested balance at June 30, 2023	6,033	$	1.41

LTI awards under the ICP were granted in February 2023 in the form of “tracking units,” at the discretion of the Compensation Committee of the Company’s Board of Directors (the “2022 LTI Awards”). Each such tracking unit has a value equal to one share of Tellurian common stock and entitles the grantee to receive, upon vesting, a cash payment equal to the closing price of our common stock on the trading day prior to the vesting date. These tracking units will vest in three equal tranches at the grant date and the first and second anniversaries of the grant date.

Non-vested 2022 LTI Awards as of June 30, 2023 and awards granted during the period were as follows:


	Number of Tracking Units (in thousands)	Price per Tracking Unit
Balance at January 1, 2023	—	—
Granted	14,789	$	2.10
Vested	(4,930)	1.63
Forfeited	(444)	1.47
Unvested balance at June 30, 2023	9,415	$	1.41

We recognize compensation expense for awards with graded vesting schedules over the requisite service periods for each separately vesting portion of the award as if each award was in substance multiple awards. Compensation expense for the first tranche of the 2021 LTI ~~Award~~Awards and the 2022 LTI Awards that vested at the grant date was recognized over the performance period when it was probable that the performance condition was achieved. Compensation expense for the second and third tranches of the 2021 LTI ~~Award~~Awards and the 2022 LTI Awards is 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 changes in the Company’s stock price and actual forfeitures. ~~For the three and nine months ended September 30, 2022, we~~

The Company recognized ~~approximately $2.8 million and $17.1 million, respectively, in~~ compensation expense ~~for~~related to the second and third tranches of the 2021 LTI ~~Award.~~Awards and the 2022 LTI Awards as follows (in thousands):


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
2022 LTI Awards	$	2,801	$	—	$	4,979	$	—
2021 LTI Awards	1,739		1,563		1,038		14,280

NOTE 13 — INCOME TAXES

Due to our cumulative loss position, historical net operating losses (“NOLs”), and other available evidence related to our ability to generate taxable income, we have recorded a full valuation allowance against our net deferred tax assets as of ~~September~~June 30, ~~2022~~2023 and December 31, ~~2021.~~2022. Accordingly, we have not recorded a provision for federal, state or foreign income taxes during the three and ~~nine~~six months ended ~~September~~June 30, ~~2022.~~

2023.

We experienced ownership changes as defined by Internal Revenue Code (“IRC”) Section 382 in 2017, and an analysis of the annual limitation on the utilization of our NOLs was performed at that time. It was determined that IRC Section 382 will not limit the use of our NOLs over the carryover period. We will continue to monitor trading activity in our shares that may cause an additional ownership change, which may ultimately affect our ability to fully utilize our existing NOL carryforwards.

NOTE 14 — LEASES

Our Driftwood Project land leases are classified as finance leases and include one or more options to extend the lease term for up to 40 years, as well as to terminate the lease within five years, at our sole discretion. We are reasonably certain that those options will be exercised and that our termination rights will not be exercised, and we have, therefore, included those assumptions within our right of use assets and corresponding lease liabilities. Our other land leases are classified as finance leases and include one or more options to extend the lease term for up to 69 years or to terminate the lease within seven years, at our sole discretion. We are reasonably certain that those options and termination rights will not be exercised, and we have, therefore, excluded those assumptions within our right of use assets and corresponding lease liabilities.

Our office space leases are classified as operating leases and include one or more options to extend the lease term up to 10 years, at our sole discretion. As we are not reasonably certain that those

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

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 Condensed Consolidated Balance Sheets (in thousands):


Leases	Leases	Consolidated Balance Sheets Classification	September 30, 2022		December 31, 2021		Leases	Condensed Consolidated Balance Sheets Classification	June 30, 2023		December 31, 2022
Right of use asset	Right of use asset						Right of use asset
Operating	Operating	Other non-current assets	$	13,932	$	10,166	Operating	Other non-current assets	$	14,477	$	13,303
Finance	Finance	Property, plant and equipment, net	57,002		57,883		Finance	Property, plant and equipment, net	128,060		56,708
Total leased assets	Total leased assets		$	70,934	$	68,049	Total leased assets		$	142,537	$	70,011
Liabilities	Liabilities						Liabilities
Current	Current						Current
Operating	Operating	Accrued and other liabilities	$	2,570	$	2,147	Operating	Accrued and other liabilities	$	3,468	$	2,734
Finance	Finance	Accrued and other liabilities	138		132		Finance	Accrued and other liabilities	842		140
Non-Current
Non-current							Non-current
Operating	Operating	Other non-current liabilities	12,771		9,563		Operating	Other non-current liabilities	12,698		12,148
Finance	Finance	Finance lease liabilities	49,998		50,103		Finance	Finance lease liabilities	121,895		49,963
Total leased liabilities	Total leased liabilities		$	65,477	$	61,945	Total leased liabilities		$	138,903	$	64,985

Lease costs recognized in our Condensed Consolidated Statements of Operations is summarized as follows (in thousands):


		Nine months ended					Six Months Ended June 30,
Lease costs	Lease costs	2022		2021		Lease costs		2023		2022
Operating lease cost	Operating lease cost	$	2,247	$	2,056	Operating lease cost		$	1,804	$	1,452
Finance lease cost	Finance lease cost					Finance lease cost
Amortization of lease assets	Amortization of lease assets	881		494		Amortization of lease assets		1,627		587
Interest on lease liabilities	Interest on lease liabilities	2,983		1,908		Interest on lease liabilities		4,370		1,990
Finance lease cost	Finance lease cost	$	3,864	$	2,402	Finance lease cost		5,997		2,577
Total lease cost	Total lease cost	$	6,111	$	4,458	Total lease cost		$	7,801	$	4,029

Other information about lease amounts recognized in our Condensed Consolidated Financial Statements is as follows:


	~~September~~June 30, ~~2022~~2023
Lease term and discount rate
Weighted average remaining lease term (years)
Operating lease	~~4.8~~4.0
Finance lease	~~48.7~~36.6
Weighted average discount rate
Operating lease	~~6.2~~6.4	%
Finance lease	~~9.4~~8.6	%

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

The following table includes other quantitative information for our operating and finance leases (in thousands):


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021				2023		2022
Cash paid for amounts included in the measurement of lease liabilities:	Cash paid for amounts included in the measurement of lease liabilities:					Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	Operating cash flows from operating leases	$	2,545	$	2,173	Operating cash flows from operating leases		$	2,009	$	1,494
Operating cash flows from finance leases	Operating cash flows from finance leases	$	2,868	$	1,007	Operating cash flows from finance leases		4,294		2,668
Financing cash flows from finance leases	Financing cash flows from finance leases	$	1	$	1,862	Financing cash flows from finance leases		170		—

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 ~~September~~June 30, ~~2022~~2023 (in thousands):


		Operating		Finance			Operating		Finance
2022		$	822	$	1,229
2023	2023	3,579		4,111		2023	$	2,041	$	5,245
2024	2024	3,843		4,111		2024	4,665		10,491
2025	2025	3,886		4,111		2025	4,720		10,491
2026	2026	3,908		4,111		2026	4,754		10,491
After 2026		1,936		182,222
2027						2027	1,953		10,491
After 2027						After 2027	275		332,826
Total lease payments	Total lease payments	$	17,974	$	199,895	Total lease payments	$	18,408	$	380,035
Less: discount	Less: discount	2,633		149,759		Less: discount	2,242		257,298
Present value of lease liability	Present value of lease liability	$	15,341	$	50,136	Present value of lease liability	$	16,166	$	122,737

NOTE 15 — ADDITIONAL CASH FLOW INFORMATION

The following table provides information regarding the net changes in working capital (in thousands):


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Accounts receivable	Accounts receivable	$	(53,339)	$	(8,556)	Accounts receivable	$	61,000	$	(22,705)
Prepaid expenses and other current assets 1	Prepaid expenses and other current assets 1	(11,326)		412		Prepaid expenses and other current assets 1	(6,370)		(11,454)
Accounts payable	Accounts payable	14,555		4,288		Accounts payable	28,482		2,271
Accounts payable due to related parties		—		(910)

Accrued liabilities 1	Accrued liabilities 1	22,477		23,030		Accrued liabilities 1	(45,458)		(12,585)
Other, net	Other, net	831		(1,090)		Other, net	—		801
Net changes in working capital	Net changes in working capital	$	(26,802)	$	17,174	Net changes in working capital	$	37,654	$	(43,672)

1 Excludes changes in the Company’s derivative assets and liabilities.

The following table provides supplemental disclosure of cash flow information (in thousands):

Nine Months Ended September 30,
2022 2021
Non-cash accruals of property, plant and equipment and other non-current assets $ 47,663 $ 38,509
Non-cash settlement of withholding taxes associated with the 2019 bonus and vesting of certain awards — 3,064
Non-cash settlement of the 2019 bonus — 5,430

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~


	Six Months Ended June 30,
	2023		2022
Non-cash accruals of property, plant and equipment and other non-current assets	$	9,406	$	(3,551)

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the Condensed Consolidated Balance Sheets that sum to the total of such amounts shown in the Condensed Consolidated Statements of Cash Flows (in thousands):


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Cash and cash equivalents	Cash and cash equivalents	$	607,498	210,812		Cash and cash equivalents	$	106,706	$	823,522
Current restricted cash	Current restricted cash	12,375		—		Current restricted cash	9,375		3,000
Non-current restricted cash	Non-current restricted cash	24,885		—		Non-current restricted cash	24,895		24,882
Total cash, cash equivalents and restricted cash shown in the statements of cash flows		$	644,758	$	210,812
Total cash, cash equivalents and restricted cash per the statements of cash flows						Total cash, cash equivalents and restricted cash per the statements of cash flows	$	140,976	$	851,404

NOTE 16 — ~~DISCLOSURE~~DISCLOSURES 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 while continuing to increase its natural gas presence in the Haynesville Shale basin in northern Louisiana and expanding its natural gas marketing activities. The Company’s Chief Operating Decision Maker (“CODM”) determined to place additional emphasis and visibility 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.

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, gather and ~~gather~~deliver natural ~~gas.~~gas and to acquire and develop natural gas assets. The Midstream segment is organized to develop, construct and operate LNG terminals and pipelines. The Marketing & Trading segment is organized and operates to purchase and sell natural gas produced primarily by the Upstream segment, market the Driftwood terminal’s LNG production capacity and trade LNG. These operating segments represent the Company’s reportable segments. The remainder of our business is presented as “Corporate,” and consists of corporate costs and intersegment eliminations. The Company’s ~~CODM~~Chief Operating Decision Maker does not currently assess segment performance or allocate resources based on a measure of total assets. Accordingly, a total asset measure has not been provided for segment disclosure.

~~The remainder of our business is presented as “Corporate,” and consists of corporate costs and intersegment eliminations.~~

Three Months Ended September 30, 2022 Upstream Midstream Marketing & Trading Corporate Consolidated
Revenues from external customers (1)
14,205 — 66,898 — $ 81,103
Intersegment revenues (purchases) (2) (3)
66,900 (578) (68,217) 1,895 —
Segment operating profit (loss) (4)
40,071 (19,297) (11,042) (4,303) 5,429
Interest expense, net — (994) — (5,950) (6,944)
Other income (loss), net 309 — (12,937) (90) (12,718)
Consolidated loss before tax $ (14,233)
Three Months Ended September 30, 2021 Upstream Midstream Marketing & Trading Corporate Consolidated
Revenues from external customers (1)
483 — 15,155 — $ 15,638
Intersegment revenues (purchases) (2) (3)
15,155 — (12,142) (3,013) —
Segment operating profit (loss) (4)
3,491 (8,058) (640) (9,309) (14,516)
Interest expense, net — (996) — 28 (968)
Gain on extinguishment of debt, net — — — — —
Other income (loss), net — — (515) 67 (448)
Consolidated loss before tax $ (15,932)

~~Tellurian Inc. and Subsidiaries~~

~~Notes to Condensed Consolidated Financial Statements (unaudited)~~

Nine Months Ended September 30, 2022 Upstream Midstream Marketing & Trading Corporate Consolidated
Revenues from external customers (1)
15,620 — 273,773 — $ 289,393
Intersegment revenues (purchases) (2) (3)
152,824 (808) (141,385) (10,631) —
Segment operating profit (loss) (4)
83,170 (57,098) (25,093) (30,098) (29,119)
Interest expense, net — (2,984) (455) (10,351) (13,790)
Other income (loss), net 309 — (38,695) 420 (37,966)
Consolidated loss before tax $ (80,875)


Three Months Ended June 30, 2023	Upstream		Midstream		Marketing & Trading		Corporate		Consolidated
Revenues from external customers (1)	$	5,780	$	—	$	26,207	$	—	$	31,987
Intersegment revenues (purchases) (2) (3)	26,207		(1,765)		(22,782)		(1,660)		—
Segment operating loss (4)	(28,698)		(16,281)		(2,938)		(8,974)		(56,891)
Interest income (expense), net	351		(252)		3		(4,284)		(4,182)

Other income (expense), net	1,075		—		487		(108)		1,454
Consolidated loss before tax									$	(59,619)


Three Months Ended June 30, 2022	Upstream		Midstream		Marketing & Trading		Corporate		Consolidated
Revenues from external customers (1)	$	—	$	—	$	61,350	$	—	$	61,350
Intersegment revenues (purchases) (2) (3)	61,352		(230)		(59,404)		(1,718)		—
Segment operating profit (loss) (4)	38,505		(20,016)		(4,292)		(5,845)		8,352
Interest expense, net	—		(995)		—		(3,571)		(4,566)

Other income (expense), net	—		—		(3,746)		(75)		(3,821)
Consolidated loss before tax									$	(35)

Nine Months Ended September 30, 2021 Upstream Midstream Marketing & Trading Corporate Consolidated
Revenues from external customers (1)
814 — 48,884 — $ 49,698
Intersegment revenues (purchases) (2)(3)
29,108 — (26,095) (3,013) —
Segment operating loss (4)
(4,542) (24,071) (13,352) (21,290) (63,255)
Interest expense, net (1,635) (3,726) 1 (2,329) (7,689)
Gain on extinguishment of debt, net (665) 2,087 — — 1,422
Other (loss) income, net (1,202) (2,494) (514) 217 (3,993)
Consolidated loss before tax $ (73,515)


Six Months Ended June 30, 2023	Upstream		Midstream		Marketing & Trading		Corporate		Consolidated
Revenues from external customers (1)	$	9,634	$	—	$	73,288	$	—	$	82,922
Intersegment revenues (purchases) (2) (3)	73,288		(3,120)		(65,980)		(4,188)		—
Segment operating loss (4)	(31,685)		(33,996)		(5,674)		(18,540)		(89,895)
Interest income (expense), net	577		(503)		2		(8,268)		(8,192)

Loss on extinguishment of debt, net	—		—		—		(2,822)		(2,822)
Other income (expense), net	1,193		—		12,816		(212)		13,797
Consolidated loss before tax									$	(87,112)


Six Months Ended June 30, 2022	Upstream		Midstream		Marketing & Trading		Corporate		Consolidated
Revenues from external customers (1)	$	—	$	—	$	208,290	$	—	$	208,290
Intersegment revenues (purchases) (2) (3)	87,341		(230)		(77,115)		(9,996)		—
Segment operating profit (loss) (4)	43,101		(37,800)		(16,583)		(23,265)		(34,547)
Interest expense, net	—		(1,990)		(454)		(4,402)		(6,846)

Other (expense) income, net	—		—		(25,758)		509		(25,249)
Consolidated loss before tax									$	(66,642)

(1) The ~~Company's~~ Marketing & Trading segment markets to third party-purchasers most of the Company's ~~Upstream segment~~ natural gas production ~~to third party-purchasers.~~from the Upstream segment.

(2) The ~~Company’s~~ Marketing & Trading segment purchases most of the Company’s ~~Upstream segment~~ natural gas ~~production.~~production from the Upstream segment. Intersegment revenues are eliminated at consolidation.

(3) Intersegment revenues related to ~~our~~the Marketing & Trading segment are a result of cost allocations to the Corporate component using a cost plus transfer pricing methodology. Intersegment revenues related to the Corporate component are associated with intercompany interest charged to the Midstream segment. Intersegment revenues are eliminated at consolidation.

(4) Operating profit (loss) is defined as operating revenues less operating costs and allocated corporate costs.


		Nine months ended September 30,				Six Months Ended June 30,
Capital expenditures	Capital expenditures	2022		2021			Capital expenditures	2023		2022
Upstream	Upstream	236,558		$	23,416		Upstream	$	95,645	$	66,500
Midstream	Midstream	137,205		1,000			Midstream	112,565		86,150
Marketing & Trading	Marketing & Trading	—		—			Marketing & Trading	490		—
Total capital expenditures for reportable segments	Total capital expenditures for reportable segments	373,763		24,416			Total capital expenditures for reportable segments	208,700		152,650
Corporate capital expenditures	Corporate capital expenditures	1,278		—			Corporate capital expenditures	2,626		—
Consolidated capital expenditures	Consolidated capital expenditures	$	375,041	$	24,416		Consolidated capital expenditures	$	211,326	$	152,650

NOTE 17 — SUBSEQUENT EVENTS

Debt Refinancing

On August 8, 2023, we entered into a private placement securities purchase agreement (the “SPA”) with an institutional investor pursuant to which we agreed to issue and sell $250.0 million aggregate principal amount of 10% Senior Secured Notes due October 1, 2025 (the “Senior Notes”) and approximately $83.3 million aggregate principal amount of 6% Secured Convertible Notes (the “Secured Convertible Notes”) due October 1, 2025 (collectively the “Replacement Notes”). Net proceeds from the Replacement Notes of approximately $299.4 million will be used to satisfy the outstanding principal repayment obligation under the Convertible Notes.

The Replacement Notes will be collateralized by the Company’s equity interests in Tellurian Production Holdings and mortgages of the material real property natural gas assets of Tellurian Production Holdings and its subsidiaries. The Replacement Notes indentures will contain financial and non-financial covenants, including a minimum cash covenant of $50.0 million. The Replacement Notes will have quarterly interest cash payments, plus payments of approximately 3.0 million shares of common stock per quarter (or a total of approximately 25.7 million shares). On or after October 1, 2024, the holders of the Replacement Notes may redeem up to the entire principal amount of the Replacement Notes at par, plus accrued and unpaid interest, if the Company’s liquidity fails to meet or exceed a specified threshold.

At-the-Market Program

Subsequent to June 30, 2023, and through the date of this filing, we issued approximately 8.5 million shares of our common stock under our at-the-market equity offering program for net proceeds of approximately $12.4 million. As of the date of this filing, we have availability to raise aggregate gross sales proceeds of approximately $474.0 million under this at-the-market equity offering program.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of Financial Condition and Results of Operations

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

Introduction

The following discussion and analysis presents management’s view of our business, financial condition and overall performance and should be read in conjunction with our Condensed Consolidated Financial Statements and the accompanying notes. This information is intended to provide investors with an understanding of our past development activities, current financial condition and outlook for the future organized as follows:

•Our Business

•Overview of Significant Events

•Liquidity and Capital Resources

•Capital Development Activities

•Results of Operations

•Recent Accounting Standards

Our Business

Tellurian Inc. (“Tellurian,” “we,” “us,” “our,” or the “Company”), a Delaware corporation, is a Houston-based company that is developing and plans to operate 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 (collectively referred to as the “Business”). The Driftwood terminal and ~~the Driftwood pipeline~~related pipelines are collectively referred to as the “Driftwood Project.” As of ~~September~~June 30, ~~2022,~~2023, our ~~existing~~upstream natural gas assets consisted of ~~22,420~~31,117 net acres and interests in ~~131~~157 producing wells located in the Haynesville Shale ~~basin~~trend of northern Louisiana. Our Business may be developed in phases.

As part of our execution strategy, which includes increasing our asset base, we will consider various commercial arrangements with third parties across the natural gas value chain. We are also pursuing activities such as direct sales of LNG to global counterparties, trading of LNG, the acquisition of additional upstream acreage and drilling of new wells on our existing ~~or newly acquired~~ upstream acreage. We remain focused on the financing and construction of the Driftwood Project while managing our marketing & trading operations and ~~related pipelines~~upstream assets.

We manage and ~~continuing~~report our operations in three reportable segments. The Upstream segment is organized and operates to ~~expand our upstream activities.~~produce, gather, and deliver natural gas and to acquire and develop natural gas assets. The Midstream segment is organized to develop, construct and operate LNG terminals and pipelines. The Marketing & Trading segment is organized and operates to purchase and sell natural gas produced primarily by the Upstream segment, market the Driftwood terminal’s LNG production capacity and trade LNG.

We continue to evaluate the scope and other aspects of our Business in light of the evolving economic environment, dynamics of the global political landscape, needs of potential counterparties and other factors. How we execute our Business will be based on a variety of factors, including the results of our continuing analysis, changing business conditions and market feedback.

Overview of Significant Events

~~Upstream Asset Acquisition~~Binding Commitment Letter

On April 4, 2023, the Company entered into a binding letter of intent (the “LOI”) regarding the sale and leaseback of approximately 800 acres of land (the “Property”) to be used for the proposed Driftwood Project. The transaction will consist of the sale of our interests in the Property for $1.0 billion pursuant to a purchase and sale agreement (the “Purchase Agreement”) and a 40-year lease of the Property to us. On July 18, 2023, the Company entered into a commitment letter regarding the sale and leaseback of the Property that effectively replaced the LOI. The closing of the sale–leaseback transaction will occur upon the satisfaction of the closing conditions in the Purchase Agreement, including the Company securing equity and debt commitments with respect to the development of the Driftwood Project.

Debt Refinancing

On August ~~18, 2022,~~8, 2023, we entered into a private placement securities purchase agreement (the “SPA”) with an institutional investor pursuant to which we agreed to issue and sell $250.0 million aggregate principal amount of 10% Senior Secured Notes due October 1, 2025 (the “Senior Notes”) and approximately $83.3 million aggregate principal amount of 6% Secured Convertible Notes (the “Secured Convertible Notes”) due October 1, 2025 (collectively the ~~Company completed~~“Replacement Notes”). Net proceeds from the ~~acquisition of certain natural gas assets in the Haynesville Shale basin. The purchase price of $125.0 million was subject to adjustments~~Replacement Notes of approximately ~~$9.9~~$299.4 million ~~for an adjusted purchase price at closing~~will be used to satisfy the outstanding principal repayment obligation under the Convertible Notes.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of ~~approximately $134.9 million. The sellers may receive an additional cash payment~~Financial Condition and Results of $7.5 million if the average NYMEX Henry Hub Gas Price for the contract delivery months beginning with August 2022 through March 2023 exceeds a specific threshold per MmBtu (the “Contingent Consideration”).Operations

Liquidity and Capital Resources

Capital Resources

We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. We are currently funding our operations, development activities and general working capital needs through our cash on ~~hand and cash generated from our upstream natural gas sales.~~hand. Our current capital resources consist of approximately ~~$607.5~~$106.7 million of cash and cash equivalents as of ~~September~~June 30, ~~2022.~~2023. We currently maintain an at-the-market ~~debt and~~ equity offering ~~programs~~program pursuant to which we may sell our ~~Senior Notes and~~ common stock from time to time. As of the date of this filing, we have ~~remaining~~ availability to raise aggregate gross sales proceeds of approximately ~~$323.7~~$474.0 million under ~~the~~this at-the-market equity ~~offering programs and are contractually prohibited from issuing additional Senior Notes under the debt at-the-market~~ offering program.

As of ~~September~~June 30, ~~2022,~~2023, we had total indebtedness of approximately ~~$557.7 million, of which approximately $166.7 million is subject to redemption at the sole discretion of holders of the Senior Secured Convertible Notes due 2025~~

~~Tellurian Inc. and Subsidiaries~~

~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~

~~within the next twelve months.~~$391.0 million. We also had contractual obligations associated with our finance and operating leases totaling ~~approximately $217.9~~$398.4 million, of which ~~approximately $7.8~~$14.9 million is scheduled to be paid within the next twelve months. The partial redemption of the Convertible Notes, continued expenses associated with the construction of the Driftwood Project and the development of natural gas properties and declines in natural gas prices have significantly reduced our cash on hand. In June, July and August 2023, we entered into supplemental indentures that temporarily reduced the amount of cash and cash equivalents we are required to hold pursuant to the indenture governing the Convertible Notes from $100.0 million to $60.0 million.

~~The Company has sufficient~~We are planning to meet our liquidity needs from cash on hand and ~~available~~the combined proceeds generated by our Upstream operations and the sale of common stock under our at-the-market equity offering program. On August 8, 2023, we entered into a private placement securities purchase agreement (the “SPA”) with an institutional investor to refinance the Company’s existing Convertible Notes. For further information regarding the refinancing of the Company’s Convertible Notes, see Note 17, Subsequent Events, of our Notes to the Condensed Consolidated Financial Statements. The SPA is expected to close in the near future, subject to the satisfaction of customary closing conditions. We have determined that it is probable that the closing of the SPA will occur and that such sources of liquidity towill satisfy ~~its~~our obligations, ~~and~~ fund ~~its~~ working capital needs and allow us to remain compliant with our debt covenants for at least twelve months following the ~~date of~~ issuance of the ~~consolidated~~ financial statements. ~~The Company has the ability~~

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash and cash equivalents and costs and expenses for the periods presented (in thousands):


		Nine Months Ended September 30,					Six Months Ended June 30,
		2022		2021			2023		2022
Cash used in operating activities		$	(65,719)	$	(39,170)
Cash provided by (used in) operating activities						Cash provided by (used in) operating activities	$	16,080	$	(83,498)
Cash used in investing activities	Cash used in investing activities	(386,130)		(24,416)		Cash used in investing activities	(229,326)		(158,739)
Cash provided by financing activities		789,333		192,660
Net increase in cash, cash equivalents and restricted cash		337,484		129,074
Cash (used in) provided by financing activities						Cash (used in) provided by financing activities	(154,246)		786,367

Net (decrease) increase in cash, cash equivalents and restricted cash						Net (decrease) increase in cash, cash equivalents and restricted cash	(367,492)		544,130
Cash, cash equivalents and restricted cash, beginning of the period	Cash, cash equivalents and restricted cash, beginning of the period	307,274		81,738		Cash, cash equivalents and restricted cash, beginning of the period	508,468		307,274
Cash, cash equivalents and restricted cash, end of the period	Cash, cash equivalents and restricted cash, end of the period	$	644,758	$	210,812	Cash, cash equivalents and restricted cash, end of the period	$	140,976	$	851,404

Net working capital	Net working capital	$	371,009	$	161,271	Net working capital	$	6,374	$	639,766

Cash ~~used in~~provided by (used in) operating activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 increased by approximately ~~$26.5~~$99.6 million ~~due to an overall increase in disbursements in the normal course of business, as~~ compared to the same period in ~~2021.~~2022 primarily due to net changes in the Company’s working capital from December 31, 2022. For further information regarding the net changes in the Company’s working capital, see Note 15, Additional Cash Flow Information, of our Notes to the Condensed Consolidated Financial Statements.

Cash used in investing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022~~2023 increased by approximately ~~$361.7~~$70.6 million compared to the same period in ~~2021.~~2022. This increase iswas primarily due to ~~increased natural gas acquisition and development~~the funding of Driftwood Project construction activities of approximately ~~$236.6~~$112.6 million in the current period, as compared to approximately ~~$23.4~~$86.1 million of funding of Driftwood Project construction activities and land purchases and land improvements in the prior period. This increase iswas also primarily due to ~~Driftwood Project construction costs~~increased spending on natural gas development activities of approximately ~~$117.8 million and Driftwood Project land purchases and land improvements of approximately $19.4~~$95.2 million in the current period, as compared to approximately $66.5 million in the prior period.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of Financial Condition and Results of Operations

Cash (used in) provided by financing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2022 increased~~2023 decreased by approximately ~~$596.7~~$940.6 million compared to the same period in ~~2021.~~2022. This ~~increase~~decrease is primarily due to approximately $166.7 million in borrowing principal repayments in the current period as compared to $489.7 million in net proceeds from borrowing issuances in the ~~current period, as compared to approximately $119.7 million in principal repayments of borrowings in the~~ prior period. The ~~increase~~decrease is also due to approximately ~~$299.7~~$12.8 million in net proceeds from equity issuances as compared to approximately ~~$309.1~~$299.7 million in the prior period.

~~Borrowings~~

~~As of September 30, 2022, we had total indebtedness of approximately $557.7 million.~~ See Note 8, Borrowingsand Note 10, Stockholders’ Equity, of our Notes to the Condensed Consolidated Financial Statements for ~~further information.~~additional information about our financing activities.

Capital Development Activities

The activities we have proposed will require significant amounts of capital and are subject to completion risks and delays. We have received all regulatory approvals for the construction of Phase 1 of the Driftwood terminal and, as a result, our business success will depend to a significant extent upon our ability to obtain the funding necessary to construct assets on a commercially viable basis and to finance the costs of staffing, operating and expanding our company during that process. ~~We initiated certain owner construction activities necessary to proceed under the Phase 1 EPC Agreement with Bechtel and increased our upstream acquisition and development activities.~~ In March 2022, we issued a limited notice to proceed to Bechtel Energy Inc. under our Phase 1 EPC Agreement and commenced the construction of Phase 1 of the Driftwood terminal in April 2022.

We currently estimate the total cost of the Driftwood Project ~~as well as related pipelines~~ to be approximately $25.0 billion, including owners’ costs, transaction costs and contingencies but excluding interest costs incurred during construction and other financing costs. The proposed Driftwood terminal will have a liquefaction capacity of up to approximately 27.6 Mtpa and will be situated on approximately 1,200 acres in Calcasieu Parish, Louisiana. The proposed Driftwood terminal will include up to 20 liquefaction Trains, three full containment LNG storage tanks and three marine berths.

~~Tellurian Inc. and Subsidiaries~~

~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~

Our strategy involves acquiring additional natural gas properties, including properties in the Haynesville ~~shale~~Shale basin. We intend to pursue potential acquisitions of such assets, or public or private companies that own such assets. We ~~would~~ expect to use stock, cash on hand, or cash raised in financing transactions to complete an acquisition of this type.

We anticipate funding our more immediate liquidity requirements for the construction of the Driftwood terminal, natural gas activities, and general and administrative expenses through the use of cash on hand, proceeds from operations, and proceeds from completed and future issuances of securities by us. Investments in the construction of the Driftwood terminal and natural gas development are and will continue to be significant, but the size of those investments will depend on, among other things, commodity prices, Driftwood Project financing developments and other liquidity considerations, and our continuing analysis of strategic risks and opportunities. Consistent with our overall financing strategy, the Company has considered, and in some cases discussed with investors, various potential financing transactions, including issuances of debt, equity and equity-linked securities or similar transactions, to support its ~~short- and medium-term~~ capital requirements. The Company will continue to evaluate its cash needs and business outlook, and it may execute one or more transactions of this type in the future.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of Financial Condition and Results of Operations

Results of Operations

The following table summarizes revenue, costs and expenses for the periods presented (in thousands):


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
		2022		2021		2022		2021			2023		2022		2023		2022
Natural gas sales	Natural gas sales	$	81,103	15,638		168,442		29,922		Natural gas sales	31,987		$	61,350	$	82,922	$	87,339
LNG sales	LNG sales	—		—		120,951		19,776		LNG sales	—		—		—		120,951
Total revenues		81,103		15,638		289,393		49,698
Total revenue										Total revenue	31,987		61,350		82,922		208,290
Operating expenses										Operating expenses	20,848		5,943		38,293		10,108
LNG cost of sales	LNG cost of sales	—		339		131,663		23,186		LNG cost of sales	—		—		—		131,663
Operating expenses		8,428		2,729		18,536		7,655
Development expenses	Development expenses	12,891		8,823		48,244		26,327		Development expenses	11,530		17,687		23,587		35,352
Depreciation, depletion and amortization	Depreciation, depletion and amortization	12,860		3,735		22,735		8,720		Depreciation, depletion and amortization	25,210		5,854		47,397		9,875
General and administrative expenses	General and administrative expenses	41,495		14,528		97,334		47,065		General and administrative expenses	31,290		23,514		63,540		55,839
Income (loss) from operations		5,429		(14,516)		(29,119)		(63,255)
(Loss) income from operations										(Loss) income from operations	(56,891)		8,352		(89,895)		(34,547)
Interest expense, net	Interest expense, net	(6,944)		(968)		(13,790)		(7,689)		Interest expense, net	(4,182)		(4,566)		(8,192)		(6,846)
Gain on extinguishment of debt, net		—		—		—		1,422
Other expense, net		(12,718)		(448)		(37,966)		(3,993)
Income tax benefit		—		—		—		—
Loss on extinguishment of debt, net										Loss on extinguishment of debt, net	—		—		(2,822)		—
Other income (expense), net										Other income (expense), net	1,454		(3,821)		13,797		(25,249)
Income tax										Income tax	—		—		—		—
Net loss	Net loss	$	(14,233)	$	(15,932)	$	(80,875)	$	(73,515)	Net loss	$	(59,619)	$	(35)	$	(87,112)	$	(66,642)

The most significant changes affecting our results of operations for the three months ended ~~September~~June 30, ~~2022~~2023 compared to the same period in ~~2021, on a consolidated basis and by segment, are the following:~~

~~Upstream~~

•Increase of approximately $65.5 million in Natural gas sales as a result of higher realized natural gas prices and production volumes attributable to the acquisition of proved natural gas properties and newly drilled and completed wells during the third quarter of 2022.

•Increase of approximately $5.7 million in Operating expenses as a result of higher production volumes attributable to the acquisition of proved natural gas properties and newly drilled and completed wells during the third quarter of 2022.

•Increase of approximately $9.1 million in DD&A primarily attributable to a higher net book value utilized in the calculation of DD&A due to the acquisition of proved natural gas assets, increased capital expenditures and higher production volumes during the current period.

~~Marketing & Trading~~

•Increase of approximately $12.3 million in Other expense, net primarily attributable to an approximately $12.5 million of realized loss on the settlement of natural gas financial instruments, as compared to the same period in 2021.

~~Midstream~~

•~~Increase of approximately $4.1 million in Development expenses primarily attributable to an increase in technical and engineering services associated with pipeline development activities.~~

~~Tellurian Inc. and Subsidiaries~~

~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~

~~Consolidated~~

•Increase of approximately $27.0 million in General and administrative expenses primarily attributable to a $9.3 million increase in compensation expenses, a $3.8 million increase in professional services, a $9.0 million increase in donations to a university to advance global energy research and other expenses in the normal course of business.

~~Primarily as a result of the foregoing, our consolidated Net loss was approximately $14.2 million for the three months ended September 30,~~ 2022, ~~compared to a Net loss of approximately $15.9 million during the same period in 2021.~~

~~The most significant changes affecting our results of operations for the nine months ended September 30, 2022 compared to the same period in 2021,~~ on a consolidated basis and by segment, are the following:

Upstream

•~~Increase~~Decrease of approximately ~~$138.5~~$29.4 million in Natural gas sales as a result of ~~higher~~decreased realized natural gas prices ~~and~~partially offset by increased production volumes attributable to the acquisition of ~~proved~~ natural gas properties in 2022 and newly drilled and completed wells during ~~the nine months ended September 30,~~2023 and 2022.

•Increase of approximately ~~$10.9~~$14.9 million in Operating expenses as a result of ~~higher~~increased production volumes ~~attributable to the acquisition~~and approximately $3.2 million of ~~proved~~ natural gas ~~properties and newly drilled and completed wells~~drilling rig standby costs incurred during ~~2022.~~the current period.

•Increase of approximately ~~$14.0~~$19.4 million in ~~DD&A primarily attributable to a higher net book value utilized in the calculation of~~ DD&A due to the acquisition of ~~proved~~ natural gas ~~assets,~~properties in 2022, increased capital expenditures during 2022 and ~~higher~~2023 and increased natural gas production volumes during the current period.

~~Marketing & Trading~~Midstream

•~~Increases~~Decrease of approximately $101.2 million and approximately $108.5 million in LNG sales and LNG cost of sales, respectively, as a result of increased realized sales and purchase prices of an LNG cargo sold during the first quarter of 2022, as compared to the realized price of an LNG cargo sold during the second quarter of 2021.

•Increase of approximately $34.0 million in Other expense, net primarily attributable to an approximately $13.6 million unrealized loss on financial instruments due to changes in the fair value of the Company’s derivative instruments during the current period and approximately $23.8 million of realized loss on the settlement of natural gas financial instruments, as compared to the same period in 2021. The losses on financial instruments were partially offset by approximately $3.5 million of realized gain on the settlements of LNG financial instruments in the current period.

~~Midstream~~

•~~Increase of approximately $21.9~~$6.2 million in Development expenses primarily attributable to approximately $6.2 million in the cost of land and roads donated for public use in the state of Louisiana ~~an approximately $3.6 million increase~~ in ~~technical and engineering services associated with~~ the ~~Driftwood Project and pipeline development activities, and an approximately $12.1 million increase in compensation and other development expenses associated with the Driftwood Project.~~prior period.

Consolidated

•Increase of approximately ~~$50.3~~$7.8 million in General and administrative expenses primarily attributable to ~~a $23.4~~increased marketing expenses during the current period.

•Increase of approximately $5.3 million ~~increase~~ in ~~compensation expenses, a $12.1~~Other income (expense), net primarily attributable to approximately $11.4 million ~~increase in professional services, a $9.0~~of realized gains on the settlement of natural gas financial instruments and $10.9 million ~~increase in donations~~of unrealized loss on natural gas financial instruments due to ~~a university to advance global energy research and other expenses~~changes in the ~~normal course~~fair value of ~~business.~~the Company’s derivative instruments during the current period as compared to $10.5 million of realized loss and $6.8 million of unrealized gain on natural gas financial instruments in the prior period.

Primarily as a result of the foregoing, our consolidated Net loss was approximately ~~$80.9~~$59.6 million for the ~~nine~~three months ended ~~September~~June 30, ~~2022,~~2023, compared to a Net loss of approximately ~~$73.5~~$35.0 thousand during the same period in 2022.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of Financial Condition and Results of Operations

The most significant changes affecting our results of operations for the six months ended June 30, 2023 compared to the same period in 2022, on a consolidated basis and by segment, are the following:

Upstream

•Decrease of approximately $4.4 million in Natural gas sales as a result of decreased realized natural gas prices partially offset by increased production volumes attributable to the acquisition of natural gas properties in 2022 and newly drilled and completed wells during 2023 and 2022.

•Increase of approximately $28.2 million in Operating expenses primarily as a result of increased natural gas production volumes and approximately $3.6 million of natural gas drilling rig standby costs incurred during the current period.

•Increase of approximately $37.5 million in DD&A primarily attributable to a higher asset net book value utilized in the calculation of DD&A due to the acquisition of natural gas properties in 2022, increased capital expenditures during 2022 and 2023 and increased natural gas production volumes during the current period.

Marketing & Trading

•Decrease of approximately $121.0 million and approximately $131.7 million in LNG sales and LNG cost of sales, respectively, as a result of the absence of an LNG cargo that was sold during the first quarter of 2022.

Midstream

•Decrease of approximately $11.8 million in Development expenses primarily attributable to the capitalization of directly identifiable Driftwood Project costs as construction in progress during the current period, which were expensed in the prior period and $6.2 million in the cost of land and roads donated for public use in the state of Louisiana in the prior period.

Consolidated

•Increase of approximately $7.8 million in General and administrative expenses primarily attributable to increased marketing expenses during the current period.

•Increase of approximately $1.3 million in Interest expense, net due to increased interest charges as a result of higher outstanding borrowing obligations during 2023 as compared to 2022. The increase in Interest expense, net was partially offset by approximately $8.0 million of capitalized interest and $5.5 million of interest income during 2023. For further information regarding the Company’s outstanding borrowing obligations, see Note 8, Borrowings, of our Notes to the Condensed Consolidated Financial Statements.

•Increase of approximately $2.8 million in Loss on extinguishment of debt, net due to the repayment of approximately $166.7 million of the Company’s Convertible Notes, which resulted in the write-off of approximately $2.8 million of unamortized debt issuance costs.

•Increase of approximately $39.0 million in Other income (expense), net primarily attributable to approximately $23.3 million of realized gains on the settlement of natural gas financial instruments and $10.5 million of unrealized loss on natural gas financial instruments due to changes in the fair value of the Company’s derivative instruments during the current period as compared to $11.3 million of realized loss and $8.3 million of unrealized loss on natural gas financial instruments in the prior period.

As a result of the foregoing, our consolidated Net loss was approximately $87.1 million for the six months ended June 30, 2023, compared to a Net loss of approximately $66.6 million during the same period in ~~2021.~~2022.

Tellurian Inc. and Subsidiaries

Management's Discussion and Analysis of Financial Condition and Results of Operations

Recent Accounting Standards

We do not believe that any recently issued, but not yet effective, accounting standards, if currently adopted, would have a material effect on our Condensed Consolidated Financial Statements or related disclosures.

Critical Accounting Estimates

There were no changes made by management to the critical accounting policies ~~made by management~~ in the three months ended ~~September~~June 30, ~~2022.~~2023. Please refer to the Summary of Critical Accounting Estimates section within Management’s Discussion and Analysis and Note 2 to the Consolidated Financial Statements of our Annual Report on Form 10-K for the year ended December 31, ~~2021~~2022 for a discussion of our critical accounting estimates and accounting policies.

~~Tellurian Inc. and Subsidiaries~~

~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

~~The primary~~As of June 30, 2023, there were no open natural gas financial instrument positions. Accordingly, we do not believe that we hold, or are party to, instruments that are subject to market ~~risk relating~~risks that are material to our financial instrument contracts is the volatility in commodity market prices for our natural gas production. We use financial instruments to reduce the volatility of earnings and cash flow due to fluctuations in the prices of natural gas. The market price risk is offset by the gain or loss recognized upon the related sale of the production that is financially protected.Business. Refer to Note 6,5, Financial Instruments, of the ~~condensed consolidated financial statements~~Condensed Consolidated Financial Statements included in this Quarterly Report for additional details about our financial ~~instruments and their fair value.~~instruments.

ITEM 4. CONTROLS AND PROCEDURES

As indicated in the certifications in Exhibits 31.1 and 31.2 to this report, our Chief Executive Officer and Chief Financial Officer have evaluated our disclosure controls and procedures as of ~~September~~June 30, ~~2022.~~2023. Based on that evaluation, these officers have concluded that our disclosure controls and procedures are effective in ensuring that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to them in a manner that allows for timely decisions regarding required disclosures and are effective in ensuring that such information is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. There were no changes during our last fiscal quarter that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors disclosed in Part I, Item 1A, of our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2021, except~~2022, and Part II, Item 1A, of our Quarterly Report on Form 10-Q for the ~~risk factors discussed below.~~quarterly period ended March 31, 2023, other than as follows:

IfNon-U.S. holders of our common stock, in certain situations, could be subject to U.S. federal income tax upon sale, exchange or disposition of our common stock.

We are currently, and may remain in the ~~conditions precedent~~future, a U.S. real property holding corporation for U.S. federal income tax purposes because the fair market value of our assets that consist of “United States real property interests,” as defined in the Internal Revenue Code of 1986, as amended, and applicable Treasury regulations, constitutes at least 50% of the combined fair market value of our real estate interests and other business assets. As a result, under the Foreign Investment in Real Property Tax Act, or FIRPTA, certain non-U.S. investors could be subject to U.S. federal income tax on any gain from the disposition of shares of our ~~LNG sale and purchase agreement (“LNG SPA”) cannot~~common stock, in which case they would also be ~~satisfied or extended on acceptable terms, or at all, such LNG SPA may be terminated.~~

In 2021, Driftwood LNG LLC (“Driftwood LNG”) entered into an LNG SPA with each of Vitol Inc. (“Vitol”) and Gunvor Singapore Pte Ltd (“Gunvor”) and two LNG SPAs with Shell NA LLC (“Shell”). On September 23, 2022, we received a notice of termination from Shellrequired to file U.S. tax returns with respect to such gain. In general, whether these FIRPTA provisions apply in such case would depend on the ~~two LNG SPAs with Shell, and we delivered a notice~~amount of ~~termination~~our common stock that such non-U.S. investors hold. In addition, such non-U.S. investors could be subject to ~~Vitol regarding~~withholding in such case if, at the ~~LNG SPA with Vitol. Conditions precedent to each party’s obligation to consummate~~time they dispose of their shares, our common stock is not regularly traded on an established securities market within the ~~transactions contemplated by the LNG SPA with Gunvor include (i) Driftwood LNG having issued to Bechtel Oil, Gas and Chemicals, Inc. an unconditional full notice to proceed for the construction~~meaning of the ~~first two plants~~applicable Treasury regulations. So long as our common stock continues to be regularly traded on an established securities market, only a non-U.S. investor who has owned, actually or constructively, more than 5% of our common stock at any time during the shorter of (i) the five-year period ending on the date of disposition and (ii) the non-U.S. investor’s holding period for its shares may be subject to U.S. federal income tax on the disposition of our common stock under FIRPTA.

Our Executive Chairman, Charif Souki, has personal investments and interests that have at times become interrelated with the interests of the ~~Driftwood terminal~~Company. These investments and (ii) Driftwood LNG or an affiliate thereof having secured the necessary financing arrangements to construct such plants and having achieved financial close under such arrangements. The LNG SPA with Gunvor has a conditions precedent deadline of December 31, 2022. If the conditions precedent to the LNG SPA with Gunvor are not satisfied by such conditions precedent deadline, either party to the LNG SPA can terminate such LNG SPA, subject to each LNG SPA’s notice requirements. There can be no assurance that we will be able to satisfy or extend the conditions precedent deadline on acceptable terms, or at all. The termination of the LNG SPA with Gunvor could negatively affect our ability to secure additional equity and/or debt financing to complete the Driftwood Project on acceptable terms, or at all.

~~Our Acquisition (as defined below) may not achieve its intended results and~~interests may result in ~~us assuming unanticipated liabilities.~~conflicts of interest or other impacts on the Company.

~~On July 13, 2022, we entered into~~Mr. Souki has a ~~purchase~~variety of personal business interests and ~~sale agreement (the “Acquisition Agreement”) pursuant to which we acquired on August 18, 2022 certain natural gas assets~~actions taken in his personal capacity have in some cases affected the Haynesville Shale of Louisiana, with the expectation that the Acquisition would result in various benefits, growth opportunities and synergies. Achieving the anticipated benefits of the Acquisition is subject to a number of risks and uncertainties.Company. For example, ~~under~~in April 2023, the ~~Acquisition Agreement, we had the opportunity to conduct customary environmental~~Company became aware of certain facts and title due diligence. However, we may discover title defects or adverse environmental or other conditions of which we are currently unaware. Environmental, title and other problems could reduce the value of the properties to us, and, depending on the circumstances, we could have limited or no recourse with respect to those problems. We have assumed substantially all of the liabilitiesclaims associated with ~~the acquired properties~~outstanding loan agreements (the “Souki Loans”) between UBS O’Connor LLC (“UBS O’Connor”), Mr. Souki, and ~~will be entitled~~certain entities related to ~~indemnification~~Mr. Souki (collectively, “Souki”) included in ~~connection with those liabilities~~a lawsuit filed in only limited circumstances and in limited amounts. We cannot assure you that such potential remedies will be adequate for any liabilities we incur, and such liabilities could be significant. Also, it is uncertain whether our existing operations and the acquired properties and assets can be integrated in an efficient and effective manner.

As with other acquisitions, the success of the Acquisition depends on, among other things, the accuracy of our assessment of the reserves and drilling locations associated with the acquired properties, future commodity prices and operatinga New York state court by Souki against UBS

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~~costs~~O’Connor. In the lawsuit, Souki asserts claims for, among other things, breach of the duty of good faith and ~~various~~fair dealing and breach of contract in connection with UBS O’Connor’s foreclosure on certain assets held as collateral under the Souki Loans, including certain shares of the Company’s stock. In particular, Souki has alleged, among other ~~factors.~~things, that Souki and UBS O’Connor agreed in 2020 to approach the renegotiation of the terms of the Souki Loans and the Tellurian Loan “holistically”, an agreement that was not disclosed to the Company. Accordingly, this situation may have created a conflict of interest between Mr. Souki’s interests and those of the Company. In addition, pledged shares for the Souki Loans were foreclosed upon in 2023 and sold into the market, which may have caused a significant decrease in the Company’s stock price. Further, two entities owned by Mr. Souki declared bankruptcy in July 2023. These ~~assessments~~and other events relating to, or actions taken by or involving, Mr. Souki in his personal capacity may have an impact on the Company. Policies and procedures designed to mitigate potential conflicts of interest are ~~necessarily inexact. As a result, we~~subject to inherent limitations and may not ~~recover the purchase price for the Acquisition from the sale of production from the properties or recognize acceptable rates of return from~~result in all such ~~sales.~~conflicts being identified and addressed in a timely manner.

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

Recent Sales of Unregistered Securities

None that occurred during the three months ended ~~September~~June 30, ~~2022.~~2023.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

None that occurred during the three months ended ~~September~~June 30, ~~2022.~~2023.

ITEM 5. OTHER INFORMATION

~~None.~~Insider Trading Arrangements and Policies

During the three months ended June 30, 2023, none of our directors or executive officers adopted or terminated a “Rule 10b5-1 trading arrangement” or a “non-Rule 10b5-1 trading arrangement” (as such terms are defined in Item 408 of Regulation S-K).

ITEM 6. EXHIBITS


Exhibit No.						Description
3.1						Amended and Restated Certificate of Incorporation of Tellurian Inc. (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on June 7, 2023)
4.1						~~Second~~Indenture, dated as of June 3, 2022, by and between Tellurian Inc., as issuer, and Wilmington Trust, National Association, as trustee (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on June 3, 2022)
4.2						Third Supplemental Indenture, dated as of ~~July 18, 2022,~~June 16, 2023, by and among Tellurian Inc., as issuer, Wilmington Trust, National Association, as trustee, and the collateral agent named therein, relating to the 6.00% Senior Secured Convertible Notes due 2025 (incorporated by reference to Exhibit 4.4 to the Company’s Current Report on Form 8-K filed on June 20, 2023)
4.3						Fourth Supplemental Indenture, dated as of June 29, 2023, by and between Tellurian Inc., as issuer, and Wilmington Trust, National Association, as trustee, relating to the 6.00% Senior Secured Convertible Notes due 2025 (incorporated by reference to Exhibit ~~4.3~~4.5 to the Company’s ~~Quarterly~~Current Report on Form ~~10-Q for the quarter ended~~8-K filed on June ~~30, 2022)~~29, 2023)
~~10.1††‡~~ 4.4						~~Purchase and Sale Agreement,~~Fifth Supplemental Indenture, dated as of July ~~13, 2022,~~14, 2023, by and between Tellurian ~~Production LLC, EnSight IV Energy Partners, LLC~~Inc., as issuer, and ~~EnSight Haynesville Partners, LLC~~Wilmington Trust, National Association, as trustee, relating to the 6.00% Senior Secured Convertible Notes due 2025 (incorporated by reference to Exhibit ~~10.1~~4.6 to the Company’s Current Report on Form 8-K filed on July ~~13, 2022)~~17, 2023)
~~10.2‡~~ 4.5						~~Change Order CO-009,~~Sixth Supplemental Indenture, dated as of July ~~15, 2022, to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Driftwood LNG Phase 1 Liquefaction Facility, dated as of November 10, 2017,~~28, 2023, by and between ~~Driftwood LNG LLC~~Tellurian Inc., as issuer, and ~~Bechtel Energy Inc. (formerly known~~Wilmington Trust, National Association, as ~~Bechtel Oil, Gas and Chemicals, Inc.)~~trustee, relating to the 6.00% Senior Secured Convertible Notes due 2025 (incorporated by reference to Exhibit ~~10.5~~4.7 to the Company’s ~~Quarterly~~Current Report on Form ~~10-Q for~~8-K filed on July 31, 2023)




10.1‡						Securities Purchase Agreement, dated as of August 8, 2023, by and between Tellurian Inc. and the ~~quarter ended June 30, 2022)~~investor named therein
10.3‡*10.2						~~Change Order CO-010,~~Redemption Letter Agreement, dated as of ~~October 10, 2022, to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Driftwood LNG Phase 1 Liquefaction Facility, dated as of November 10, 2017,~~August 8. 2023, by and ~~between Driftwood LNG LLC~~among Tellurian Inc. and ~~Bechtel Energy Inc. (formerly known as Bechtel Oil, Gas and Chemicals, Inc.)~~the other parties named therein
31.1*						Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
31.2*						Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**						Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**						Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*						XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH*						Inline XBRL Taxonomy Extension Schema Document
101.CAL*						Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*						Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*						Inline XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*						Inline XBRL Taxonomy Extension Presentation Linkbase Document
104						The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended ~~September~~June 30, ~~2022,~~2023, formatted in Inline XBRL


*			Filed herewith.
**			Furnished herewith.
††‡			Portions of this exhibit have been omitted in accordance with Item 601(b)(2) or 601(b)(10) of Regulation S-K. The omitted information is not material and would likely cause competitive harm to the registrant if publicly disclosed. The registrant hereby agrees to furnish supplementally an unredacted copy of this exhibit to the Securities and Exchange Commission upon request.
‡			Certain schedules or similar attachments to this exhibit have been omitted in accordance with Item 601(a)(5) of Regulation S-K. The registrant hereby agrees to furnish supplementally to the Securities and Exchange Commission upon request a copy of any omitted schedule or attachment to this exhibit.

2324

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


		TELLURIAN INC.

Date:	~~November 2, 2022~~August 9, 2023	By:	/s/ ~~L. Kian Granmayeh~~Simon G. Oxley
			~~L. Kian Granmayeh~~Simon G. Oxley
			Chief Financial Officer
			(as Principal Financial Officer)
			Tellurian Inc.

~~Date:~~	~~November 2, 2022~~August 9, 2023	By:	/s/ Khaled A. Sharafeldin
			Khaled A. Sharafeldin
			Chief Accounting Officer
			(as Principal Accounting Officer)
			Tellurian Inc.

2425


Three Months Ended September 30, 2022	Upstream	Midstream	Marketing & Trading	Corporate	Consolidated
Revenues from external customers (1)	14,205	—	66,898	—	$	81,103
Intersegment revenues (purchases) (2) (3)	66,900	(578)	(68,217)	1,895	—
Segment operating profit (loss) (4)	40,071	(19,297)	(11,042)	(4,303)	5,429
Interest expense, net	—	(994)	—	(5,950)	(6,944)
Other income (loss), net	309	—	(12,937)	(90)	(12,718)
Consolidated loss before tax					$	(14,233)


Three Months Ended September 30, 2021	Upstream	Midstream	Marketing & Trading	Corporate	Consolidated
Revenues from external customers (1)	483	—	15,155	—	$	15,638
Intersegment revenues (purchases) (2) (3)	15,155	—	(12,142)	(3,013)	—
Segment operating profit (loss) (4)	3,491	(8,058)	(640)	(9,309)	(14,516)
Interest expense, net	—	(996)	—	28	(968)
Gain on extinguishment of debt, net	—	—	—	—	—
Other income (loss), net	—	—	(515)	67	(448)
Consolidated loss before tax					$	(15,932)


Nine Months Ended September 30, 2022	Upstream	Midstream	Marketing & Trading	Corporate	Consolidated
Revenues from external customers (1)	15,620	—	273,773	—	$	289,393
Intersegment revenues (purchases) (2) (3)	152,824	(808)	(141,385)	(10,631)	—
Segment operating profit (loss) (4)	83,170	(57,098)	(25,093)	(30,098)	(29,119)
Interest expense, net	—	(2,984)	(455)	(10,351)	(13,790)
Other income (loss), net	309	—	(38,695)	420	(37,966)
Consolidated loss before tax					$	(80,875)


Nine Months Ended September 30, 2021	Upstream	Midstream	Marketing & Trading	Corporate	Consolidated
Revenues from external customers (1)	814	—	48,884	—	$	49,698
Intersegment revenues (purchases) (2)(3)	29,108	—	(26,095)	(3,013)	—
Segment operating loss (4)	(4,542)	(24,071)	(13,352)	(21,290)	(63,255)
Interest expense, net	(1,635)	(3,726)	1	(2,329)	(7,689)
Gain on extinguishment of debt, net	(665)	2,087	—	—	1,422
Other (loss) income, net	(1,202)	(2,494)	(514)	217	(3,993)
Consolidated loss before tax					$	(73,515)