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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2023

OR

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

For the transition period from __________ to__________

Commission File Number: 001-38790

New Fortress Energy Inc.

(Exact Name of Registrant as Specified in its Charter)

Delaware			83-1482060
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

111 W. 19th Street, 8th Floor New York, NY			10011
(Address of principal executive offices)			(Zip Code)

Registrant’s telephone number, including area code: (516) 268-7400

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 x			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

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

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

Class A common stock

“NFE”

Nasdaq Global Select Market

As of November 6, 2023, the registrant had 205,031,406 shares of Class A common stock outstanding.

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TABLE OF CONTENTS

GLOSSARY OF TERMS						ii
CAUTIONARY STATEMENT ON FORWARD-LOOKING STATEMENTS						iv
PART I FINANCIAL INFORMATION						1
Item 1.			Financial Statements.			1
Item 2.			Management’s Discussion and Analysis of Financial Condition and Results of Operations.			31
Item 3.			Quantitative and Qualitative Disclosures About Market Risk.			52
Item 4.			Controls and Procedures.			52
PART II OTHER INFORMATION						54
Item 1.			Legal Proceedings.			54
Item 1A.			Risk Factors.			54
Item 2.			Unregistered Sales of Equity Securities and Use of Proceeds.			86
Item 3.			Defaults Upon Senior Securities.			86
Item 4.			Mine Safety Disclosures.			86
Item 5.			Other Information.			86
Item 6.			Exhibits.			86
SIGNATURES						92

i

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GLOSSARY OF TERMS

As commonly used in the liquefied natural gas industry, to the extent applicable and as used in this Quarterly Report on Form 10-Q (“Quarterly Report”), the terms listed below have the following meanings:

ADO			automotive diesel oil
Bcf/yr			billion cubic feet per year
Btu			the amount of heat required to raise the temperature of one avoirdupois pound of pure water from 59 degrees Fahrenheit to 60 degrees Fahrenheit at an absolute pressure of 14.696 pounds per square inch gage
CAA			Clean Air Act
CERCLA			Comprehensive Environmental Response, Compensation and Liability Act
CWA			Clean Water Act
DOE			U.S. Department of Energy
DOT			U.S. Department of Transportation
EPA			U.S. Environmental Protection Agency
FTA countries			countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAP			generally accepted accounting principles in the United States
GHG			greenhouse gases
GSA			gas sales agreement
Henry Hub			a natural gas pipeline located in Erath, Louisiana that serves as the official delivery location for futures contracts on the New York Mercantile Exchange
ISO container			International Organization of Standardization, an intermodal container
LNG			natural gas in its liquid state at or below its boiling point at or near atmospheric pressure
MMBtu			one million Btus, which corresponds to approximately 12.1 gallons of LNG
mtpa			metric tons per year
MW			megawatt. We estimate 2,500 LNG gallons would be required to produce one megawatt
NGA			Natural Gas Act of 1938, as amended
non-FTA countries			countries without a free trade agreement with the United States providing for national treatment for trade in natural gas and with which trade is permitted
OPA			Oil Pollution Act

ii

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OUR			Office of Utilities Regulation (Jamaica)
PHMSA			Pipeline and Hazardous Materials Safety Administration
PPA			power purchase agreement
SSA			steam supply agreement
TBtu			one trillion Btus, which corresponds to approximately 12,100,000 gallons of LNG

iii

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CAUTIONARY STATEMENT ON FORWARD-LOOKING STATEMENTS

This Quarterly Report contains forward-looking statements regarding, among other things, our plans, strategies, prospects and projections, both business and financial. All statements contained in this Quarterly Report other than historical information are forward-looking statements that involve known and unknown risks and relate to future events, our future financial performance or our projected business results. In some cases, you can identify forward-looking statements by terminology such as “may,” “will,” “should,” “expects,” “plans,” “anticipates,” “believes,” “estimates,” “predicts,” “projects,” “targets,” “potential” or “continue” or the negative of these terms or other comparable terminology. Such forward-looking statements are necessarily estimates based upon current information and involve a number of risks and uncertainties. Actual events or results may differ materially from the results anticipated in these forward-looking statements as a result of a variety of factors. While it is impossible to identify all such factors, factors that could cause actual results to differ materially from those estimated by us include:

•our limited operating history;

•the results of our subsidiaries, affiliates, joint ventures and special purpose entities in which we invest and their ability to make dividends or distributions to us;

•construction and operational risks related to our facilities and assets, including cost overruns and delays;

•failure of LNG or natural gas to be a competitive source of energy in the markets in which we operate, and seek to operate;

•complex regulatory and legal environments related to our business, assets and operations, including actions by governmental entities or changes to regulation or legislation, in particular related to our permits, approvals and authorizations for the construction and operation of our facilities;

•delays or failure to obtain and maintain approvals and permits from governmental and regulatory agencies;

•failure to obtain a return on our investments for the development of our projects and assets and the implementation of our business strategy;

•failure to maintain sufficient working capital for the development and operation of our business and assets;

•failure to convert our customer pipeline into actual sales;

•lack of asset, geographic or customer diversification, including loss of one or more of our customers;

•competition from third parties in our business;

•cyclical or other changes in the demand for and price of LNG and natural gas;

•inability to procure LNG at necessary quantities or at favorable prices to meet customer demand, or otherwise to manage LNG supply and price risks, including hedging arrangements;

•inability to successfully develop and implement our technological solutions;

•inability to service our debt and comply with our covenant restrictions;

•inability to obtain additional financing to effect our strategy;

•inability to successfully complete mergers, sales, divestments or similar transactions related to our businesses or assets or to integrate such businesses or assets and realize the anticipated benefits;

•economic, political, social and other risks related to the jurisdictions in which we do, or seek to do, business;

•weather events or other natural or manmade disasters or phenomena;

•the extent of the global COVID-19 pandemic or any other major health and safety incident;

•increased labor costs, disputes or strikes, and the unavailability of skilled workers or our failure to attract and retain qualified personnel;

•the tax treatment of, or changes in tax laws applicable to, us or our business or of an investment in our Class A shares; and

•other risks described in the “Risk Factors” section of this Quarterly Report.

All forward-looking statements speak only as of the date of this Quarterly Report. When considering forward-looking statements, you should keep in mind the risks set forth under “Item 1A. Risk Factors” and other cautionary statements included in our Annual Report on Form 10-K for the year ended December 31, 2022 (our “Annual Report”), this Quarterly Report and in our other filings with the Securities and Exchange Commission (the “SEC”). The cautionary statements referred to in this section also should be considered in connection with any subsequent written or oral forward-looking statements that may be issued by us or persons acting on our behalf. We undertake no duty to update these forward-looking statements, even though our situation may change in the future. Furthermore, we cannot guarantee future results, events, levels of activity, performance, projections or achievements.

iv

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PART I

FINANCIAL INFORMATION

Item 1.    Financial Statements.

New Fortress Energy Inc.

Condensed Consolidated Balance Sheets

As of September 30, 2023 and December 31, 2022

(Unaudited, in thousands of U.S. dollars, except share amounts)

			September 30, 2023						December 31, 2022
Assets
Current assets
Cash and cash equivalents			$	171,329					$	675,492
Restricted cash			66,162						165,396
Receivables, net of allowances of $1,133 and $884, respectively			360,820						280,313
Inventory			103,331						39,070
Prepaid expenses and other current assets, net			164,559						226,883
Total current assets			866,201						1,387,154
Construction in progress			4,789,799						2,418,608
Property, plant and equipment, net			2,563,871						2,116,727
Equity method investments			139,058						392,306
Right-of-use assets			474,483						377,877
Intangible assets, net			67,443						85,897
Goodwill			776,760						776,760
Deferred tax assets, net			8,074						8,074
Other non-current assets, net			110,681						141,679
Total assets			$	9,796,370					$	7,705,082
Liabilities
Current liabilities
Current portion of long-term debt and short-term borrowings			$	270,547					$	64,820
Accounts payable			892,924						80,387
Accrued liabilities			435,692						1,162,412
Current lease liabilities			142,296						48,741
Other current liabilities			169,744						52,878
Total current liabilities			1,911,203						1,409,238
Long-term debt			5,897,528						4,476,865
Non-current lease liabilities			318,082						302,121
Deferred tax liabilities, net			27,206						25,989
Other long-term liabilities			63,789						49,010
Total liabilities			8,217,808						6,263,223
Commitments and contingencies (Note 19)
Stockholders’ equity
Class A common stock, $0.01 par value, 750 million shares authorized, 205.0 million issued and outstanding as of September 30, 2023; 208.8 million issued and outstanding as of December 31, 2022			2,050						2,088
Additional paid-in capital			1,039,428						1,170,254
Retained earnings			331,282						62,080
Accumulated other comprehensive income			63,312						55,398
Total stockholders’ equity attributable to NFE			1,436,072						1,289,820
Non-controlling interest			142,490						152,039
Total stockholders’ equity			1,578,562						1,441,859
Total liabilities and stockholders’ equity			$	9,796,370					$	7,705,082

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

1

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New Fortress Energy Inc.

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

For the three and nine months ended September 30, 2023 and 2022

(Unaudited, in thousands of U.S. dollars, except share and per share amounts)

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Revenues
Operating revenue			$	420,868					$	632,684					$	1,417,175					$	1,529,999
Vessel charter revenue			67,287						92,860						209,651						260,414
Other revenue			26,307						6,386						28,112						31,490
Total revenues			514,462						731,930						1,654,938						1,821,903
Operating expenses
Cost of sales (exclusive of depreciation and amortization shown separately below)			191,920						393,830						602,626						874,529
Vessel operating expenses			11,613						20,318						36,347						61,910
Operations and maintenance			60,819						22,033						121,187						65,691
Selling, general and administrative			49,107						67,601						157,048						165,952
Transaction and integration costs			2,739						5,620						4,787						12,387
Depreciation and amortization			48,670						35,793						125,160						106,439
Asset impairment expense			—						—						—						48,109
Total operating expenses			364,868						545,195						1,047,155						1,335,017
Operating income			149,594						186,735						607,783						486,886
Interest expense			64,822						63,588						200,891						156,344
Other (income) expense, net			(2,271)						10,214						16,150						(31,613)
Loss on extinguishment of debt, net			—						14,997						—						14,997
Income before income from equity method investments and income taxes			87,043						97,936						390,742						347,158
Income (loss) from equity method investments			489						(31,734)						12,738						(354,426)
Tax provision (benefit)			25,194						9,971						69,476						(126,249)
Net income			62,338						56,231						334,004						118,981
Net (income) loss attributable to non-controlling interest			(1,117)						5,617						(3,329)						11,371
Net income attributable to stockholders			$	61,221					$	61,848					$	330,675					$	130,352
Net income per share – basic			$	0.30					$	0.30					$	1.60					$	0.62
Net income per share – diluted			$	0.30					$	0.29					$	1.59					$	0.62
Weighted average number of shares outstanding – basic			205,032,928						209,629,936						206,249,474						209,749,139
Weighted average number of shares outstanding – diluted			205,032,928						209,800,427						206,804,833						209,869,058
Other comprehensive income (loss):
Net income			$	62,338					$	56,231					$	334,004					$	118,981
Currency translation adjustment			(11,356)						(33,087)						7,693						48,040
Comprehensive income			50,982						23,144						341,697						167,021
Comprehensive (income) loss attributable to non-controlling interest			(795)						6,085						(3,108)						11,029
Comprehensive income attributable to stockholders			$	50,187					$	29,229					$	338,589					$	178,050

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

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New Fortress Energy Inc.

Condensed Consolidated Statements of Changes in Stockholders’ Equity

For the three and nine months ended September 30, 2023 and 2022

(Unaudited, in thousands of U.S. dollars, except share amounts)

																					Class A common stock												Additional paid-in capital						Retained earnings						Accumulated other comprehensive income						Non- controlling interest						Total stockholders’ equity
																											Shares																																				Amount
Balance as of December 31, 2022																											208,770,088						$	2,088					$	1,170,254					$	62,080					$	55,398					$	152,039					$	1,441,859
Net income																											—						—						—						150,206						—						1,360						151,566
Other comprehensive income																											—						—						—						—						1,946						195						2,141
Cancellation of shares																											(4,100,000)						(41)						(122,713)						—						—						—						(122,754)
Dividends																											—						—						—						(20,467)						—						(3,019)						(23,486)
Balance as of March 31, 2023																											204,670,088						$	2,047					$	1,047,541					$	191,819					$	57,344					$	150,575					$	1,449,326
Net income																											—						—						—						119,248						—						852						120,100
Other comprehensive income (loss)																											—						—						—						—						17,002						(94)						16,908
Share-based compensation expense																											—						—						1,179						—						—						—						1,179
Issuance of shares for vested share-based compensation awards																											689,401						3						—						—						—						—						3
Shares withheld from employees related to share-based compensation, at cost																											(328,083)						—						(9,519)						—						—						—						(9,519)
Dividends																											—						—						—						(20,503)						—						(6,619)						(27,122)
Balance as of June 30, 2023																											205,031,406						$	2,050					$	1,039,201					$	290,564					$	74,346					$	144,714					$	1,550,875
Net income																											—						—						—						61,221						—						1,117						62,338
Other comprehensive loss																											—						—						—						—						(11,034)						(322)						(11,356)
Share-based compensation expense																											—						—						227						—						—						—						227
Dividends																											—						—						—						(20,503)						—						(3,019)						(23,522)
Balance as of September 30, 2023																											205,031,406						$	2,050					$	1,039,428					$	331,282					$	63,312					$	142,490					$	1,578,562

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															Class A common stock												Additional paid-in capital						Retained earnings (Accumulated deficit)						Accumulated other comprehensive income (loss)						Non- controlling interest						Total stockholders’ equity
																																																						Shares						Amount
Balance as of December 31, 2021																											206,863,242						$	2,069					$	1,923,990					$	(132,399)					$	(2,085)					$	202,479					$	1,994,054
Net income																											—						—						—						238,269						—						2,912						241,181
Other comprehensive income																											—						—						—						—						118,874						1,956						120,830
Share-based compensation expense																											—						—						880						—						—						—						880
Issuance of shares for vested RSUs																											1,121,255						7						—						—						—						—						7
Shares withheld from employees related to share-based compensation, at cost																											(442,146)						—						(15,274)						—						—						—						(15,274)
Dividends																											—						—						(20,754)						—						—						(3,019)						(23,773)
Balance as of March 31, 2022																											207,542,351						$	2,076					$	1,888,842					$	105,870					$	116,789					$	204,328					$	2,317,905
Net loss																											—						—						—						(169,765)						—						(8,666)						(178,431)
Other comprehensive loss																											—						—						—						—						(38,557)						(1,146)						(39,703)
Share-based compensation expense																											—						—						358						—						—						—						358
Issuance of shares for vested RSUs																											13,898						—						—						—						—						—						—
Dividends																											—						—						(20,582)						—						—						(7,019)						(27,601)
Balance as of June 30, 2022																											207,556,249						$	2,076					$	1,868,618					$	(63,895)					$	78,232					$	187,497					$	2,072,528
Net income (loss)																											—						—						—						61,848						—						(5,617)						56,231
Other comprehensive loss																											—						—						—						—						(32,619)						(468)						(33,087)
Share-based compensation expense																											—						—						13,417						—						—						—						13,417
Issuance of shares for vested RSU/PSUs																											2,291,060						12						(12)						—						—						—						—
Shares withheld from employees related to share-based compensation, at cost																											(1,077,221)						—						(59,548)						—						—						—						(59,548)
Deconsolidation of vessels																											—						—						—						—						—						(23,569)						(23,569)
Dividends																											—						—						(20,756)						—						—						(3,019)						(23,775)
Balance as of September 30, 2022																											208,770,088						$	2,088					$	1,801,719					$	(2,047)					$	45,613					$	154,824					$	2,002,197

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

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New Fortress Energy Inc.

Condensed Consolidated Statements of Cash Flows

For the nine months ended September 30, 2023 and 2022

(Unaudited, in thousands of U.S. dollars)

			Nine Months Ended September 30,
			2023						2022
Cash flows from operating activities
Net income			$	334,004					$	118,981
Adjustments for:
Depreciation and amortization			125,853						107,185
(Earnings) losses of equity method investees			(12,738)						354,426
Dividends received from equity method investees			5,830						23,195
Change in market value of derivatives			(2,672)						(6,700)
Deferred taxes			1,217						(203,026)
Asset impairment expense			—						48,109
Earnings recognized from vessels chartered to third parties transferred to Energos			(112,608)						(14,341)
Loss on the disposal of equity method investment			37,401						—
Loss on extinguishment of debt			—						14,997
Loss on sale of net investment in lease			—						11,592
Other			2,211						15,464
Changes in operating assets and liabilities:
(Increase) in receivables			(86,743)						(287,748)
(Increase) in inventories			(29,238)						(28,078)
Decrease (Increase) in other assets			56,512						(93,329)
Decrease in right-of-use assets			68,360						51,265
Increase (decrease) in accounts payable/accrued liabilities			73,211						(10,487)
Increase (decrease) in amounts due to affiliates			1,613						(3,220)
(Decrease) in lease liabilities			(56,908)						(47,237)
Increase in other liabilities			131,879						40,057
Net cash provided by operating activities			537,184						91,105
Cash flows from investing activities
Capital expenditures			(2,191,605)						(787,166)
Sale of equity method investment			100,000						—
Proceeds from sale of net investment in lease			—						593,000
Other investing activities			26,043						(1,794)
Net cash used in investing activities			(2,065,562)						(195,960)
Cash flows from financing activities
Proceeds from borrowings of debt			1,768,715						1,932,020
Payment of deferred financing costs			(18,064)						(16,093)
Repayment of debt			(104,530)						(1,518,471)
Payments related to tax withholdings for share-based compensation			(9,519)						(72,597)
Payment of dividends			(700,440)						(75,149)
Other financing activities			(12,090)						—
Net cash provided by financing activities			924,072						249,710
Impact of changes in foreign exchange rates on cash and cash equivalents			923						(4,896)
Net (decrease) increase in cash, cash equivalents and restricted cash			(603,383)						139,959
Cash, cash equivalents and restricted cash – beginning of period			855,083						264,030
Cash, cash equivalents and restricted cash – end of period			$	251,700					$	403,989
Supplemental disclosure of non-cash investing and financing activities:
Changes in accounts payable and accrued liabilities associated with construction in progress and property, plant and equipment additions			$	641,967					$	112,886
Principal payments on financing obligation to Energos by third party charterers			(52,035)						(5,438)
Shares received in Hilli Exchange			(122,754)						—

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Investment in Energos			—						129,518
Non-cash financing			—						41,264

The following table identifies the balance sheet line-items included in Cash and cash equivalents, Current restricted cash, and Non-current restricted cash presented in the Condensed Consolidated Statement of Cash Flows:

			Nine Months Ended September 30,
			2023						2022
Cash and cash equivalents			$	171,329					$	364,313
Current restricted cash			66,162						24,204
Non-current restricted cash			—						2,581
Cash and cash equivalents classified as held for sale			14,209						12,891
Cash, cash equivalents and restricted cash – end of period			$	251,700					$	403,989

Cash and cash equivalents as of September 30, 2023 and 2022 includes $14,209 and $12,891, respectively, which have been classified as assets held for sale and included in Other current assets on the condensed consolidated balance sheets.

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

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1. Organization

New Fortress Energy Inc. (“NFE,” together with its subsidiaries, the “Company”), a Delaware corporation, is a global energy infrastructure company founded to help address energy poverty and accelerate the world’s transition to reliable, affordable and clean energy. The Company owns and operates natural gas and liquefied natural gas ("LNG") infrastructure, ships and logistics assets to rapidly deliver turnkey energy solutions to global markets. The Company has liquefaction, regasification and power generation operations in the United States, Jamaica, Brazil and Mexico. The Company has marine operations with vessels operating under time charters and in the spot market globally.

The Company currently conducts its business through two operating segments, Terminals and Infrastructure and Ships. The business and reportable segment information reflect how the Chief Operating Decision Maker (“CODM”) regularly reviews and manages the business.

2. Basis of presentation

The accompanying unaudited interim condensed consolidated financial statements contained herein were prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and reflect all normal and recurring adjustments which are, in the opinion of management, necessary to provide a fair statement of the financial position, results of operations and cash flows of the Company for the interim periods presented. These condensed consolidated financial statements and accompanying notes should be read in conjunction with the Company’s annual audited consolidated financial statements and accompanying notes included in its Annual Report on Form 10-K for the year ended December 31, 2022 (the "Annual Report"). Certain prior year amounts have been reclassified to conform to current year presentation.

The preparation of condensed consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions, impacting the reported amounts of assets and liabilities, net earnings and disclosures of contingent assets and liabilities as of the date of the condensed consolidated financial statements. Actual results could be different from these estimates.

3. Adoption of new and revised standards

The Company has reviewed recently issued accounting pronouncements and concluded that such pronouncements are either not applicable to the Company or no material impact is expected in the condensed consolidated financial statements as a result of future adoption.

4. Revenue recognition

Operating revenue in the condensed consolidated statements of operations and comprehensive income (loss) includes revenue from sales of LNG and natural gas as well as outputs from the Company’s natural gas-fueled power generation facilities, including power and steam, and the sale of LNG cargos. The Company did not have any LNG cargo sales in the third quarter of 2023. For the nine months ended September 30, 2023, the Company recognized LNG cargo sales to customers of $617,138, which included $332,000 of contract settlements. LNG cargo sales for the three and nine months ended September 30, 2022 were $350,550 and $944,751, respectively.

Under most customer contracts, invoicing occurs once the Company’s performance obligations have been satisfied, at which point payment is unconditional. As of September 30, 2023 and December 31, 2022, receivables related to revenue from contracts with customers totaled $351,160 and $280,382, respectively, and were included in Receivables, net on the condensed consolidated balance sheets, net of current expected credit losses of $1,133 and $884, respectively. Other items included in Receivables, net not related to revenue from contracts with customers represent leases, which are accounted for outside the scope of ASC 606, and receivables associated with reimbursable costs.

Contract assets are comprised of the transaction price allocated to completed performance obligations that will be billed to customers in subsequent periods. The Company has recognized contract liabilities, comprised of unconditional payments due or paid under the contracts with customers prior to the Company’s satisfaction of the related performance obligations. The contract assets and contract liabilities balances as of September 30, 2023 and December 31, 2022 are detailed below:

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			September 30, 2023						December 31, 2022
Contract assets, net - current			$	8,567					$	8,083
Contract assets, net - non-current			22,176						28,651
Total contract assets, net			$	30,743					$	36,734
Contract liabilities, net - current			$	69,254					$	12,748
Contract liabilities, net - non-current			41,818						—
Total contract liabilities, net			$	111,072					$	12,748
Revenue recognized in the year from:
Amounts included in contract liabilities at the beginning of the year			$	12,748					$	2,951

Contract assets are presented net of expected credit losses of $326 and $401 as of September 30, 2023 and December 31, 2022, respectively. As of September 30, 2023 and December 31, 2022, contract assets was comprised of $30,603 and $36,483 of unbilled receivables, respectively, which represent unconditional rights to payment only subject to the passage of time.

Contract liabilities increased during the nine months ended September 30, 2023 primarily due to upfront payments received under the Company's contracts in Puerto Rico to provide temporary power and to operate and maintain PREPA's power generation assets. These payments will be recognized as revenue over the expected term of these contracts.

The Company has recognized costs to fulfill contracts with customers, which primarily consist of expenses required to enhance resources to deliver under agreements with these customers. These costs can include set-up and mobilization costs incurred ahead of the service period, and such costs will be recognized on a straight-line basis over the expected terms of the agreements. As of September 30, 2023, the Company has capitalized $26,587 of which $2,753 of these costs is presented within Prepaid expenses and other current assets, net and $23,834 is presented within Other non-current assets, net on the condensed consolidated balance sheets. As of December 31, 2022, the Company had capitalized $10,377, of which $604 of these costs was presented within Prepaid expenses and other current assets, net and $9,773 was presented within Other non-current assets, net on the condensed consolidated balance sheets.

Transaction price allocated to remaining performance obligations

Some of the Company’s contracts are short-term in nature with a contract term of less than a year. The Company applied the optional exemption not to report any unfulfilled performance obligations related to these contracts.

The Company has arrangements in which LNG, natural gas or outputs from the Company’s power generation facilities are sold on a “take-or-pay” basis whereby the customer is obligated to pay for the minimum guaranteed volumes even if it does not take delivery. The price under these agreements is typically based on a market index plus a fixed margin. The fixed transaction price allocated to the remaining performance obligations under these arrangements represents the fixed margin multiplied by the outstanding minimum guaranteed volumes. The Company expects to recognize this revenue over the following time periods. The pattern of recognition reflects the minimum guaranteed volumes in each period:

Period			Revenue
Remainder of 2023			$	473,460
2024			2,044,859
2025			1,449,971
2026			528,514
2027			525,643
Thereafter			8,004,334
Total			$	13,026,781

For all other sales contracts that have a term exceeding one year, the Company has elected the practical expedient in ASC 606 under which the Company does not disclose the transaction price allocated to remaining performance obligations if the

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variable consideration is allocated entirely to a wholly unsatisfied performance obligation. For these excluded contracts, the sources of variability are (a) the market index prices of natural gas used to price the contracts, and (b) the variation in volumes that may be delivered to the customer. Both sources of variability are expected to be resolved at or shortly before delivery of each unit of LNG, natural gas, power or steam. As each unit of LNG, natural gas, power or steam represents a separate performance obligation, future volumes are wholly unsatisfied.

Lessor arrangements

Property, plant and equipment subject to vessel charters accounted for as operating leases is included within Vessels within "Note 12 Property, plant and equipment, net." Vessels included in the Energos Formation Transaction (defined below in "Note 10 Equity method investments"), including those vessels chartered to third parties, continue to be recognized on the condensed consolidated balance sheet. The carrying amount of these vessels that are leased to third parties under operating leases is as follows:

			September 30, 2023						December 31, 2022
Property, plant and equipment			$	917,563					$	1,292,957
Accumulated depreciation			(84,503)						(80,233)
Property, plant and equipment, net			$	833,060					$	1,212,724

The components of lease income from vessel operating leases for the three and nine months ended September 30, 2023 and 2022 are shown below. As the Company has not recognized the sale of all of the vessels included in the Energos Formation Transaction, the operating lease income shown below for the three and nine months ended September 30, 2023 is comprised of revenue from third-party charters of vessels included in the Energos Formation Transaction.

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Operating lease income			$	66,557					$	83,188					$	208,921					$	235,092
Variable lease income			730						8,238						730						19,470
Total operating lease income			$	67,287					$	91,426					$	209,651					$	254,562

Prior to the completion of the Energos Formation Transaction, the Company's charter of the Nanook was accounted for as a finance lease, and the Company recognized interest income of $5,517 and $28,643 for the three and nine months ended September 30, 2022, respectively, related to this finance lease, which was presented within Other revenue in the condensed consolidated statements of operations and comprehensive income (loss). The Company also recognized revenue of $1,434 and $5,852 for the three and nine months ended September 30, 2022, respectively, related to the operation and services agreement and variable charter revenue within Vessel charter revenue in the condensed consolidated statements of operations and comprehensive income (loss). The Company recognized the sale of the net investment in the finance lease of the Nanook as part of the Energos Formation Transaction.

Subsequent to the Energos Formation Transaction, all cash receipts on vessel charters, including the finance lease of the Nanook, will be received by Energos. As such, there are no future cash receipts from operating leases, and the future cash receipts from other finance leases are not significant as of September 30, 2023.

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5. Leases, as lessee

The Company has operating leases primarily for the use of LNG vessels, marine port space, office space, land and equipment under non-cancellable lease agreements. The Company’s leases may include multiple optional renewal periods that are exercisable solely at the Company’s discretion. Renewal periods are included in the lease term when the Company is reasonably certain that the renewal options would be exercised, and the associated lease payments for such periods are reflected in the right-of-use ("ROU") asset and lease liability.

The Company’s leases include fixed lease payments which may include escalation terms based on a fixed percentage or may vary based on an inflation index or other market adjustments. Escalations based on changes in inflation indices and market adjustments and other lease costs that vary based on the use of the underlying asset are not included as lease payments in the calculation of the lease liability or ROU asset; such payments are included in variable lease cost when the obligation that triggers the variable payment becomes probable. Variable lease cost includes contingent rent payments for office space based on the percentage occupied by the Company in addition to common area charges and other charges that are variable in nature. The Company also has a component of lease payments that are variable related to the LNG vessels, in which the Company may receive credits based on the performance of the LNG vessels during the period.

As of September 30, 2023 and December 31, 2022, ROU assets, current lease liabilities and non-current lease liabilities consisted of the following:

			September 30, 2023						December 31, 2022
Operating right-of-use-assets			$	418,265					$	355,883
Finance right-of-use-assets (1)			56,218						21,994
Total right-of-use assets			$	474,483					$	377,877
Current lease liabilities:
Operating lease liabilities			$	114,536					$	44,371
Finance lease liabilities			27,760						4,370
Total current lease liabilities			$	142,296					$	48,741
Non-current lease liabilities:
Operating lease liabilities			$	294,972					$	290,899
Finance lease liabilities			23,110						11,222
Total non-current lease liabilities			$	318,082					$	302,121

(1) Finance lease ROU assets are recorded net of accumulated amortization of $15,582 and $2,134 as of September 30, 2023 and December 31, 2022, respectively.

For the three and nine months ended September 30, 2023 and 2022, the Company’s operating lease cost recorded within the condensed consolidated statements of operations and comprehensive income (loss) was as follows:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Fixed lease cost			$	33,840					$	19,433					$	73,066					$	58,346
Variable lease cost			1,435						622						3,036						1,558
Short-term lease cost			11,502						6,204						17,421						12,326
Lease cost - Cost of sales			$	28,409					$	23,438					$	59,300					$	64,453
Lease cost - Operations and maintenance			16,274						1,066						28,322						2,675
Lease cost - Selling, general and administrative			2,094						1,755						5,901						5,102

For the three months ended September 30, 2023 and 2022, the Company has capitalized $8,111 and $4,005 of lease costs, respectively. For the nine months ended September 30, 2023 and 2022, the Company has capitalized $26,816 and $15,220

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of lease costs, respectively. Capitalized costs include vessels and port space used during the commissioning of development projects. Short-term lease costs for vessels chartered by the Company to transport inventory from a supplier’s facilities to the Company’s storage locations are capitalized to inventory.

The Company has leases of turbines, ISO tanks and a parcel of land that are recognized as finance leases. For the three and nine months ended September 30, 2023 and 2022, the Company’s finance interest expense and amortization recorded in Interest expense and Depreciation and amortization, respectively, within the condensed consolidated statements of operations and comprehensive income (loss) were as follows:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Interest expense related to finance leases			$	1,080					$	208					$	2,766					$	655
Amortization of right-of-use asset related to finance leases			5,888						378						13,448						1,137

Cash paid for operating leases is reported in operating activities in the condensed consolidated statements of cash flows. Supplemental cash flow information related to leases was as follows for the nine months ended September 30, 2023 and 2022:

			Nine Months Ended September 30,
			2023						2022
Cash outflows for operating lease liabilities			$	89,326					$	73,389
Cash outflows for finance lease liabilities			13,582						3,654
Right-of-use assets obtained in exchange for new operating lease liabilities			130,646						135,075
Right-of-use assets obtained in exchange for new finance lease liabilities			47,672						—

The future payments due under operating and finance leases as of September 30, 2023 are as follows:

			Operating Leases						Financing Leases
Due remainder of 2023			$	39,454					$	8,101
2024			137,439						29,997
2025			75,637						12,427
2026			52,744						3,041
2027			52,281						436
Thereafter			187,505						943
Total lease payments			$	545,060					$	54,945
Less: effects of discounting			135,552						4,075
Present value of lease liabilities			$	409,508					$	50,870
Current lease liability			$	114,536					$	27,760
Non-current lease liability			294,972						23,110

As of September 30, 2023, the weighted average remaining lease term for operating leases was 6.4 years and finance leases was 2.2 years. Because the Company generally does not have access to the rate implicit in the lease, the incremental borrowing rate is utilized as the discount rate. The weighted average discount rate associated with operating leases as of September 30, 2023 was 8.8% and as of December 31, 2022 was 8.5%. The weighted average discount rate associated with finance leases as of September 30, 2023 was 8.2% and as of December 31, 2022 was 5.1%.

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6. Financial instruments

Commodity risk management

The Company has utilized commodity swap transactions to manage exposure to changes in market pricing of natural gas or LNG. Realized and unrealized gains and losses on these transactions have been recognized in Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

During the fourth quarter of 2022, the Company entered into a commodity swap transaction to swap market pricing exposure for approximately 6.8 TBtus for a fixed price of $40.55 per MMBtu. The swap settled during the first quarter of 2023 resulting in a gain of $41,315 recognized as a reduction to Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss). The gain was comprised of a realized gain of $146,112 and the reversal of the unrealized gain of $104,797 recognized in the fourth quarter of 2022.

In January 2023, the Company entered into a series of commodity swap transactions. Mark-to-market unrealized gains of $975 for the three months ended September 30, 2023 and unrealized losses of $1,841 for the nine months ended September 30, 2023 on this instrument have been recognized in Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

Interest rate and currency risk management

The Company was party to an interest rate swap, and in the first quarter of 2023, the interest rate swap was terminated.

The Company does not hold or issue instruments for speculative purposes, and the counterparties to such contracts are major banking and financial institutions. Credit risk exists to the extent that the counterparties are unable to perform under the contracts; however, the Company does not anticipate non-performance by any counterparties.

The mark-to-market gain or loss on the interest rate swap and other derivative instruments that are not intended to mitigate commodity risk are reported in Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss).

Fair value

Fair value measurements and disclosures require the use of valuation techniques to measure fair value that maximize the use of observable inputs and minimize use of unobservable inputs. These inputs are prioritized as follows:

•Level 1 – observable inputs such as quoted prices in active markets for identical assets or liabilities.

•Level 2 – inputs other than quoted prices included within Level 1 that are observable, either directly or indirectly, such as quoted prices for similar assets or liabilities or market corroborated inputs.

•Level 3 – unobservable inputs for which there is little or no market data and which require the Company to develop its own assumptions about how market participants price the asset or liability.

The valuation techniques that may be used to measure fair value are as follows:

•Market approach – uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities.

•Income approach – uses valuation techniques, such as the discounted cash flow technique, to convert future amounts to a single present amount based on current market expectations about those future amounts.

•Cost approach – based on the amount that currently would be required to replace the service capacity of an asset (replacement cost).

The Company uses the market approach when valuing investment in equity securities which is recorded in Other non-current assets on the condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022.

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The Company uses the income approach when valuing the following financial instruments:

◦Interest rate swap - The Company did not have any interest rate swaps outstanding as of September 30, 2023. As of December 31, 2022, the Company had an interest rate swap that was recorded within Other non-current assets on the condensed consolidated balance sheets.

◦The liability and asset associated with commodity swaps are recorded within Other current liabilities and Prepaid expenses and other current assets on the condensed consolidated balance sheets as of September 30, 2023 and December 31, 2022, respectively.

◦Contingent consideration derivative liability represents consideration due to the sellers in asset acquisitions when certain contingent events occur. The liabilities associated with these derivative liabilities are recorded within Other current liabilities and Other long-term liabilities on the condensed consolidated balance sheets based on the timing of expected settlement.

The fair value of derivative instruments, including commodity swaps is estimated considering current interest rates, foreign exchange rates, closing quoted market prices and the creditworthiness of counterparties. The Company estimates fair value of the contingent consideration derivative liabilities using a discounted cash flows method with discount rates based on the average yield curve for bonds with similar credit ratings and matching terms to the discount periods as well as a probability of the contingent events occurring.

The following table presents the Company’s financial assets and financial liabilities, including those that are measured at fair value, as of September 30, 2023 and December 31, 2022:

						Level 1						Level 2						Level 3						Total
September 30, 2023
Assets
Investment in equity securities						$	—					$	—					$	7,678					$	7,678
Liabilities
Commodity swap						$	—					$	1,841					$	—					$	1,841
Contingent consideration derivative liabilities						—						—						40,946						40,946
December 31, 2022
Assets
Investment in equity securities						$	10,128					$	—					$	7,678					$	17,806
Interest rate swap						—						11,650						—						11,650
Commodity swap						—						104,797						—						104,797
Liabilities
Contingent consideration derivative liabilities						$	—					$	—					$	46,619					$	46,619

The Company believes the carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximated their fair value as of September 30, 2023 and December 31, 2022 and are classified as Level 1 within the fair value hierarchy.

The table below summarizes the fair value adjustment to instruments measured at Level 3 in the fair value hierarchy, including the contingent consideration derivative liabilities. These adjustments have been recorded within Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss) for the three and nine months ended September 30, 2023 and 2022:

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			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Contingent consideration derivative liabilities - Fair value adjustment - (gain) / loss			$	(2,722)					$	177					$	(5,757)					$	1,161
Foreign currency forward purchase - (gain)			—						(2,923)						—						(20,394)

During the nine months ended September 30, 2023 and 2022, the Company had no settlements or transfers in or out of Level 3 in the fair value hierarchy.

7. Restricted cash

As of September 30, 2023 and December 31, 2022, restricted cash consisted of the following:

			September 30, 2023						December 31, 2022
Cash restricted under the terms of loan agreements			$	3,825					$	124,085
Collateral for letters of credit and performance bonds			62,337						41,392
Collateral for interest rate swaps			—						2,500
Total restricted cash			$	66,162					$	167,977
Current restricted cash			$	66,162					$	165,396
Non-current restricted cash			—						2,581

As of September 30, 2023, the balance presented as collateral for letters of credit and performance bonds includes $21,300 to support a letter of credit to facilitate the purchase of turbines that was completed in the third quarter of 2023. A portion of these turbines will be utilized to support the Company's contract to generate temporary power in Puerto Rico.

Use of cash proceeds under the Barcarena Term Loan are restricted to certain payments to construct the Barcarena Power Plant (each as defined in our Annual Report). Non-current restricted cash is presented in Other non-current assets, net on the condensed consolidated balance sheets.

8. Inventory

As of September 30, 2023 and December 31, 2022, inventory consisted of the following:

			September 30, 2023						December 31, 2022
LNG and natural gas inventory			$	73,936					$	15,398
Automotive diesel oil inventory			9,848						8,164
Bunker fuel, materials, supplies and other			19,547						15,508
Total inventory			$	103,331					$	39,070

Inventory is adjusted to the lower of cost or net realizable value each quarter. Changes in the value of inventory are recorded within Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss). In the second quarter of 2023, the Company acquired a spot cargo at a higher cost to obtain a new customer contract. The net realizable value of this cargo was below the cost as of June 30, 2023, and as such, we recognized an adjustment to inventory of $6,232. No adjustments were recorded during the three months ended September 30, 2023 or the nine months ended September 30, 2022.

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9. Prepaid expenses and other current assets

As of September 30, 2023 and December 31, 2022, prepaid expenses and other current assets consisted of the following:

			September 30, 2023						December 31, 2022
Prepaid expenses			$	26,831					$	56,380
Recoverable taxes			68,748						37,504
Commodity swap			—						104,797
Due from affiliates			1,542						698
Assets held for sale			48,879						—
Other current assets			18,559						27,504
Total prepaid expenses and other current assets, net			$	164,559					$	226,883

Prepaid expenses as December 31, 2022 included $34,882 of prepaid LNG inventory. The Company does not have any significant prepaid LNG inventory as of September 30, 2023. Other current assets as of September 30, 2023 and December 31, 2022 primarily consists of deposits and the current portion of contract assets (Note 4).

Assets held for sale

In the third quarter of 2022, NFE Brazil Holdings LLC ("Brazil Holdings"), a consolidated indirect subsidiary of NFE and indirect owner of Pecém Energia S.A. (“Pecém”) and Energetica Camacari Muricy II S.A. (“Muricy”), and Centrais Elétricas de Pernambuco S.A. – EPESA (“EPESA”), entered into a Share Purchase Agreement pursuant to which Brazil Holdings agreed to sell 100% of the shares of Pecém and Muricy to EPESA, following an internal reorganization. The sale price includes cash consideration of BRL 59 million (approximately $12 million using the exchange rate as of September 30, 2023), as well as additional consideration for the satisfaction of certain milestones. Consideration under this agreement also includes potential future earnout payments based on the revenue generated from power purchase agreements held by Pecém and Muricy. The sale of Pecém and Muricy was approved by Agência Nacional de Energia Elétrica ("ANEEL") after the balance sheet date; the sale is subject to customary terms and conditions and conditions precedent prior to closing.

All assets and liabilities of Pecém and Muricy were classified as held for sale as of September 30, 2023 and December 31, 2022. The estimated fair value of these entities based on the consideration in the agreement was in excess of the carrying value, and no impairment loss was recognized upon classification as held for sale. Assets held for sale include a cash balance of $14,209 and $11,614 as of September 30, 2023 and December 31, 2022, respectively, which have been included in the ending cash and cash equivalents on the condensed consolidated statement of cash flows.

10. Equity method investments

Changes in the balance of the Company’s equity method investments is as follows:

			September 30, 2023
Equity method investments as of December 31, 2022			$	392,306
Dividends			(5,830)
Equity in earnings of investees			12,738
Sale of equity method investments			(260,156)
Equity method investments as of September 30, 2023			$	139,058

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The carrying amounts of the Company's equity method investments as of September 30, 2023 and December 31, 2022 are:

			September 30, 2023						December 31, 2022
Hilli LLC			$	—					$	260,000
Energos			139,058						132,306
Total			$	139,058					$	392,306

As of September 30, 2023, the carrying value of the Company’s equity method investment was less than its proportionate share of the underlying net assets of its investee by $1,548. At December 31, 2022, the carrying value of the Company’s equity method investments exceeded its proportionate share of the underlying net assets of its investees by $16,976, and the basis difference attributable to amortizable net assets was amortized to Income (loss) from equity method investments in the condensed consolidated statements of operations and comprehensive income (loss) over the remaining estimated useful lives of the underlying assets.

Hilli LLC

On March 15, 2023, the Company completed a transaction with Golar LNG Limited ("GLNG") for the sale of the Company's investment in the common units of Hilli LLC in exchange for approximately 4.1 million NFE shares and $100,000 in cash (the "Hilli Exchange"). In the fourth quarter of 2022, the Company recognized an other-than-temporary impairment on the investment in Hilli LLC of $118,558; this impairment was recognized in Income (loss) from equity method investments in the consolidated statements of operations and comprehensive income (loss). Upon completion of the Hilli Exchange, a loss on disposal of $37,401 was recognized in Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss). As a result of the Hilli Exchange, the Company no longer has an ownership interest in the Hilli. NFE shares received from GLNG were cancelled upon closing of the Hilli Exchange.

The Company had guaranteed 50% of the outstanding principal and interest amounts payable by Hilli Corp., a direct subsidiary of Hilli LLC. The Company had also guaranteed letters of credit issued by a financial institution in the event of Hilli Corp.’s underperformance or non-performance under the liquefaction tolling agreement with its customer. In conjunction with the Hilli Exchange, the Company is no longer a guarantor under these arrangements, and the remaining guarantee liability of $2,286 was derecognized as a reduction to Selling, general and administrative in the condensed consolidated statements of operations in the first quarter of 2023.

Energos

In August 2022, the Company completed a transaction (the “Energos Formation Transaction”) with an affiliate of Apollo Global Management, Inc., pursuant to which the Company transferred ownership of 11 vessel to Energos Infrastructure ("Energos") in exchange for approximately $1.85 billion in cash and a 20% equity interest in Energos. The Company's equity investment provides certain rights, including representation on the board of directors, which give the Company significant influence over the operations of Energos, and as such, the investment has been accounted for under the equity method; this investment is included within the Ships segment. Energos is also an affiliate, and all transactions with Energos are transactions with an affiliate.

Due to the timing and availability of financial information of Energos, the Company recognizes its proportional share of the income or loss from the equity method investment on a financial reporting lag of one fiscal quarter. For the three and nine months ended September 30, 2023, the Company has recognized earnings from Energos of $489 and $6,752.

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11. Construction in progress

The Company’s construction in progress activity during the nine months ended September 30, 2023 is detailed below:

			September 30, 2023
Construction in progress as of December 31, 2022			$	2,418,608
Additions			2,889,770
Impact of currency translation adjustment			13,811
Assets placed in service			(532,390)
Construction in progress as of September 30, 2023			$	4,789,799

Interest expense of $201,890 and $56,778, inclusive of amortized debt issuance costs, was capitalized for the nine months ended September 30, 2023 and 2022, respectively.

The Company has significant development activities in Latin America as well as the development of the Company's Fast LNG liquefaction solution, and the completion of such developments are subject to risks of successful completion, including those related to government approvals, site identification, financing, construction permitting and contract compliance. The Company's development activities for the nine months ended September 30, 2023 were primarily focused on Fast LNG and the construction of temporary power generation assets to support the Puerto Rican grid stabilization project; additions to construction in progress in the first nine months of 2023 of $2,569,197 were to develop Fast LNG projects and Puerto Rican temporary power.

Assets placed in service during 2023 are primarily comprised of assets to support our Puerto Rican temporary power project and our power plant at the Port of Pichilingue in Baja California Sur, Mexico.

12. Property, plant and equipment, net

As of September 30, 2023 and December 31, 2022, the Company’s property, plant and equipment, net consisted of the following:

			September 30, 2023						December 31, 2022
Vessels			$	1,527,684					$	1,518,839
Terminal and power plant equipment			430,883						218,296
CHP facilities			273,978						123,897
Gas terminals			179,103						177,780
ISO containers and other equipment			148,756						134,324
LNG liquefaction facilities			63,316						63,316
Gas pipelines			66,319						65,985
Land			52,759						52,995
Leasehold improvements			152,962						9,377
Accumulated depreciation			(331,889)						(248,082)
Total property, plant and equipment, net			$	2,563,871					$	2,116,727

The book value of the vessels that was recognized due to the failed sale leaseback in the Energos Formation Transaction as of September 30, 2023 and December 31, 2022 was $1,308,795 and $1,328,553, respectively.

Depreciation expense for the three months ended September 30, 2023 and 2022 totaled $36,705 and $26,326, respectively, of which $230 and $222, respectively, is included within Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss). Depreciation expense for the nine months ended September 30, 2023 and 2022 totaled $92,980 and $78,393, respectively, of which $693 and $749, respectively, is included within Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

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13. Goodwill and intangible assets

Goodwill

The carrying amount of goodwill was $776,760 as of both September 30, 2023 and December 31, 2022.

Intangible assets

The following tables summarize the composition of intangible assets as of September 30, 2023 and December 31, 2022:

			September 30, 2023
			Gross Carrying Amount						Accumulated Amortization						Currency Translation Adjustment						Net Carrying Amount						Weighted Average Life
Definite-lived intangible assets
Favorable vessel charter contracts			$	106,500					$	(82,373)					$	—					$	24,127					3
Permits and development rights			48,217						(5,020)						(2,207)						40,990						38
Easements			1,556						(330)						—						1,226						30
Indefinite-lived intangible assets
Easements			1,191						—						(91)						1,100						n/a
Total intangible assets			$	157,464					$	(87,723)					$	(2,298)					$	67,443

			December 31, 2022
			Gross Carrying Amount						Accumulated Amortization						Currency Translation Adjustment						Net Carrying Amount						Weighted Average Life
Definite-lived intangible assets
Favorable vessel charter contracts			$	106,500					$	(64,836)					$	—					$	41,664					3
Permits and development rights			48,217						(4,115)						(2,239)						41,863						38
Easements			1,556						(294)						—						1,262						30
Indefinite-lived intangible assets
Easements			1,191						—						(83)						1,108						n/a
Total intangible assets			$	157,464					$	(69,245)					$	(2,322)					$	85,897

Amortization expense for the three months ended September 30, 2023 and 2022 was $6,290 and $9,287, respectively. Amortization expense for the nine months ended September 30, 2023 and 2022 was $19,371 and $27,589, respectively. Amortization expense is inclusive of reductions in expense for the amortization of unfavorable contract liabilities.

Intangible assets associated with the acquired power purchase agreements have been classified as held for sale as of September 30, 2023 and December 31, 2022; no impairment loss was recognized upon classification as held for sale (See Note 9).

In the third quarter of 2023, An Bord Pleanála, Ireland's planning commission, denied the Company's application for the development of an LNG terminal and power plant in Shannon, Ireland. The Company is challenging this decision. Capitalized permits and development rights are primarily comprised of capitalized costs related to this project. The Company has concluded that these recent events do not indicate that these assets are not recoverable. The continued development of this project is uncertain and there are multiple risks, including regulatory risks, that could preclude the development of this project, and the results of these risks could have a material effect to the Company's results of operations.

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14. Other non-current assets, net

As of September 30, 2023 and December 31, 2022, Other non-current assets consisted of the following:

			September 30, 2023						December 31, 2022
Assets held for sale			$	—					$	40,685
Cost to fulfill (Note 4)			23,834						9,773
Contract assets, net (Note 4)			22,176						28,651
Upfront payments to customers			8,715						9,158
Investments in equity securities (Note 6)			7,678						17,806
Other			48,278						35,606
Total other non-current assets, net			$	110,681					$	141,679

During the third quarter of 2023, the Company sold certain investments in equity securities recognizing a realized loss of $374. The remaining investments in equity securities of $7,678 as of September 30, 2023 are investments without a readily determinable fair value.

The Company recognized unrealized losses of $672 and $1,629 on its investments in equity securities for the three months ended September 30, 2023 and 2022, respectively, within Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss). The Company recognized an unrealized gain of $539 and an unrealized loss of $2,720 on its investments in equity securities for the nine months ended September 30, 2023 and 2022, respectively, within Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss).

Upfront payments to customers consist of amounts the Company has paid in relation to two natural gas sales contracts with customers to construct fuel-delivery infrastructure that the customers will own. Other non-current assets includes deferred financing costs related to the Revolving Facility.

15. Accrued liabilities

As of September 30, 2023 and December 31, 2022, accrued liabilities consisted of the following:

			September 30, 2023						December 31, 2022
Accrued development costs			$	265,061					$	364,157
Accrued interest			72,970						51,994
Accrued inventory			29,800						45,511
Accrued bonuses			28,378						37,739
Accrued dividend			—						626,310
Other accrued expenses			39,483						36,701
Total accrued liabilities			$	435,692					$	1,162,412

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16. Other current liabilities

As of September 30, 2023 and December 31, 2022, other current liabilities consisted of the following:

			September 30, 2023						December 31, 2022
Derivative liabilities			$	20,045					$	19,458
Contract liabilities			69,254						12,748
Income tax payable			31,180						6,261
Due to affiliates			9,112						7,499
Liabilities held for sale (See Note 9)			21,407						—
Other current liabilities			18,746						6,912
Total other current liabilities			$	169,744					$	52,878

17. Debt

As of September 30, 2023 and December 31, 2022, debt consisted of the following:

			September 30, 2023						December 31, 2022
Senior Secured Notes, due September 2025			$	1,245,069					$	1,243,351
Senior Secured Notes, due September 2026			1,484,944						1,481,639
Vessel Financing Obligation, due August 2042			1,369,701						1,406,091
Revolving Facility			866,600						—
Bridge Term Loan, due August 2024			391,764						—
South Power 2029 Bonds, due May 2029			216,782						216,177
Equipment Notes, due July 2026			195,399						—
Barcarena Term Loan, due February 2024			198,725						194,427
EB-5 Loan, due July 2028			37,256						—
Short-term Borrowings			161,835						—
Total debt			$	6,168,075					$	4,541,685
Current portion of long-term debt and short-term borrowings			$	270,547					$	64,820
Long-term debt			5,897,528						4,476,865

Long-term debt is recorded at amortized cost on the condensed consolidated balance sheets. The fair value of the Company's long-term debt is $6,014,096 and $4,327,311 as of September 30, 2023 and December 31, 2022, respectively, and is classified as Level 2 within the fair value hierarchy.

Subsequent to September 30, 2023, the Company entered into the BNDES Credit Agreement, Barcarena Debentures and Term Loan B Credit Agreement (each defined and described in Note 24. Subsequent events). Proceeds from these new credit arrangements have been or will be used to refinance the Bridge Term Loan and the Barcarena Term Loan on a long term basis, and as such, these principal balances have been shown as non-current on the condensed consolidated balance sheets as of September 30, 2023.The terms of the Company's debt instruments have been described in the Annual Report on Form 10-K. Significant changes to the Company's outstanding debt are described below.

Revolving Facility

In April 2021, the Company entered into a $200,000 senior secured revolving credit facility (the "Revolving Facility"). The borrowings under the Revolving Facility bear interest at a Secured Overnight Financing Rate ("SOFR") based rate plus a margin based upon usage of the Revolving Facility. The Revolving Facility will mature in 2026 if the 2025 Notes (as

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defined in the Annual Report) are refinanced prior to maturity, with the potential for the Company to extend the maturity date of the Revolving Facility once for a one-year increment; if not, the Revolving Facility becomes due approximately 60 days prior to the maturity of the 2025 Notes. Borrowings under the Revolving Facility may be prepaid, at the option of the Company, at any time without premium.

In 2022, the Revolving Facility was amended twice to increase the borrowing capacity by a total of $240,000, and in first three quarters of 2023, the Company entered into amendments which increased the borrowing capacity by $426,600, for a total capacity of $866,600. The amendments did not impact the interest rate or term of the Revolving Facility, and no deferred costs were written off. During the first nine months of 2023, the Company drew $866,600 from the Revolving Facility, which is outstanding as of September 30, 2023.

The Company incurred $5,398 in origination, structuring and other fees, associated with entry into the Revolving Facility, which includes additional fees to expand the facility in 2022. During the first three quarters of 2023, the Company incurred an additional $7,027 in fees in relation to the 2023 amendments. These costs have been capitalized within Other non-current assets on the condensed consolidated balance sheets. As of September 30, 2023 and December 31, 2022, total remaining unamortized deferred financing costs for the Revolving Facility was $10,167 and $5,172, respectively.

The obligations under the Revolving Facility are guaranteed by certain of the Company's subsidiaries. The Company is required to comply with covenants under the Revolving Facility and letter of credit facility, including requirements to maintain Debt to Capitalization Ratio of less than 0.7:1.0, and for quarters in which the Revolving Facility is greater than 50% drawn, the Debt to Annualized EBITDA Ratio must be less than 5.0:1.0 for fiscal quarters ending December 31, 2021 until September 30, 2023 and less than 4.0:1.0 for the fiscal quarter ended December 31, 2023 and onwards. The Company was in compliance with all covenants as of September 30, 2023.

Bridge Term Loan Credit Agreement

On August 3, 2023, the Company entered into a Bridge Term Loan Credit Agreement (the “Bridge Term Loan Agreement”) pursuant to which the lenders funded term loans (the “Bridge Term Loans”) to the Company in an aggregate principal amount of $400,000. Bridge Term Loan proceeds may be used for working capital and other general corporate purposes. The Bridge Term Loans were to mature on August 1, 2024 and were payable in full on the maturity date. The Bridge Term Loans were repaid in full without penalty using proceeds from the Term Loan B which closed after September 30, 2023 (See Note 24. Subsequent events).

The Bridge Term Loans were guaranteed on a senior secured basis by each domestic and foreign subsidiary that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility (each as defined in the Annual Report). The Bridge Term Loans were secured by substantially the same collateral as the first lien obligations under the 2025 Notes, 2026 Notes and Revolving Facility. The Bridge Term Loan Agreement contained usual and customary representations and warranties, and usual and customary affirmative and negative covenants, including requirements to maintain certain levels of total debt to capitalization and total first lien debt to EBITDA, and the ratios required to be maintained were consistent with the requirements under the Revolving Facility.

The Bridge Term Loans bore interest at a per annum rate equal to Adjusted Term SOFR (as defined in the Bridge Term Loan Agreement) plus 3.50%. The Company incurred $9,628 in origination, structuring and other fees, associated with entry into the Bridge Term Loans Facility. As of September 30, 2023, total remaining unamortized deferred financing costs for the Bridge Term Loans was $8,236.

Equipment Notes

In June 2023, the Company executed a Master Loan and Security Agreement with a lender to borrow up to $200,000 under promissory notes secured by certain turbines acquired in the first quarter of 2023 to support our grid stabilization project in Puerto Rico (the “Equipment Notes”). During the second and third quarters of 2023, the Company borrowed the full

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capacity bearing interest at approximately 7.7%, and the principal is partially repayable in monthly installments over the 36 month term of the loan with the balance due upon maturity in July 2026.

The Equipment Notes contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. The Equipment Notes do not contain any restrictive financial covenants.

Proceeds received were net of upfront fees due to the lender, and through September 30, 2023, the Company has incurred $2,516 in origination, structuring and other fees, associated with entry into the Equipment Notes. As of September 30, 2023, total remaining unamortized deferred financing costs for the Equipment Notes was $2,423.

EB-5 Loan Agreement

On July 21, 2023, the Company entered into a loan agreement under the U.S. Citizenship and Immigration Services EB-5 Program (“EB-5 Loan Agreement”) to pay for the development and construction of a new green hydrogen facility in Texas. The maximum aggregate principal amount available under the EB-5 Loan Agreement is $100,000, and outstanding borrowings bear interest at a fixed rate of 4.75%. The loan matures in 5 years from the initial advance with an option to extend the maturity by two one-year periods. It is expected that the loan will be secured by NFE's green hydrogen facility, and NFE has provided a guarantee of the obligations under the EB-5 Loan Agreement. In the third quarter of 2023, $37,928 was funded under the EB-5 Loan Agreement.

The EB-5 Loan Agreement contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. The EB-5 Loan Agreement does not contain any restrictive financial covenants.

The Company has incurred $693 in origination, structuring and other fees, associated with entry into the EB-5 Loan Agreement. As of September 30, 2023, total remaining unamortized deferred financing costs for the EB-5 Loan Agreement was $672.

Short-term Borrowings

The Company may, from time to time, enter into sales and repurchase agreements with a financial institution, whereby the Company sells to the financial institution an LNG cargo and concurrently enters into an agreement to repurchase the same LNG cargo immediately with the repurchase price payable at a future date, generally not to exceed 90-days from the date of the sale and repurchase (the “Short-term Borrowings”). As of September 30, 2023, the Company had $161,835 due under repurchase arrangements with a weighted average interest rate of 9.74%.

Interest expense

Interest and related amortization of debt issuance costs, premiums and discounts recognized during major development and construction projects are capitalized and included in the cost of the project. Interest expense, net of amounts capitalized, recognized for the three and nine months ended September 30, 2023 and 2022 consisted of the following:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Interest per contractual rates			$	89,908					$	58,740					$	229,327					$	174,751
Interest expense on Vessel Financing Obligation			52,373						29,340						159,168						29,340
Amortization of debt issuance costs, premiums and discounts			4,777						2,583						11,520						8,376
Interest expense incurred on finance lease obligations			1,080						208						2,766						655
Total interest costs			$	148,138					$	90,871					$	402,781					$	213,122
Capitalized interest			83,316						27,283						201,890						56,778
Total interest expense			$	64,822					$	63,588					$	200,891					$	156,344

Interest expense on the Vessel Financing Obligation includes non-cash expense of $37,285 and $119,648 for the three and nine months ended September 30, 2023 related to payments received by Energos from third-party charterers.

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18. Income Taxes

The effective tax rate for the three months ended September 30, 2023 was 28.8% compared to 15.1% for the three months ended September 30, 2022. The total tax provision for the three months ended September 30, 2023 was $25,194 compared to a provision of $9,971 for the three months ended September 30, 2022. The Company’s current and prior year interim period effective tax rate and tax provision differ primarily due to significant discrete items recognized in the prior year including the windfalls from share-based compensation and the other-than-temporary impairment recognized on the Company's investment in CELSEPAR.

The effective tax rate for the nine months ended September 30, 2023 was 17.2% compared to 1,737.1% for the nine months ended September 30, 2022. The total tax provision for the nine months ended September 30, 2023 was $69,476 compared to a benefit of $126,249 for the nine months ended September 30, 2022. Our prior year benefit and effective tax rate was primarily driven by significant discrete items, including the remeasurement of a deferred tax liability in conjunction with an internal reorganization. The Company has not recognized any significant discrete items in the first nine months of 2023.

19. Commitments and contingencies

The Company may be subject to certain legal proceedings, claims and disputes that arise in the ordinary course of business. The Company does not believe that these proceedings, individually or in the aggregate, will have a material adverse effect on the Company’s financial position, results of operations or cash flows.

20. Earnings per share

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Numerator:
Net income (loss)			$	62,338					$	56,231					$	334,004					$	118,981
Net (income) loss attributable to non-controlling interests			(1,117)						5,617						(3,329)						11,371
Net income attributable to Class A common stock			$	61,221					$	61,848					$	330,675					$	130,352
Denominator:
Weighted-average shares - basic			205,032,928						209,629,936						206,249,474						209,749,139
Net income per share - basic			$	0.30					$	0.30					$	1.60					$	0.62
Diluted
Numerator:
Net income (loss)			$	62,338					$	56,231					$	334,004					$	118,981
Net (income) loss attributable to non-controlling interests			(1,117)						5,617						(3,329)						11,371
Adjustments attributable to dilutive securities			—						—						(1,113)						—
Net income (loss) attributable to Class A common stock			61,221						61,848						329,562						130,352
Denominator:
Weighted-average shares - diluted			205,032,928						209,800,427						206,804,833						209,869,058
Net income per share - diluted			$	0.30					$	0.29					$	1.59					$	0.62

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The following table presents potentially dilutive securities excluded from the computation of diluted net income per share for the periods presented because its effects would have been anti-dilutive.

			Three Months Ended September 30,												Nine Months Ended September 30,
			2023						2022						2023						2022
Equity Agreement shares (1)			555,359						422,680						—						422,680
Total			555,359						422,680						—						422,680

(1) Represents Class A common stock that would be issued in relation to an agreement to issue shares executed in conjunction with a prior year asset acquisition.

In the fourth quarter of 2022, the Board declared a dividend of $626,310 representing $3.00 per Class A share, which was paid in January 2023. The Company also declared and paid dividends of $20,503 and $20,756 during the three months ended September 30, 2023 and 2022, respectively, representing $0.10 per Class A share. The Company declared and paid dividends of $61,473 and $62,092 during the nine months ended September 30, 2023 and 2022, respectively, representing $0.10 per Class A share.

During each of the three months ended September 30, 2023 and 2022, the Company paid dividends of $3,019 to holders of Golar LNG Partners LP's ("GMLP") 8.75% Series A Cumulative Redeemable Preferred Units (“Series A Preferred Units”). During each of the nine months ended September 30, 2023 and 2022, the Company paid dividends of $9,057 to holders of the Series A Preferred Units. As these equity interests have been issued by one of the Company’s consolidated subsidiaries, the value of the Series A Preferred Units is recognized as non-controlling interest in the condensed consolidated financial statements.

21. Share-based compensation

The Company has granted Performance Share Units ("PSUs") to certain employees and non-employees that contain a performance condition under the New Fortress Energy Inc. 2019 Omnibus Incentive Plan. Vesting is determined based on achievement of a performance metric for the year subsequent to the grant, and the number of shares that will vest can range from zero to a multiple of units granted. As of September 30, 2023, the Company determined it was not probable that the performance condition required for the PSUs granted in the fourth quarter of 2022 ("2022 Grant") to vest would be achieved, and as such, no compensation expense was recognized for this award.

PSUs Granted

Units Granted

Range of Vesting

Units Vested / Probable of Vesting

Unrecognized Compensation Cost(1)

Weighted Average Remaining Vesting Period

2022 Grant

746,296

0 to 1,492,592

—

$

47,797

0.25 years

(1) Unrecognized compensation cost is based upon the maximum amount of shares that could vest.

22. Related party transactions

Management services

Messrs. Edens, chief executive officer and chairman of the Board of Directors, and Nardone, member of the Board of Directors, are currently employed by Fortress Investment Group LLC (“Fortress”). In the ordinary course of business, Fortress, through affiliated entities, charges the Company for administrative and general expenses incurred pursuant to its Administrative Services Agreement (“Administrative Agreement”). The charges under the Administrative Agreement that are attributable to the Company totaled $1,643 and $1,117 for the three months ended September 30, 2023 and 2022, respectively, and totaled $4,284 and $3,776 for the nine months ended September 30, 2023 and 2022, respectively. Costs associated with the Administrative Agreement are included within Selling, general and administrative in the condensed consolidated statements of operations and comprehensive income (loss). As of September 30, 2023 and December 31, 2022, $4,130 and $4,629 were due to Fortress, respectively.

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In addition to administrative services, an affiliate of Fortress owns and leases an aircraft chartered by the Company for business purposes in the course of operations. The Company incurred, at aircraft operator rates, charter costs of $523 and $750 for the three months ended September 30, 2023 and 2022, respectively, and $1,934 and $2,897 for the nine months ended September 30, 2023 and 2022, respectively. As of September 30, 2023 and December 31, 2022, $1,216 and $416 was due to this affiliate, respectively.

Fortress affiliated entities

The Company provides certain administrative services to related parties including Fortress affiliated entities. No costs are incurred for such administrative services by the Company as the Company is fully reimbursed for all costs incurred. The Company has subleased a portion of office space to affiliates of entities managed by Fortress, and for the three months ended September 30, 2023 and 2022, $280 and $99 of rent and office related expenses were incurred by these affiliates, respectively. For the nine months ended September 30, 2023 and 2022, $821 and $491 of rent and office related expenses were incurred by these affiliates, respectively. As of September 30, 2023 and December 31, 2022, $1,456 and $700, respectively, were due from all Fortress affiliated entities.

Additionally, an entity formerly affiliated with Fortress and currently owned by Messrs. Edens and Nardone provides certain administrative services to the Company, as well as providing office space under a month-to-month non-exclusive license agreement. The Company incurred rent and administrative expenses of approximately $767 and $663 for the three months ended September 30, 2023 and 2022, respectively, and $2,016 and $1,845 for the nine months ended September 30, 2023 and 2022, respectively. As of September 30, 2023 and December 31, 2022, $3,698 and $2,455 were due to Fortress affiliated entities, respectively.

Land leases

The Company has leased land from Florida East Coast Industries, LLC (“FECI”), which is controlled by funds managed by an affiliate of Fortress. The Company recognized expense related to the land lease of $126 and $103 during the three months ended September 30, 2023 and 2022, respectively, and $378 and $310 during the nine months ended September 30, 2023 and 2022, respectively, which was included within Operations and maintenance in the condensed consolidated statements of operations and comprehensive income (loss). The Company has amounts due to FECI of $69 and $0 as of September 30, 2023 and December 31, 2022, respectively. As of September 30, 2023 and December 31, 2022, the Company has recorded a lease liability of $3,363 and $3,340, respectively, on the condensed consolidated balance sheets.

In September 2023, the Company entered into a lease agreement to lease land from Jefferson Terminal South LLC, which is an indirect, majority-owned subsidiary of a public company which is managed by an affiliate of Fortress. The Company recognized expense related to the land lease of $30 during three months ended and nine months ended September 30, 2023, which was included within Operations and maintenance in the condensed consolidated statements of operations and comprehensive income (loss). The Company does not have any amounts due to Jefferson Terminal South LLC as of September 30, 2023. As of September 30, 2023 the Company has recorded a lease liability of $4,003 on the condensed consolidated balance sheets.

DevTech investment

In August 2018, the Company entered into a consulting arrangement with DevTech Environment Limited (“DevTech”) to provide business development services to increase the customer base of the Company. DevTech also contributed cash consideration in exchange for a 10% interest in a consolidated subsidiary. The 10% interest was reflected as non-controlling interest in the Company’s condensed consolidated financial statements. The Company recognized approximately $117 and $111 in expense within Selling, general and administrative for the three months ended September 30, 2023 and 2022, respectively, and $318 and $328 in expense within Selling, general and administrative for the nine months ended September 30, 2023 and 2022, respectively. As of September 30, 2023 and December 31, 2022, $117 and $80 were due to DevTech, respectively.

23. Segments

As of September 30, 2023, the Company operates in two reportable segments: Terminals and Infrastructure and Ships:

•Terminals and Infrastructure includes the Company’s vertically integrated gas to power solutions, spanning the entire production and delivery chain from natural gas procurement and liquefaction to logistics, shipping, facilities

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and conversion or development of natural gas-fired power generation. Vessels that are utilized in the Company’s terminal or logistics operations are included in this segment.

Terminals and Infrastructure Operating Margin included the Company’s effective share of revenues, expenses and operating margin attributable to the Company's 50% investment in Centrais Elétricas de Sergipe Participações S.A. (“CELSEPAR”); the Company disposed of this investment in the fourth quarter of 2022.

Terminal and Infrastructure segment includes realized gains and losses from the settlement of derivative transactions entered into as economic hedges to reduce market risks associated with commodity prices.

•Ships includes vessels that are leased to customers under long-term or spot arrangements, and as of September 30, 2023, six vessels are included in this segment. The Company’s investment in Energos is also included in the Ships segment.

Ships Operating Margin included our effective share of revenue, expenses and operating margin attributable to our ownership of 50% of the common units of Hilli LLC prior to the disposition of this investment in first quarter of 2023.

The CODM uses Segment Operating Margin to evaluate the performance of the segments and allocate resources. Segment Operating Margin is defined as the segment’s revenue less cost of sales less operations and maintenance less vessel operating expenses, excluding unrealized gains or losses to financial instruments recognized at fair value.

Management considers Segment Operating Margin to be the appropriate metric to evaluate and compare the ongoing operating performance of the Company’s segments on a consistent basis across reporting periods as it eliminates the effect of items which management does not believe are indicative of each segment’s operating performance.

The table below presents segment information for the three and nine months ended September 30, 2023 and 2022:

			Three Months Ended September 30, 2023
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(4)						Consolidated
Statement of operations:
Total revenues			$	447,905					$	66,557					$	514,462					$	—					$	514,462
Cost of sales(1) (3)			192,343						—						192,343						(423)						191,920
Vessel operating expenses			—						11,613						11,613						—						11,613
Operations and maintenance			60,819						—						60,819						—						60,819
Segment Operating Margin			$	194,743					$	54,944					$	249,687					$	423					$	250,110
Balance sheet:
Total assets			$	8,738,875					$	1,057,495					$	9,796,370					$	—					$	9,796,370
Other segmental financial information:
Capital expenditures(2)			$	662,717					$	—					$	662,717					$	—					$	662,717

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			Nine Months Ended September 30, 2023
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(4)						Consolidated
Statement of operations:
Total revenues			$	1,446,017					$	230,315					$	1,676,332					$	(21,394)					$	1,654,938
Cost of sales(1) (3)			488,512						—						488,512						114,114						602,626
Vessel operating expenses			—						42,295						42,295						(5,948)						36,347
Operations and maintenance			121,187						—						121,187						—						121,187
Segment Operating Margin			$	836,318					$	188,020					$	1,024,338					$	(129,560)					$	894,778
Balance sheet:
Total assets			$	8,738,875					$	1,057,495					$	9,796,370					$	—					$	9,796,370
Other segmental financial information:
Capital expenditures(2)			$	2,911,345					$	—					$	2,911,345					$	—					$	2,911,345

			Three Months Ended September 30, 2022
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(4)						Consolidated
Statement of operations:
Total revenues			$	687,437					$	111,660					$	799,097					$	(67,167)					$	731,930
Cost of sales(3)			402,458						—						402,458						(8,628)						393,830
Vessel operating expenses			3,431						23,799						27,230						(6,912)						20,318
Operations and maintenance			30,079						—						30,079						(8,046)						22,033
Segment Operating Margin			$	251,469					$	87,861					$	339,330					$	(43,581)					$	295,749
Balance sheet:
Total assets			$	5,366,730					$	2,074,254					$	7,440,984					$	—					$	7,440,984
Other segmental financial information:
Capital expenditures(2)			$	451,360					$	12,690					$	464,050					$	—					$	464,050

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			Nine Months Ended September 30, 2022
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(4)						Consolidated
Statement of operations:
Total revenues			$	1,711,241					$	337,626					$	2,048,867					$	(226,964)					$	1,821,903
Cost of sales(3)			909,938						—						909,938						(35,409)						874,529
Vessel operating expenses			11,178						71,029						82,207						(20,297)						61,910
Operations and maintenance			89,861						—						89,861						(24,170)						65,691
Segment Operating Margin			$	700,264					$	266,597					$	966,861					$	(147,088)					$	819,773
Balance sheet:
Total assets			$	5,366,730					$	2,074,254					$	7,440,984					$	—					$	7,440,984
Other segmental financial information:
Capital expenditures(2)			$	890,558					$	27,127					$	917,685					$	—					$	917,685

(1) Cost of sales in the Company’s segment measure only includes realized gains and losses on derivative transactions that are an economic hedge of commodity purchases and sales, and realized losses of $293 and realized gains of $141,560 for the three and nine months ended September 30, 2023, respectively, were recognized as a reduction to Cost of sales in the segment measure.

The Company recognized unrealized gains of $423 and unrealized losses of $107,882 on the mark-to-market value of derivative transactions for the three and nine months ended September 30, 2023, respectively, and these gains and losses reconcile Cost of sales in the segment measure to Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

The Company has excluded contract acquisition costs that do not meet the criteria for capitalization from the segment measure. Contract acquisition costs of $0 and $6,232 for the three and nine months ended September 30, 2023, respectively, reconcile Cost of sales in the segment measure to Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

(2) Capital expenditures includes amounts capitalized to construction in progress and additions to property, plant and equipment during the period.

(3) Cost of sales is presented exclusive of costs included in Depreciation and amortization in the condensed consolidated statements of operations and comprehensive income (loss).

(4) Consolidation and Other adjusts for the inclusion of the effective share of revenues, expenses and operating margin attributable to the Company's 50% ownership of CELSEPAR and the common units of Hilli LLC in the segment measure prior to the disposition of these investments, the exclusion of the unrealized mark-to-market gain or loss on derivative instruments, and the exclusion of non-capitalizable contract acquisition costs.

Consolidated Segment Operating Margin is defined as net income, adjusted for Selling, general and administrative expenses, Transaction and integration costs, Depreciation and amortization, Asset impairment expense, Interest expense, Other (income) expense, net, Loss on extinguishment of debt, net, Tax provision (benefit) and Income from equity method investments.

The following table reconciles Net income, the most comparable financial statement measure, to Consolidated Segment Operating Margin:

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			Three Months Ended September 30,												Nine Months Ended September 30,
(in thousands of $)			2023						2022						2023						2022
Net income			$	62,338					$	56,231					$	334,004					$	118,981
Add:
Selling, general and administrative			49,107						67,601						157,048						165,952
Transaction and integration costs			2,739						5,620						4,787						12,387
Depreciation and amortization			48,670						35,793						125,160						106,439
Asset impairment expense			—						—						—						48,109
Interest expense			64,822						63,588						200,891						156,344
Other (income) expense, net			(2,271)						10,214						16,150						(31,613)
Loss on extinguishment of debt, net			—						14,997						—						14,997
Tax provision (benefit)			25,194						9,971						69,476						(126,249)
(Income) from equity method investments			(489)						31,734						(12,738)						354,426
Consolidated Segment Operating Margin			$	250,110					$	295,749					$	894,778					$	819,773

24. Subsequent events

The financing transactions described below were entered into subsequent to September 30, 2023. Proceeds from these financing transactions, combined with the expected contractual cash flows from recent projects placed in service, are expected to provide the Company with the liquidity necessary to meets its obligations as they become due in the ordinary course of its business.

Barcarena Financings

In October 2023, certain of the Company's Brazilian subsidiaries entered into two long-term financing arrangements, fully funding the construction of the Company's power plant located in Pará, Brazil (the "Barcarena Power Plant"). Proceeds received will be used to repay the current Barcarena Term Loan and to pay for all remaining expected construction costs through the planned completion of the Barcarena Power Plant in 2025.

The owner of the Barcarena Power Plant entered into a credit agreement with BNDES, the Brazilian Development Bank (the "BNDES Credit Agreement"). The Company is able to borrow up to R$1.8 billion under the BNDES Credit Agreement, segregated into three tranches based on the use of proceeds ("BNDES Term Loan"). Each tranche bears a different rate of interest ranging from 2.61% to 4.41% plus the fixed rate announced by BNDES. No principal payments are required until April 2026 and are due quarterly thereafter until maturity in 2045.

The obligations under the BNDES Credit Agreement are guaranteed by certain indirect Brazilian subsidiaries that are constructing the Barcarena Power Plant, and are secured by the Barcarena Power Plant and receivables under the Barcarena Power Plant's PPAs. These Brazilian subsidiaries are required to comply with customary affirmative and negative covenants, and the BNDES Credit Agreement also provides for customary events of default, prepayment and cure provisions.

Additionally, the parent of the owner of the Barcarena Power Plant entered into an agreement for the issuance of up to $200 million of convertible debentures maturing in October 2028 ("Barcarena Debentures"). Interest on the Barcarena Debentures is due quarterly, and interest accrues at an annual rate of 12%, increasing 1.25% each year after the third anniversary of issuance. The Company is able to prepay the Barcarena Debentures, subject to customary break funding

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costs, and the Company is required to utilize certain excess cash flows from the Company's Brazilian operations to prepay principal.

The Barcarena Debentures are convertible to shares of one of the Company's indirect Brazilian subsidiaries on the maturity date at the creditors' option, based on the current fair value of this subsidiary's equity at the time of conversion.

The obligations under the Barcarena Debentures are guaranteed by certain indirect Brazilian subsidiaries that own Company's LNG regasification terminals located in Pará, Brazil ("Barcarena Terminal") and Santa Catarina, Brazil. NFE has also provided a parent company guarantee that will be released once the Barcarena Terminal commences commercial operations. Brazilian subsidiaries guaranteeing these obligations are required to comply with customary affirmative and negative covenants, and the Barcarena Debentures also provides for customary events of default, prepayment and cure provisions.

Term Loan B Credit Agreement

On October 30, 2023, the Company entered into a credit agreement (the “Term Loan B Agreement”) pursuant to which the lenders funded term loans to the Company in an aggregate principal amount of $856 million ("Term Loan B"). The proceeds from the Term Loan B issuance were used to repay the Bridge Term Loans and may be used for working capital and other general corporate purposes. The Term Loan B will mature in October 2028 if the 2025 Notes and 2026 Notes (each as defined in the Annual Report) are refinanced prior to their maturities; if not, the Term Loan B becomes due approximately 60 days prior to the maturity of each the 2025 Notes and 2026 Notes. Quarterly principal payments of approximately $2.1 million begin to be due starting March 2024.

The Term Loan B is guaranteed on a senior secured basis by each domestic subsidiary that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility (each as defined in the Annual Report) and will be guaranteed on a senior secured basis by each foreign guarantor that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility on a post-closing basis. The Term Loan B is and will be secured by substantially the same collateral as the first lien obligations under the 2025 Notes, 2026 Notes, the Company's letter of credit facility and Revolving Facility. Additionally the Term Loan B is secured by assets comprising the Company's first Fast LNG project in Altamira, Mexico.

The Term Loan B bears interest at a per annum rate equal to Adjusted Term SOFR (as defined in the Term Loan B Agreement) plus 5.0%. The Company may prepay the Term Loan B at its option subject to prepayment premiums until October 2025 and customary break funding costs. The Company is required to prepay the Term Loan B with the net proceeds of certain asset sales, condemnations, and debt and convertible securities issuances, in each case subject to certain exceptions and thresholds. Additionally, commencing with the fiscal quarter ending December 31, 2024, the Company will be required to prepay the Term Loan B with the Company’s Excess Cash Flow (as defined in the Term Loan B Agreement).

The Term Loan B Agreement contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. No financial covenant compliance is required under the Term Loan B Agreement.

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Item 2.    Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Certain information contained in the following discussion and analysis, including information with respect to our plans, strategy, projections and expected timeline for our business and related financing, includes forward-looking statements. Forward-looking statements are estimates based upon current information and involve a number of risks and uncertainties. Actual events or results may differ materially from the results anticipated in these forward-looking statements as a result of a variety of factors.

You should read “Risk Factors” and “Cautionary Statement on Forward-Looking Statements” elsewhere in this Quarterly Report on Form 10-Q (“Quarterly Report”) and under similar headings in the Annual Report on Form 10-K for the year ended December 31, 2022 (our “Annual Report”) for a discussion of important factors that could cause actual results to differ materially from the results described in or implied by the forward-looking statements contained in the following discussion and analysis.

The following information should be read in conjunction with our unaudited condensed consolidated financial statements and accompanying notes included elsewhere in this Quarterly Report. Our financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”). This information is intended to provide investors with an understanding of our past performance and our current financial condition and is not necessarily indicative of our future performance. Please refer to “—Factors Impacting Comparability of Our Financial Results” for further discussion. Unless otherwise indicated, dollar amounts are presented in millions.

Unless the context otherwise requires, references to “Company,” “NFE,” “we,” “our,” “us” or like terms refer to New Fortress Energy Inc. and its subsidiaries.

Overview

We are a global energy infrastructure company founded to help address energy poverty and accelerate the world’s transition to reliable, affordable and clean energy. We own and operate natural gas and liquefied natural gas ("LNG") infrastructure, and an integrated fleet of ships and logistics assets to rapidly deliver turnkey energy solutions to global markets; additionally, we have expanded our focus to building our modular LNG manufacturing business. Our near-term mission is to provide modern infrastructure solutions to create cleaner, reliable energy while generating a positive economic impact worldwide. Our long-term mission is to become one of the world’s leading companies providing power free from carbon emissions by leveraging our global portfolio of integrated energy infrastructure. We discuss this important goal in more detail in our Annual Report, “Items 1 and 2: Business and Properties” under “Sustainability—Toward a Very-Low Carbon Future.”

Our chief operating decision maker makes resource allocation decisions and assesses performance on the basis of two operating segments, Terminals and Infrastructure and Ships.

Our Terminals and Infrastructure segment includes the entire production and delivery chain from natural gas procurement and liquefaction to logistics, shipping, facilities and conversion or development of natural gas-fired power generation. We currently source LNG from long-term supply agreements with third-party suppliers and from our own liquefaction facility in Miami, Florida. Upon the completion of commissioning, we expect to begin to source a portion of our LNG from our modular floating liquefaction facilities, which we refer to as "Fast LNG" or "FLNG." The Terminals and Infrastructure segment includes all terminal operations in Jamaica, Puerto Rico, Mexico and Brazil, as well as vessels utilized in our terminal or logistics operations. We centrally manage our LNG supply and the deployment of our vessels utilized in our terminal or logistics operations, which allows us to optimally manage our LNG supply and fleet.

Our Ships segment includes all vessels which are leased to customers under long-term or spot arrangements. The Company’s investment in Energos (defined below) is also included in the Ships segment. Over time, we expect to utilize these vessels in our own terminal operations as charter agreements for these vessels expire.

Our Current Operations – Terminals and Infrastructure

Our management team has successfully employed our strategy to secure long-term contracts with significant customers, including Jamaica Public Service Company Limited (“JPS”), the sole public utility in Jamaica, South Jamaica Power Company Limited (“SJPC”), an affiliate of JPS, Jamalco, a bauxite mining and alumina producer in Jamaica, the Puerto Rico Electric Power Authority (“PREPA”), and Comisión Federal de Electricidad (“CFE”), Mexico’s power utility,

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each of which is described in more detail below. Our assets built to service these significant customers have been designed with capacity to service other customers.

Montego Bay Facility

The Montego Bay Facility serves as our supply hub for the north side of Jamaica, providing natural gas to JPS to fuel the 145MW Bogue power plant in Montego Bay, Jamaica ("Bogue Power Plant"). Our Montego Bay Facility commenced commercial operations in October 2016 and is capable of processing up to 61,000 MMBtu of LNG per day and features approximately 7,000 cubic meters of onsite storage. The Montego Bay Facility also consists of an ISO loading facility that can transport LNG to numerous on-island industrial users.

Old Harbour Facility

The Old Harbour Facility is an offshore facility consisting of an FSRU that is capable of processing up to 750,000 MMBtus of LNG per day. The Old Harbour Facility commenced commercial operations in June 2019 and supplies natural gas to the 190MW Old Harbour power plant (“Old Harbour Power Plant”) operated by SJPC. The Old Harbour Facility is also supplying natural gas to our dual-fired combined heat and power facility in Clarendon, Jamaica (“CHP Plant”). The CHP Plant supplies electricity to JPS under a long-term agreement. The CHP Plant also provides steam to Jamalco under a long-term take-or-pay agreement. The Old Harbour Facility also supplies gas directly to Jamalco to utilize in their gas-fired boilers.

San Juan Facility

Our San Juan Facility became fully operational in the third quarter of 2020. It is designed as a landed micro-fuel handling facility located in the Port of San Juan, Puerto Rico. The San Juan Facility has multiple truck loading bays to provide LNG to on-island industrial users. The San Juan Facility is near the PREPA San Juan Power Plant and serves as our supply hub for the PREPA San Juan Power Plant and other industrial end-user customers in Puerto Rico.

In the first and second quarters of 2023, we entered into agreements with Weston Solutions, Inc. ("Weston") for the installation and operation of approximately 350MW of additional power to be generated at the Palo Seco Power Plant and San Juan Power Plant in Puerto Rico as well as the supply of natural gas. Weston has been contracted by the U.S. Army Corps of Engineers to support the island’s grid stabilization project with additional power capacity to enable maintenance and repair work on Puerto Rico’s power system and grid. We commissioned 150MW of duel-fuel power generation using our gas supply in the second quarter of 2023, and the remaining 200MW was commissioned in September 2023.

In the first quarter of 2023, our wholly-owned subsidiary, Genera PR LLC ("Genera"), was awarded a 10-Year contract for the operation and maintenance of PREPA’s thermal generation assets with the goal of reducing costs and improving reliability of power generation in Puerto Rico. We will receive an annual management fee and be eligible for performance-based incentive fees, beginning after the service period under the contract commenced on July 1, 2023.

La Paz Facility

In July 2021, we began commercial operations at the Port of Pichilingue in Baja California Sur, Mexico (the “La Paz Facility”). The La Paz Facility is expected to supply approximately 22,300 MMBtu of LNG per day to our 100MW gas-fired modular power units (the “La Paz Power Plant”), which we placed into service in the third quarter of 2023. Natural gas supply to the La Paz Power Plant may be increased to approximately 29,000 MMBtu of LNG per day for up to 135MW of power.

In the fourth quarter of 2022, we finalized short-form agreements with CFE to expand and extend our supply of natural gas to multiple CFE power generation facilities in Baja California Sur and to sell the La Paz Power Plant to CFE. We executed the final long-form gas sales agreement in the second quarter of 2023, which is subject to certain conditions precedent including the execution of the final agreement to sell the La Paz Power Plant.

Miami Facility

Our Miami Facility began operations in April 2016. This facility has liquefaction capacity of approximately 8,300 MMBtu of LNG per day and enables us to produce LNG for sales directly to industrial end-users in southern Florida,

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including Florida East Coast Railway via our train loading facility, and other customers throughout the Caribbean using ISO containers.

Our LNG Supply and Cargo Sales

NFE provides reliable, affordable and clean energy supplies to customers around the world that we plan to satisfy through the following sources: 1) our current contractual supply commitments; 2) additional LNG supply contracts expected to commence in 2027; 3) our Miami Facility; and 4) supply from our own Fast LNG production. We have secured commitments to purchase and receive physical delivery of LNG volumes for 100% of our expected committed volumes for each of our downstream terminals inclusive of our Montego Bay Facility, Old Harbour Facility, San Juan Facility, La Paz Facility, Puerto Sandino Facility, Barcarena Facility and Santa Catarina Facility. Additionally, we have binding contracts for LNG volumes from two separate U.S. LNG facilities, each with a 20-year term, which are expected to commence in 2027. Finally, we plan to commence production from our own Fast LNG facilities upon the completion of commissioning. We plan to expand that capacity when additional Fast LNG units come online over the next two years.

The recent geopolitical events in Europe have substantially impacted the natural gas and LNG markets with unprecedented price increases and volatility. The majority of our LNG supply contracts are based on a natural gas-based index, Henry Hub, plus a contractual spread. We limit our exposure to fluctuations in natural gas prices as our pricing in contracts with customers is largely based on the Henry Hub index price plus a fixed fee component. Additionally, with our own Fast LNG production expected to commence in the fourth quarter of 2023, we plan to further mitigate our exposure to variability in LNG prices. Due to current market conditions, we expect that our revenue and results of operations will benefit in the near term from selling cargos into the elevated global LNG market. As FLNG facilities commence production, our long-term strategy is to sell substantially all cargos produced to customers on a long-term, take-or-pay basis through our downstream terminals.

Our Current Operations – Ships

Our Ships segment includes Floating Storage and Regasification Units ("FSRUs"), Floating Storage Units ("FSUs") and LNG carriers ("LNGCs"), which are leased to customers under long-term or spot arrangements. At the expiration of third party charters of vessels owned by Energos Infrastructure (“Energos”), an entity formed in 2022 and described in more detail below, we plan to charter these vessels for our own operational purposes. The results of operations of vessels utilized in our terminal operations are reflected in the Terminals and Infrastructure segment.

In August 2022, we completed a transaction (the “Energos Formation Transaction”) with an affiliate of Apollo Global Management, Inc., pursuant to which we transferred ownership of 11 vessel to Energos in exchange for approximately $1.85 billion in cash and a 20% equity interest in Energos. Ten of the vessels were subject to current or future charters with NFE and one vessel (the Nanook) was not subject to a future NFE charter. The in-place and future charters to NFE of ten vessels prevent the recognition of the sale of those vessels to Energos, and the proceeds associated with these vessels have been treated as a failed sale leaseback. As a result, these ten vessels continue to be recognized on our consolidated balance sheet as Property, plant and equipment, and the proceeds are recognized as debt. Consistent with this treatment as a failed sale leaseback, (i) the third party charter revenues continue to be recognized by us as Vessel charter revenue; (ii) the costs of operating the vessels is included in Vessel operating expenses for the remaining terms of the third-party charters and (iii) such revenues are included as part of debt service for the sale leaseback financing debt and are included in additional financing costs within Interest expense, net.

Our Development Projects

Our projects currently under development include our development of a series of modular floating liquefaction facilities to provide a source of low-cost supply of LNG to customers around the world through our Fast LNG technologies; our LNG terminal facility and power plant in Puerto Sandino, Nicaragua (“Puerto Sandino Facility”); our LNG terminal (“Barcarena Facility”) and power plant (“Barcarena Power Plant”) located in Pará, Brazil; our LNG terminal located on the southern coast of Brazil ("Santa Catarina Terminal"); and our LNG terminal (“Ireland Facility”) and power plant in Ireland. We are also in active discussions to develop projects in multiple regions around the world that may have significant demand for additional power, LNG and natural gas, although there can be no assurance that these discussions will result in additional contracts or that we will be able to achieve our target revenue or results of operations.

The design, development, construction and operation of our projects are highly regulated activities and subject to various approvals and permits. The process to obtain required permits, approvals and authorizations is complex, time-

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consuming, challenging and varies in each jurisdiction in which we operate. We obtain required permits, approvals and authorizations in due course in connection with each milestone for our projects.

We describe each of our current development projects below.

Fast LNG

We are currently developing multiple modular liquefaction facilities to provide a source of low-cost supply of LNG to customers around the world. We have designed and are constructing liquefaction facilities for our growing customer base that we believe are both faster and more economical to construct than many traditional liquefaction solutions. The “Fast LNG,” or “FLNG,” design pairs advancements in modular, midsize liquefaction technology with jack up rigs, semi-submersible rigs or similar marine floating infrastructure to enable a lower cost and faster deployment schedule than land-based site-built alternatives. Semi-permanently moored floating storage unit(s) (FSUs) will provide LNG storage alongside the floating liquefaction infrastructure, which can be deployed anywhere there is abundant and stranded natural gas. As noted below, we are also in discussions with CFE to utilize our FLNG design in an onshore application.

Our initial Fast LNG units are being constructed at the Kiewit Offshore Services shipyard near Corpus Christi, Texas. The Kiewit facility specializes in the fabrication and integration of offshore projects. In partnership with Kiewit, we believe we have established an efficient and repeatable process to reduce cost and time to build incremental liquefaction capacity. Our first Fast LNG unit is being deployed offshore to Altamira, Mexico, and we expect to deploy additional units over the next two years.

We plan to deploy several Fast LNG units at different locations around the world and describe our currently planned projects below.

Altamira

In the first quarter of 2023, we executed an agreement, which include conditions to effectiveness that have not been satisfied, with CFE to supply natural gas for one FLNG unit located off the coast of Altamira, Tamaulipas, Mexico. The 1.4 million ton per annum (“MTPA”) FLNG unit will utilize CFE’s firm pipeline transportation capacity on the Sur de Texas-Tuxpan Pipeline to receive feedgas volumes. Our first FLNG unit has been installed and connected to the gas pipeline at Altamira, and we are in process of commissioning the project.

We have also entered into a non-binding MOU with CFE to develop and operate an onshore liquefied natural gas terminal with up to four 1.4 MTPA FLNG units. The terminal is to be located at the existing Altamira LNG import facility and would source feedgas from the Sur de-Texas Tuxpan Pipeline. The Altamira onshore LNG facility is a world class import facility that will be converted to export LNG similar to other gulf coast regasification terminals. Existing infrastructure at the facility includes two 150,000m3 storage tanks, deepwater marine berth and access to local gas and power networks.

Louisiana

In addition, we are considering a plan to install up to two FLNG units approximately 16 nautical miles off the southeast coast of Grand Isle, Louisiana. We have filed applications with the U.S. Maritime Administration ("MARAD") and the U.S. Coast Guard to obtain our deepwater port license application for this facility. The facility will be capable of exporting up to approximately 145 billion cubic feet of natural gas per year, equivalent to approximately 2.8 MTPA of LNG.

Lakach

Also, in the fourth quarter of 2022, we finalized agreements, which include conditions to effectiveness that have not been satisfied, with Petróleos Mexicanos (“Pemex”) to form a long-term strategic partnership to develop the Lakach deepwater natural gas field for Pemex to supply natural gas to Mexico's onshore domestic market and for NFE to produce LNG for export to global markets. If the agreements become effective, NFE would invest in the continued development of the Lakach field over a two-year period by completing seven offshore wells and deploy a 1.4 MTPA Fast LNG unit to liquefy the majority of the produced natural gas. Remaining natural gas and associated condensate volumes would be utilized by Pemex in Mexico's onshore domestic market.

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Puerto Sandino Facility

We are developing an offshore facility consisting of an FSRU and associated infrastructure, including mooring and offshore pipelines, in Puerto Sandino, Nicaragua. We have entered into a 25-year PPA with Nicaragua’s electricity distribution companies, and we expect to utilize approximately 57,500 MMBtu from LNG per day to provide natural gas to the Puerto Sandino Power Plant in connection with the 25-year power purchase agreement. As part of our long-term partnership with the local utility, we are evaluating solutions to optimize power generation efficiency and allow for additional electrical capacity in a market that is underserved. We expect to complete this optimization in 2024.

Barcarena Facility

The Barcarena Facility consists of an FSRU and associated infrastructure, including mooring and offshore and onshore pipelines. The Barcarena Facility is capable of processing up to 790,000 MMBtu per day and storing up to 170,000 cubic meters of LNG. The Barcarena Facility is expected to supply gas to third-party industrial and power customers as well as the Barcarena Power Plant, a new 630MW combined cycle thermal power plant to be located in Pará, Brazil, which we own. The Barcarena Power Plant is supported by multiple 25-year power purchase agreements to supply electricity to the national electricity grid. The power project is scheduled to deliver power to nine committed offtakers for 25 years beginning in 2025. We substantially completed our Barcarena Facility in 2022 and expect to commence operations in the first quarter of 2024. We expect to complete the Barcarena Power Plant and to commence operations in 2025.

We have financed the development of the Barcarena Power Plant pursuant to a financing agreement. For information on this financing agreement, see “—Long-Term Debt and Preferred Stock” in our Annual Report.

Santa Catarina Facility

The Santa Catarina Facility will be located on the southern coast of Brazil and will consist of an FSRU with a processing capacity of approximately 570,000 MMBtus per day and LNG storage capacity of up to 170,000 cubic meters. We are developing a 33-kilometer, 20-inch pipeline that will connect the Santa Catarina Facility to the existing inland Transportadora Brasileira Gasoduto Bolivia-Brasil S.A. (“TBG”) pipeline via an interconnection point in the municipality of Garuva. The Santa Catarina Facility and associated pipeline are expected to have a total addressable market of 15 million cubic meters per day. We expect to complete our Santa Catarina Facility and commence operations in the first quarter of 2024.

Ireland Facility

We intend to develop and operate an LNG facility and power plant on the Shannon Estuary, near Tarbert, Ireland. In April 2023, we were awarded a capacity contract for the development of a power plant for approximately 353 MW of electricity generation with a duration of ten years as part of the auction process operated by Ireland’s Transmission System Operator. The power plant is required to be operational by October 2026. In the third quarter of 2023, An Bord Pleanála, Ireland's planning commission, denied our application for the development of an LNG terminal and power plant. We are challenging this decision. The continued development of this project is uncertain and there are multiple risks, including regulatory risks, that could preclude the development of this project, and the results of these risks could have a material effect on our results of operations.

Recent Developments

Barcarena Financings

In October 2023, certain the Company's Brazilian subsidiaries entered into two long-term financing arrangements fully funding the construction of the Company's power plant located in Pará, Brazil (the "Barcarena Power Plant"). Proceeds received will be used to repay the current Barcarena Term Loan and to pay for all remaining expected construction costs through the planned completion of the Barcarena Power Plant in 2025.

The owner of the Barcarena Power Plant entered into a credit agreement with BNDES, the Brazilian Development Bank (the "BNDES Credit Agreement"). The Company is able to borrow up to R$1.8 billion under the BNDES Credit Agreement, segregated into three tranches based on the use of proceeds ("BNDES Term Loan"). Each tranche bears a

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different rate of interest ranging from 2.61% to 4.41% plus the fixed rate announced by BNDES. No principal payments are required until April 2026 and are due quarterly thereafter until maturity in 2045.

The obligations under the BNDES Credit Agreement are guaranteed by certain indirect Brazilian subsidiaries that are constructing the Barcarena Power Plant, and are secured by the Barcarena Power Plant and receivables under the Barcarena Power Plant's PPAs. These Brazilian subsidiaries are required to comply with customary affirmative and negative covenants, and the BNDES Credit Agreement also provides for customary events of default, prepayment and cure provisions.

Additionally, the parent of the owner of the Barcarena Power Plant entered into an agreement for the issuance of up to $200 million of convertible debentures maturing in October 2028 ("Barcarena Debentures"). Interest on the Barcarena Debentures is due quarterly, and interest accrues at an annual rate of 12%, increasing 1.25% each year after the third anniversary of issuance. The Company is able to prepay the Barcarena Debentures, subject to customary break funding costs, and the Company is required to utilize certain excess cash flows from the Company's Brazilian operations to prepay principal.

The Barcarena Debentures are convertible to shares of one of the Company's indirect Brazilian subsidiaries on the maturity date at the creditors' option, based on the current fair value of this subsidiary's equity at the time of conversion.

The obligations under the Barcarena Debentures are guaranteed by certain indirect Brazilian subsidiaries that own Company's LNG regasification terminals located in Pará, Brazil ("Barcarena Terminal") and Santa Catarina, Brazil. NFE has also provided a parent company guarantee that will be released once the Barcarena Terminal commences commercial operations. Brazilian subsidiaries guaranteeing these obligations are required to comply with customary affirmative and negative covenants, and the Barcarena Debentures also provides for customary events of default, prepayment and cure provisions.

Term Loan B Credit Agreement

On October 30, 2023, the Company entered into a credit agreement (the “Term Loan B Agreement”) pursuant to which the lenders funded term loans to the Company in an aggregate principal amount of $856 million ("Term Loan B"). The proceeds from the Term Loan B issuance will be used to repay the Bridge Term Loans and may be used for working capital and other general corporate purposes. The Term Loan B will mature in October 2028 if the 2025 Notes and 2026 Notes (each as defined in the Annual Report) are refinanced prior to their maturities; if not, the Term Loan B becomes due approximately 60 days prior to the maturity of each the 2025 Notes and 2026 Notes. Quarterly principal payments of approximately $2.1 million begin to be due starting March 2024.

The Term Loan B is guaranteed on a senior secured basis by each domestic subsidiary that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility (each as defined in the Annual Report) and will be guaranteed on a senior secured basis by each foreign guarantor that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility on a post-closing basis. The Term Loan B is and will be secured by substantially the same collateral as the first lien obligations under the 2025 Notes, 2026 Notes, the Company's letter of credit facility and Revolving Facility. Additionally the Term Loan B is secured by assets comprising our first Fast LNG project in Altamira, Mexico.

The Term Loan B bears interest at a per annum rate equal to Adjusted Term SOFR (as defined in the Term Loan B Agreement) plus 5.0%. The Company may prepay the Term Loan B at its option subject to prepayment premiums until October 2025 and customary break funding costs. The Company is required to prepay the Term Loan B with the net proceeds of certain asset sales, condemnations, and debt and convertible securities issuances, in each case subject to certain exceptions and thresholds. Additionally, commencing with the fiscal quarter ending December 31, 2024, the Company will be required to prepay the Term Loan B with the Company’s Excess Cash Flow (as defined in the Term Loan B Agreement).

The Term Loan B Agreement contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. No financial covenant compliance is required under the Term Loan B Agreement.

Other Matters

On June 18, 2020, we received an order from the Federal Energy Regulatory Commission ("FERC"), which asked us to explain why our San Juan Facility is not subject to FERC’s jurisdiction under section 3 of the NGA. Because we do not

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believe that the San Juan Facility is jurisdictional, we provided our reply to FERC on July 20, 2020 and requested that FERC act expeditiously. On March 19, 2021, FERC issued an order that the San Juan Facility does fall under FERC jurisdiction. FERC directed us to file an application for authorization to operate the San Juan Facility within 180 days of the order, which was September 15, 2021, but also found that allowing operation of the San Juan Facility to continue during the pendency of an application is in the public interest. FERC also concluded that no enforcement action against us is warranted, presuming we comply with the requirements of the order. Parties to the proceeding, including the Company, sought rehearing of the March 19, 2021 FERC order, and FERC denied all requests for rehearing in an order issued on July 15, 2021; the FERC order was affirmed by the United States Court of Appeals for the District of Columbia Circuit on June 14, 2022. In order to comply with the FERC’s directive, on September 15, 2021, we filed an application for authorization to operate the San Juan Facility, which remains pending.

On July 18, 2023, we filed for an amendment to the March 19, 2021 and July 15, 2021 FERC orders allowing the continued operation of the San Juan Facility during the pendency of the formal application to allow us to construct and interconnect 220 feet of incremental 10-inch pipeline needed to supply natural gas for temporary power generation solicited through the Puerto Rico Power Stabilization Task Force. On July 31, 2023, FERC issued an order stating that it would not take action to prevent the construction and operation of the pipeline and interconnect.

Results of Operations – Three Months Ended September 30, 2023 compared to Three Months Ended June 30, 2023 and Nine Months Ended September 30, 2023 compared to Nine Months Ended September 30, 2022

Performance of our two segments, Terminals and Infrastructure and Ships, is evaluated based on Segment Operating Margin. Segment Operating Margin reconciles to Consolidated Segment Operating Margin as reflected below, which is a non-GAAP measure. We reconcile Consolidated Segment Operating Margin to GAAP Gross margin, inclusive of depreciation and amortization. Consolidated Segment Operating Margin is mathematically equivalent to Revenue minus Cost of sales (excluding depreciation and amortization reflected separately) minus Operations and maintenance minus Vessel operating expenses, each as reported in our financial statements. We believe this non-GAAP measure, as we have defined it, offers a useful supplemental measure of the overall performance of our operating assets in evaluating our profitability in a manner that is consistent with metrics used for management’s evaluation of the overall performance of our operating assets.

Consolidated Segment Operating Margin is not a measurement of financial performance under GAAP and should not be considered in isolation or as an alternative to Gross margin, income/(loss) from operations, net income/(loss), cash flow from operating activities or any other measure of performance or liquidity derived in accordance with GAAP. As Consolidated Segment Operating Margin measures our financial performance based on operational factors that management can impact in the short-term, items beyond the control of management in the short term, such as depreciation and amortization are excluded. As a result, this supplemental metric affords management the ability to make decisions and facilitates measuring and achieving optimal financial performance of our current operations. The principal limitation of this non-GAAP measure is that it excludes significant expenses and income that are required by GAAP. A reconciliation is provided for the non-GAAP financial measure to the most directly comparable GAAP measure, Gross margin. Investors are encouraged to review the related GAAP financial measures and the reconciliation of the non-GAAP financial measure to our Gross margin, and not to rely on any single financial measure to evaluate our business.

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The tables below present our segment information for the three months ended September 30, 2023 and June 30, 2023, and for the nine months ended September 30, 2023 and September 30, 2022:

			Three Months Ended September 30, 2023
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(3)						Consolidated
Total revenues			$	447,905					$	66,557					$	514,462					$	—					$	514,462
Cost of sales(1)(2)			192,343						—						192,343						(423)						191,920
Vessel operating expenses(4)			—						11,613						11,613						—						11,613
Operations and maintenance(4)			60,819						—						60,819						—						60,819
Segment Operating Margin			$	194,743					$	54,944					$	249,687					$	423					$	250,110

Three Months Ended September 30, 2023
(in thousands of $)																											Consolidated
Gross margin (GAAP)																											$	201,440
Depreciation and amortization																											48,670
Consolidated Segment Operating Margin (Non-GAAP)																											$	250,110

			Three Months Ended June 30, 2023
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(3)						Consolidated
Total revenues			$	495,504					$	65,841					$	561,345											$	561,345
Cost of sales(2)			222,371						—						222,371						3,397						225,768
Vessel operating expenses(4)			—						11,443						11,443												11,443
Operations and maintenance(4)			33,697						—						33,697						—						33,697
Segment Operating Margin			$	239,436					$	54,398					$	293,834					$	(3,397)					$	290,437

Three Months Ended June 30, 2023
(in thousands of $)																											Consolidated
Gross margin (GAAP)																											$	248,322
Depreciation and amortization																											42,115
Consolidated Segment Operating Margin (Non-GAAP)																											$	290,437

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			Nine Months Ended September 30, 2023
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(3)						Consolidated
Total revenues			$	1,446,017					$	230,315					$	1,676,332					$	(21,394)					$	1,654,938
Cost of sales(1)(2)			488,512						—						488,512						114,114						602,626
Vessel operating expenses(4)			—						42,295						42,295						(5,948)						36,347
Operations and maintenance(4)			121,187						—						121,187						—						121,187
Segment Operating Margin			$	836,318					$	188,020					$	1,024,338					$	(129,560)					$	894,778

Nine Months Ended September 30, 2023
(in thousands of $)																											Consolidated
Gross margin (GAAP)																											$	769,618
Depreciation and amortization																											125,160
Consolidated Segment Operating Margin (Non-GAAP)																											$	894,778

			Nine Months Ended September 30, 2022
(in thousands of $)			Terminals and Infrastructure						Ships						Total Segment						Consolidation and Other(3)						Consolidated
Total revenues			$	1,711,241					$	337,626					$	2,048,867					$	(226,964)					$	1,821,903
Cost of sales(2)			909,938						—						909,938						(35,409)						874,529
Vessel operating expenses(4)			11,178						71,029						82,207						(20,297)						61,910
Operations and maintenance(4)			89,861						—						89,861						(24,170)						65,691
Segment Operating Margin			$	700,264					$	266,597					$	966,861					$	(147,088)					$	819,773

Nine Months Ended September 30, 2022
(in thousands of $)																								Consolidated
Gross margin (GAAP)																								$	713,334
Depreciation and amortization																								106,439
Consolidated Segment Operating Margin (Non-GAAP)																								$	819,773

(1) Cost of sales in our segment measure only includes realized gains and losses on derivative transactions that are an economic hedge of commodity purchases and sales, and realized losses of $0.3 million and realized gains of $141.6 million for the three and nine months ended September 30, 2023, respectively, were recognized as a reduction to Cost of sales in the segment measure.

We recognized unrealized gains of $0.4 million and unrealized losses of $107.9 million on the mark-to-market value of derivative transactions for the three and nine months ended September 30, 2023, respectively, and these gains and losses reconcile Cost of sales in the segment measure to Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

We have excluded contract acquisition costs that do not meet the criteria for capitalization from the segment measure. Contract acquisition costs of $6.2 million for the three and nine months ended September 30, 2023 reconcile Cost of sales in the segment measure to Cost of sales in the condensed consolidated statements of operations and comprehensive income (loss).

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(2) Cost of sales is presented exclusive of costs included in Depreciation and amortization in the condensed consolidated statements of operations and comprehensive income (loss).

(3) Consolidation and Other adjusts for the inclusion of the effective share of revenues, expenses and operating margin attributable to our 50% ownership of Centrais Elétricas de Sergipe Participações S.A. (“CELSEPAR”) and the common units of Hilli LLC in the segment measure, prior to the disposition to these investments, the exclusion of the unrealized mark-to-market gain or loss on derivative instruments, and the exclusion of non-capitalizable contract acquisition costs.

(4) Operations and maintenance and Vessel operating expenses are directly attributable to revenue-producing activities of our terminals and vessels and are included in the calculation of Gross margin defined under GAAP.

Terminals and Infrastructure Segment

			Three Months Ended,
(in thousands of $)			September 30, 2023						June 30, 2023						Change
Total revenues			$	447,905					$	495,504					$	(47,599)
Cost of sales (exclusive of depreciation and amortization)			192,343						222,371						(30,028)
Operations and maintenance			60,819						33,697						27,122
Segment Operating Margin			$	194,743					$	239,436					$	(44,693)

			Nine Months Ended,
(in thousands of $)			September 30, 2023						September 30, 2022						Change
Total revenues			$	1,446,017					$	1,711,241					$	(265,224)
Cost of sales (exclusive of depreciation and amortization)			488,512						909,938						(421,426)
Vessel operating expenses			—						11,178						(11,178)
Operations and maintenance			121,187						89,861						31,326
Segment Operating Margin			$	836,318					$	700,264					$	136,054

Total revenue

Total revenue for the Terminals and Infrastructure Segment decreased by $47.6 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023. The decrease was primarily driven by decreases to revenue from LNG cargo sales to third parties, partially offset by additional gas sales in Puerto Rico and increases to the Henry Hub index. The index forms a portion of the pricing to invoice most of our customers in this segment.

The decrease in revenue in third quarter of 2023 when compared to the second quarter of 2023 was primarily attributable to the following:

•We had no revenue from LNG cargo sales for the three months ended September 30, 2023, decreasing from $267.8 million for the three months ended June 30, 2023, as we were able to utilize all LNG purchased under our long-term supply contracts in our terminal operations.

Such decrease was offset by increases to revenue in the three months ended September 30, 2023 when compared to the three months ended June 30, 2023, due to the following:

•Volumes delivered to downstream terminal customers increased from 14.0 TBtus in the second quarter of 2023 to 20.1 TBtu in the third quarter of 2023. We continue to support the grid stabilization project in Puerto Rico, and we recognized a full quarter of operations for our Palo Seco Power Plant during the third quarter. We also completed the commissioning of additional power assets at the San Juan Power Plant in September. Additionally, in August 2023, we placed our La Paz Power Plant into service, and we began to recognize revenue from power sales from this plant in the local spot market.

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•The average Henry Hub index pricing used to invoice our downstream customers increased by 22% for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023.

Total revenue for the Terminals and Infrastructure Segment decreased by $265.2 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The decrease was primarily driven by lower LNG cargo sales, no pro rata share of revenue from our former investment in CELSEPAR and a reduction in the Henry Hub index that forms a portion of the pricing to invoice most of our customers in this segment. The decrease in revenue was partially offset by increased revenue from sales to downstream terminal customers.

The decrease in revenue in the nine months ended September 30, 2023 when compared to the nine months ended September 30, 2022 was primarily attributable to the following:

•Our LNG cargo sales to third parties decreased by $327.7 million for the nine months ended September 30, 2023, decreasing from $944.8 million for the nine months ended September 30, 2022 to $617.1 million nine months ended September 30, 2023. In the third quarter of 2023, we were able to utilize all LNG purchased under our long-term supply contracts in our terminal operations.

•After the completion of the sale of our investment in CELSEPAR in the fourth quarter of 2022, we no longer recognize revenue from this investment in our segment measure. Our share of revenue from CELSEPAR was $148.3 million for the nine months ended September 30, 2022, which was primarily comprised of fixed capacity payments received under related PPAs.

•The average Henry Hub index pricing used to invoice our downstream customers decreased by 60% for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022

Such decrease was offset by increases to revenue in the nine months ended September 30, 2023 when compared to the nine months ended September 30, 2022, due to the following:

•Volumes delivered to downstream customers were 46.1 TBtu for the nine months ended September 30, 2023 as compared to 28.5 TBtu for the nine months ended September 30, 2022, and these increased volumes were primarily attributable to our operations in Jamaica, Puerto Rico and Mexico.

•In the prior year, maintenance activities significantly lowered consumption at our facilities; there has been no significant maintenance downtime during 2023. The maintenance downtime in the prior year was across our facilities, including downtime at our CHP Plant for unplanned maintenance, downtime at our Montego Bay Facility due to a reconfiguration of our assets required by the Port of Montego Bay and maintenance at PREPA's San Juan Power Plants. Volumes delivered across from these facilities increased by 12.8 TBtu as compared to the nine months ended September 30, 2022.

•In May 2023, we began to support the grid stabilization project in Puerto Rico, commissioning power generation assets at the Palo Seco Power Plant. In September 2023, we finished commissioning additional power generation assets at the San Juan Power Plant. We have consumed 4.7 TBtu at these power plants during the nine months ended September 30, 2023 as part of this project.

Cost of sales

Cost of sales includes the procurement of feedgas or LNG, as well as shipping and logistics costs to deliver LNG or natural gas to our facilities. Our LNG and natural gas supply are purchased from third parties or converted in our Miami Facility. Costs to convert natural gas to LNG, including labor, depreciation and other direct costs to operate our Miami Facility are also included in Cost of sales.

Cost of sales decreased by $30.0 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023, which was attributable to the following:

•We did not incur any cost of LNG purchased from third parties for LNG cargo sales, decreasing our cost by $76.9 million during the third quarter of 2023.

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•Vessel costs increased by $23.0 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023. Vessels were used for commissioning of our La Paz Power Plant and our enhanced supply chain for our Puerto Rican operations in the second quarter, and such vessel costs were capitalized. As these projects became operational in the third quarter we recognized higher expense associated with these vessels. Further, certain vessels were placed into service at our terminals during the third quarter resulting in higher vessel charter costs.

•Increase in cost of LNG purchased from third parties for sale to our downstream customers of $18.4 million related to higher terminal sales; volumes delivered to our downstream customers increased by approximately 43% in the current quarter. Our cost to deliver these volumes decreased to $6.76 per MMBtu for the three months ended September 30, 2023 from $8.08 per MMBtu for the three months ended June 30, 2023.

Cost of sales decreased by $421.4 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022, which was attributable to the following:

•We incurred decreased cost of LNG purchased from third parties for LNG cargo sales of $212.6 million during the nine months ended September 30, 2023, resulting from no LNG cargo sales in the third quarter as well as lower cost under our LNG supply contracts for cargos sold earlier in 2023.

•Realized gains of $141.6 million from the settlement of commodity swap transactions, entered into as an economic hedge to reduce the market risks associated with commodity prices, were included as reduction of cost of sales. For segment performance measures, unrealized mark to market gains and losses are excluded until settled.

•Vessel costs decreased by $37.6 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022 primarily due to the capitalization of vessel costs for the commissioning of development projects, as well as, vessel costs recognized as inventory when our vessels are used to transport inventory from a supplier's facility to our storage locations and terminals.

•Cost of sales for the nine months ended September 30, 2022 included $28.6 million of our share of cost of sales from our investment in CELSEPAR, which was primarily comprised of LNG costs to fuel a power plant owned by CELSEPAR.

•We incurred increased cost of LNG purchased from third parties for sale to our downstream customers of $15.3 million during the nine months ended September 30, 2023 due to increased volumes delivered; we delivered 62% more volumes to our downstream terminal customers in the current period as compared to the nine months ended September 30, 2022. While we delivered significantly more volumes to our downstream customers, our pricing to purchase LNG for delivery to such customers was substantially lower, decreasing to $7.26 per MMBtu for the nine months ended September 30, 2023 from $10.78 per MMBtu for the nine months ended September 30, 2022.

The weighted-average cost of our LNG inventory balance to be used in our downstream terminal operations as of September 30, 2023 and December 31, 2022 was $7.30 per MMBtu and $10.42 per MMBtu, respectively.

Vessel operating expenses

Vessel operating expenses include direct costs associated with operating a vessel, and these costs are typically included in the Ships segment. Once we begin to use a vessel in our terminal operations, the costs of the vessel begin to be included in the Terminals and Infrastructure segment. For the nine months ended September 30, 2022, we incurred $11.2 million of vessel operating expenses in this segment; we did not incur vessel operating costs in this segment during the nine months ended September 30, 2023.

Operations and maintenance

Operations and maintenance includes costs of operating our facilities, exclusive of costs to convert that are reflected in Cost of sales.

Operations and maintenance increased by $27.1 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023. Starting in the third quarter of 2023, our subsidiary, Genera, began to provide

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operations and maintenance services for PREPA's thermal generation assets, and we recognized payroll and other operating costs of $16.3 million. Under our contract with PREPA, we pass all of these costs onto PREPA, and such billings are recognized as revenue. In the third quarter, we also undertook activities to ensure that we have LNG supply available for our expanded Puerto Rican operations, including leasing berth space to place a storage vessel to service Puerto Rico, and we incurred additional lease cost associated with this berth space in the third quarter of 2023.

Operations and maintenance increased $31.3 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The increase was primarily attributable to reimbursable payroll and operating costs of Genera and increased lease costs associated with our Puerto Rican operations incurred in the third quarter of 2023. Additionally, we leased turbines to generate power at the Palo Seco Power Plant as part of the grid stabilization project in Puerto Rico, increasing operations and maintenance costs when compared to the prior year. These increases were partially offset by the exclusion of our share of Operations and maintenance from the investment in CELSEPAR; after the sale of our investment in CELSEPAR in the fourth quarter of 2022, we do not include these costs during nine months ended September 30, 2023.

Ships Segment

			Three Months Ended,
(in thousands of $)			September 30, 2023						June 30, 2023						Change
Total revenues			$	66,557					$	65,841					$	716
Vessel operating expenses			11,613						11,443						170
Segment Operating Margin			$	54,944					$	54,398					$	546

			Nine Months Ended,
(in thousands of $)			September 30, 2023						September 30, 2022						Change
Total revenues			$	230,315					$	337,626					$	(107,311)
Vessel operating expenses			42,295						71,029						(28,734)
Segment Operating Margin			$	188,020					$	266,597					$	(78,577)

Revenue in the Ships segment is comprised of operating lease revenue under time charters, fees for positioning and repositioning vessels as well as the reimbursement of certain vessel operating costs. Prior to the completion of the Energos Formation Transaction, we also recognized revenue related to the interest portion of lease payments and the operating and service agreements in connection with the sales-type lease of the Nanook. We included the interest income earned under sales-type leases as revenue as amounts earned under chartering and operating service agreements represented our ongoing ordinary business operations.

On March 15, 2023, we completed a transaction with Golar LNG Limited (“GLNG”) for the sale of our investment in the common units of Hilli LLC in exchange for approximately 4.1 million NFE shares and $100 million in cash (the "Hilli Exchange"). In the fourth quarter of 2022, we recognized a loss on the investment in the Hilli of $118.6 million; this loss was recognized in Loss from equity method investments in the consolidated statements of operations and comprehensive income (loss). Upon completion of the Hilli Exchange during the first quarter of 2023, we recognized an additional loss on disposal of $37.4 million, which was included in Other (income) expense, net. As a result of the Hilli Exchange we no longer have an ownership interest in the Hilli. NFE shares received from GLNG were cancelled upon the closing of the Hilli Exchange.

As of September 30, 2023, four FSRUs and two LNG carriers were leased to customers under long-term or spot arrangements. In July 2023, we sold the vessel Golar Spirit for a total consideration of $15.8 million resulting in a gain of $7.8 million. The gain on sale is included in Other (income) expense, net in the condensed consolidated statements of operations and comprehensive income (loss). The Mazo continues to be in cold lay-up, and no vessel charter revenue was generated from the vessel.

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Total revenue

Total revenue for the Ships segment increased $0.7 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023. During the third quarter, there were no reclassifications of vessels out of the Ships segment; there were also no significant changes the vessel charters.

Total revenue for the Ships segment decreased $107.3 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The decrease in revenue was primarily the result of the sale of the Nanook as part of the Energos Formation Transaction; we no longer recognize revenue related to the Nanook in 2023. One of our vessel charters was renewed at the beginning of 2023 at a lower rate; additionally the charters for two vessels concluded in the first quarter of 2023, lowering vessel revenue for the full nine months ended September 30, 2023. We plan to utilize these vessels in our operations following conversion and other upgrades starting later in 2023.

Vessel operating expenses

Vessel operating expenses include direct costs associated with operating a vessel, such as crewing, repairs and maintenance, insurance, stores, lube oils, communication expenses, management fees and costs to operate the Hilli prior to the Hilli Exchange discussed above. We also recognize voyage expenses within Vessel operating expenses, which principally consist of fuel consumed before or after the term of time charter or when the vessel is off hire. Under time charters, the majority of voyage expenses are paid by customers. To the extent that these costs are a fixed amount specified in the charter, which is not dependent upon redelivery location, the estimated voyage expenses are recognized over the term of the time charter.

Vessel operating expenses increased $0.2 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023.

Vessel operating expenses decreased $28.7 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The decrease in vessel operating expenses was primarily due to lower costs related to the Hilli after the Hilli Exchange at the end of the first quarter of 2023. Vessel operating expenses also decreased as a result of the sale of the Nanook as part of the Energos Formation Transaction; we recognized vessel operating expenses related to the Nanook during 2022 and no longer recognize vessel operating expenses related to the Nanook in 2023.

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Other operating results

			Three Months Ended,																								Nine Months Ended,
(in thousands of $)			September 30, 2023						June 30, 2023						Change												September 30, 2023						September 30, 2022						Change
Selling, general and administrative			$	49,107					$	55,803					$	(6,696)											$	157,048					$	165,952					$	(8,904)
Transaction and integration costs			2,739						1,554						1,185												4,787						12,387						(7,600)
Depreciation and amortization			48,670						42,115						6,555												125,160						106,439						18,721
Asset impairment expense			—						—						—												—						48,109						(48,109)
Total operating expenses			100,516						99,472						1,044												286,995						332,887						(45,892)
Operating income			149,594						190,965						(41,371)												607,783						486,886						120,897
Interest expense			64,822						64,396						426												200,891						156,344						44,547
Other (income) expense, net			(2,271)						(6,584)						4,313												16,150						(31,613)						47,763
Loss on extinguishment of debt, net			—						—						—												—						14,997						(14,997)
Income before income from equity method investments and income taxes			87,043						133,153						(46,110)												390,742						347,158						43,584
Income (loss) from equity method investments			489						2,269						(1,780)												12,738						(354,426)						367,164
Tax provision (benefit)			25,194						15,322						9,872												69,476						(126,249)						195,725
Net income			$	62,338					$	120,100					$	(57,762)											$	334,004					$	118,981					$	215,023

Selling, general and administrative

Selling, general and administrative includes compensation expenses for our corporate employees, employee travel costs, insurance, professional fees for our advisors, and screening costs for projects that are in initial stages and development is not yet probable.

Selling, general and administrative decreased $6.7 million for the three months ended September 30, 2023, compared to the three months ended June 30, 2023. We have decreased headcount supporting our administrative activities, and we recognized a decrease to our estimate of annual incentive compensation due to the headcount reduction in the third quarter of 2023.

Selling, general and administrative decreased $8.9 million for the nine months ended September 30, 2023 as compared to the nine months ended September 30, 2022. The decreases were primarily due to lower share-based compensation expense in 2023, offset by higher payroll costs incurred for the nine months ended September 30, 2023 prior to our headcount reduction.

Transaction and integration costs

For the three months ended September 30, 2023, we did not incur significant transaction and integration costs.

For the nine months ended September 30, 2023, we incurred $4.8 million for transaction and integration costs, as compared to $12.4 million for the nine months ended September 30, 2022. For the nine months ended September 30, 2022, we incurred transaction and integration costs primarily associated with the Sergipe Sale. There were no such significant transactions for the nine months ended September 30, 2023.

Depreciation and amortization

Depreciation and amortization increased $6.6 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023 and increased $18.7 million for the nine months ended September 30, 2023 as

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compared to the nine months ended September 30, 2022. In the second quarter of 2023, we began to place assets in service as part of the grid stabilization project in Puerto Rico, including turbines we own, as well a turbines we leased under a finance lease, at the Palo Seco Power Plant. These assets were placed into service in the May 2023, and we recognized a full quarter of depreciation in the third quarter of 2023.

Asset impairment expense

As a result of our acquisition of Hygo Energy Transition Limited in 2021, we recognized long-lived assets associated with the expansion of the Sergipe Power Plant. During the nine months ended September 30, 2022, we recognized asset impairment expense of $48.1 million, as the fair value of these assets was less than the carrying value, and the asset group was held for sale. There were no such transactions for the nine months ended September 30, 2023.

Interest expense

Interest expense increased by $0.4 million for the three months ended September 30, 2023 as compared to the three months ended June 30, 2023. Increased interest expense due to borrowings under our expanded Revolving Facility and the Bridge Term Loan, as well as the issuance of the Equipment Notes and the Short-term Borrowings (each as defined below), were mostly offset by increases in capitalized interest.

Interest expense increased by $44.5 million for the nine months ended September 30, 2023, as compared to the nine months ended September 30, 2022. The increase was primarily due to an increase in total principal outstanding due to additional principal balance outstanding, including obligations under the Energos Formation Transaction. The total principal balance on outstanding facilities was $6.2 billion as of September 30, 2023 as compared to total principal outstanding of $4.5 billion as of September 30, 2022.

Other (income) expense, net

Other (income) expense, net was $(2.3) million and $(6.6) million three months ended September 30, 2023, and June 30, 2023, respectively. Other expense (income), net was $16.2 million and $(31.6) million for the nine months ended September 30, 2023 and September 30, 2022, respectively.

Other income recognized in the three months ended September 30, 2023 was primarily comprised of a $7.8 million gain on the sale of the Golar Spirit and interest income. This income was partially offset by foreign currency remeasurement losses and realized losses on the sale of certain investments in equity securities.

Other expense recognized in the nine months ended September 30, 2023 was primarily comprised of a $37.4 million loss on disposal of Hilli equity method investment in the Hilli Exchange. This loss was partially offset by interest income and foreign currency remeasurement net gains.

Tax provision

We recognized a tax provision for the three months ended September 30, 2023 of $25.2 million compared to a tax provision of $15.3 million for the three months ended June 30, 2023. Our effective tax rate for the three months ended September 30, 2023 was 28.8% compared to 11.3% for the three months ended June 30, 2023. Our tax provision and effective tax rate primarily increased due to additional expected income tax expense related to certain of the Company's foreign subsidiaries.

We recognized a tax provision of $69.5 million for the nine months ended September 30, 2023 compared to a tax benefit of $126.2 million for the nine months ended September 30, 2022. The significant tax benefit recognized in 2022 was primarily driven by significant discrete items, including the remeasurement of a deferred tax liability in conjunction with an internal reorganization and the tax benefit associated with the other-than-temporary impairment on our investment in CELSEPAR. We have not recognized any significant discrete items through the third quarter of 2023.

Income (loss) from equity method investments

We recognized income from our equity method investments of $0.5 million and $2.3 million for the three months ended September 30, 2023 and June 30, 2023, respectively. We completed the Hilli Exchange in the first quarter of 2023, and as such, income from equity method investments in the second and third quarters of 2023 is wholly comprised of

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earnings from our investment in Energos. Our share of earnings from Energos decreased in the third quarter due to additional vessel operating expenses incurred by Energos.

We recognized income of $12.7 million from our equity method investments in the nine months ended September 30, 2023 compared to loss of $354.4 million for the nine months ended September 30, 2022. In connection with the announcement of the sale of our investment in CELSEPAR in 2022, we recognized an other than temporary impairment of the investment in CELSEPAR of $369.2 million; we did not have any such impairments impacting the earnings from our equity method investments in 2023.

Factors Impacting Comparability of Our Financial Results

Our historical results of operations and cash flows are not indicative of results of operations and cash flows to be expected in the future, principally for the following reasons:

•Our historical financial results do not reflect our Fast LNG solution that will lower the cost of our LNG supply. We currently purchase the majority of our supply of LNG from third parties, sourcing approximately 98% of our LNG volumes from third parties for the nine months ended September 30, 2023. We anticipate that the deployment of Fast LNG floating liquefaction facilities will significantly lower the cost of our LNG supply and reduce our dependence on third-party suppliers. We expect to deploy our first Fast LNG unit upon the completion of commissioning.

•Our historical financial results do not include significant projects that have recently been completed or are near completion. Our results of operations for the three and nine months ended September 30, 2023 include our Montego Bay Facility, Old Harbour Facility, San Juan Facility, certain industrial end-users and our Miami Facility. We have placed our La Paz Facility in service, and in the third quarter of 2023, we placed the La Paz Power Plant into service. We have executed agreements to extend and amend our supply of natural gas to multiple CFE power generation facilities in Baja California Sur, and as such, our revenue and results of operations have begun to be impacted by our operations in Mexico. We are also continuing to develop our Puerto Sandino Facility, Barcarena Facility, Santa Catarina Facility and Ireland Facility, and our current results do not include revenue and operating results from these projects.

Additionally, we began to deliver power to the Puerto Rican grid from the Palo Seco Power Plant as part of the grid stabilization project in the second quarter of 2023. At the end of September 2023, we placed additional power generation assets in service at the San Juan Power Plant. We expect that our power generation assets at both the Palo Seco Power Plant and at the San Juan Power Plant will operate at full capacity, and we expect that our revenue and results of operations will benefit from significant gas consumption required to operate these assets.

•Our historical financial results include the results from our investments in the common units of Hilli LLC and CELSEPAR. On March 15, 2023, we completed the Hilli Exchange, and in the fourth quarter of 2022, we sold our interest in CELSEPAR, the indirect owner of the Sergipe Power Plant in Brazil. As a result of these transactions, we no longer have any ownership interest in either the Hilli or the Sergipe Power Plant, and their results will no longer be included in NFE's results of operations.

Liquidity and Capital Resources

We believe we will have sufficient liquidity from proceeds from recent borrowings, access to additional capital sources and cash flow from operations to fund our capital expenditures and working capital needs for the next 12 months and the reasonably foreseeable future. Our significant capital projects, primarily our first FLNG unit, are nearing completion, and as with many capital projects, a significant portion of the overall capital spending becomes due near the completion of the project. We have also incurred significant capital costs to deploy 350MW of temporary power as part of the grid stabilization project in Puerto Rico.

We expect the current working capital position to improve based on: (1) following September 30, 2023, we have borrowed under our new Term Loan B Agreement, totaling $856 million; (2) we have fully funded the construction of our Barcarena Power Plant with new long-term financing in Brazil; (3) our credit agreements allow for proceeds from the sale of assets to be reinvested in our business, and we have significant non-core assets that could be used to fund our developments; (4) expected cash flows generated from the temporary power project and from sales of our own LNG

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generated by our first deployed Fast LNG unit; and (5) our relationships with certain significant vendors constructing our Fast LNG assets have allowed us to extend our payment terms to better align with the expected completion of Fast LNG.

We expect to fund our current operations and continued development of additional facilities through cash on hand, borrowings under our debt facilities, cash generated from certain sales and financing transactions and cash generated from operations. We may also opportunistically elect to generate additional liquidity through future debt or equity issuances and asset sales to fund our developments and transactions.

We have assumed total committed expenditures for all completed and existing projects to be approximately $6,162 million, with approximately $4,815 million having already been paid through September 30, 2023. This estimate represents the committed expenditures for our Fast LNG project, as well as committed expenditures necessary to complete the La Paz Facility, Puerto Sandino Facility, Barcarena Facility, Barcarena Power Plant, Santa Catarina Facility and committed capital expenditures to support our grid stabilization project in Puerto Rico. We expect fully completed Fast LNG units to cost between $1.0 billion and $1.6 billion per unit. Unlike engineering, procurement and construction agreements for traditional liquefaction construction, our contracts with vendors to construct the Fast LNG units allow us to closely control the timing of our spending and construction schedules so that we can complete each project in time frames to meet our business needs. For example, expected spending for our second and third Fast LNG units that is not currently contracted is excluded from the estimated committed spending. Each Fast LNG completion is subject to permitting, various contractual terms, project feasibility, our decision to proceed and timing. We carefully manage our contractual commitments, the related funding needs and our various sources of funding including cash on hand, cash flow from operations, and borrowings under existing and future debt facilities. We may also enter into other financing arrangements to generate proceeds to fund our developments.

As of September 30, 2023, we have spent approximately $128.6 million to develop the Pennsylvania Facility. Approximately $22.5 million of construction and development costs have been expensed as we have not issued a final notice to proceed to our engineering, procurement and construction contractors. Cost for land, as well as engineering and equipment that could be deployed to other facilities and associated financing costs of approximately $106.1 million, has been capitalized, and to date, we have repurposed approximately $16.8 million of engineering and equipment to our Fast LNG project. We intend to apply for updated permits for the Pennsylvania Facility with the aim of obtaining these permits to coincide with the commencement of construction activities.

On December 12, 2022, our Board of Directors approved an update to our dividend policy. In connection with the dividend policy update, the Board declared a dividend of $626.3 million, representing $3.00 per Class A share, which was paid during the first quarter of 2023. Additionally, we declared and paid quarterly dividends totaling $61.5 million during the nine months ended September 30, 2023, representing $0.10 per Class A share. Our future dividend policy is within the discretion of our Board of Directors and will depend upon then-existing conditions, including our results of operations and financial condition, capital requirements, business prospects, statutory and contractual restrictions on our ability to pay dividends, including restrictions contained in our debt agreements, and other factors our Board of Directors may deem relevant. In the third quarter of 2023, our Board of Directors reinstated a dividend policy of targeting a quarterly dividend of $0.10 per share.

Contractual Obligations

We are committed to make cash payments in the future pursuant to certain contracts. The following table summarizes certain contractual obligations in place as of September 30, 2023.

(in thousands of $)			Total						Less than Year 1						Years 2 to 3						Year 4 to 5						More than 5 years
Long-term debt obligations			$	8,525,237					$	225,540					$	3,550,767					$	2,177,844					$	2,571,086
Purchase obligations			14,968,923						645,109						2,237,465						1,412,110						10,674,239
Lease obligations			600,005						47,555						255,500						108,502						188,448
Total			$	24,094,165					$	918,204					$	6,043,732					$	3,698,456					$	13,433,773

Long-term debt obligations

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For information on our long-term debt obligations, see “—Liquidity and Capital Resources—Long-Term Debt” in our Annual Report. The amounts included in the table above are based on the total debt balance, scheduled maturities, and interest rates in effect as of September 30, 2023.

A portion of our long-term debt obligations will be paid to Energos under charters of vessels included in the Energos Formation Transaction to third parties. The residual value of these vessels also forms a part of the obligation and will be recognized as a bullet payment at the end of the charters. As neither these third party charter payments nor the residual value of these vessels represent cash payments due by NFE, such amounts have been excluded from the table above.

Subsequent to September 30, 2023, we entered into the BNDES Credit Agreement, Barcarena Debentures and Term Loan B Credit Agreement (each defined and described in Note 24. Subsequent events). Proceeds from these new credit arrangements have been or will be used to refinance the Bridge Term Loan and the Barcarena Term Loan on a long term basis, and as such, these principal balances have been shown as non-current on the condensed consolidated balance sheets as of September 30, 2023.

Purchase obligations

We are party to contractual purchase commitments for the purchase, production and transportation of LNG and natural gas, as well as engineering, procurement and construction agreements to develop our terminals and related infrastructure. Our commitments to purchase LNG and natural gas are principally take-or-pay contracts, which require the purchase of minimum quantities of LNG and natural gas, and these commitments are designed to assure sources of supply and are not expected to be in excess of normal requirements. Certain LNG purchase commitments are subject to conditions precedent, and we include these expected commitments in the table above beginning when delivery is expected assuming that all contractual conditions precedent are met. For purchase commitments priced based upon an index such as Henry Hub, the amounts shown in the table above are based on the spot price of that index as of September 30, 2023.

We have construction purchase commitments in connection with our development projects, including our Fast LNG project, La Paz Facility, Puerto Sandino Facility, Barcarena Facility, Santa Catarina Facility and committed capital expenditures to support our grid stabilization project in Puerto Rico. Commitments included in the table above include commitments under engineering, procurement and construction contracts where a notice to proceed has been issued.

Lease obligations

Future minimum lease payments under non-cancellable lease agreements, inclusive of fixed lease payments for renewal periods we are reasonably certain will be exercised, are included in the above table. Our lease obligations are primarily related to LNG vessel time charters, marine port leases, ISO tank leases, office space, gas turbines and a land lease.

Cash Flows

The following table summarizes the changes to our cash flows for the nine months ended September 30, 2023 and 2022, respectively:

			Nine Months Ended September 30,
(in thousands of $)			2023						2022						Change
Cash flows from:
Operating activities			$	537,184					$	91,105					$	446,079
Investing activities			(2,065,562)						(195,960)						(1,869,602)
Financing activities			924,072						249,710						674,362
Net (decrease) increase in cash, cash equivalents, and restricted cash			$	(604,306)					$	144,855					$	(749,161)

Cash provided by operating activities

Our cash flow provided by operating activities was $537.2 million for the nine months ended September 30, 2023, which increased by $446.1 million from cash provided by operating activities of $91.1 million for the nine months ended

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September 30, 2022. The increase in cash provided by operating activities for the nine months ended September 30, 2023 was primarily driven by changes in working capital, including improved collection of receivables and the settlement of a significant commodity derivative, as well as significant cash receipts under our temporary power agreements that are required to be deferred as contract liabilities.

Cash (used in) investing activities

Our cash flow used in investing activities was $2,065.6 million for the nine months ended September 30, 2023, which increased by $1,869.6 million from cash used in investing activities of $196.0 million for the nine months ended September 30, 2022. Cash outflows for investing activities during the nine months ended September 30, 2023 were used primarily for continued development of our Fast LNG project and assets to service the grid stabilization project in Puerto Rico. Cash outflows were offset by proceeds of $100.0 million from the sale of our equity method investment in Hilli LLC in the Hilli Exchange, as well as proceeds received from the sale of the Spirit and a portion of our investment in equity securities.

Cash outflows for investing activities during the nine months ended September 30, 2022 were used for continued development of our Fast LNG project, Santa Catarina Facility, and Barcarena Facility. Cash outflows were offset by proceeds of $593.0 million from the sale of the finance lease of the Nanook.

Cash provided by financing activities

Our cash flow provided by financing activities was $924.1 million for the nine months ended September 30, 2023, which increased by $674.4 million from cash provided by financing activities of $249.7 million for the nine months ended September 30, 2022. In December 2022, our Board of Directors approved and declared a dividend of $626.3 million, representing $3.00 per Class A share; such dividend payment was made in January 2023. We have borrowed under our expanded Revolving Facility, Bridge Term Loans, Equipment Notes, as well as short-term borrowings under repurchase arrangements for total additional borrowings of $1,768.7 million. Such borrowings were primarily used to fund the ongoing development of our Fast LNG project and to support our grid stabilization project in Puerto Rico. Increased borrowings during 2023 were offset by repayments of debt totaling $104.5 million, primarily the repayment of short-term borrowings under repurchase arrangements.

Cash provided by financing activities during the nine months ended September 30, 2022 was due to proceeds from issuance of debt of $1.9 billion, offset by repayments of debt of $1.5 billion, payment of dividends of $75.1 million and payments related to tax withholdings for shared-based compensation of $72.6 million.

Long-Term Debt and Preferred Stock

The terms of our debt instruments and associated obligations have been described in our Annual Report. There have been no significant changes to the terms of our outstanding debt, covenant requirements or payment obligations, other than described below.

Bridge Term Loan Credit Agreement

On August 3, 2023, we entered into a Bridge Term Loan Credit Agreement (the “Bridge Term Loan Agreement”) pursuant to which the lenders funded term loans (the “Bridge Term Loans”) to the Company in an aggregate principal amount of $400 million. Bridge Term Loan proceeds may be used for working capital and other general corporate purposes. The Bridge Term Loans will mature on August 1, 2024 and are payable in full on the maturity date. The Bridge Term Loans were repaid in full without penalty using proceeds from the Term Loan B which closed after September 30, 2023.

The Bridge Term Loans were guaranteed on a senior secured basis by each domestic and foreign subsidiary that is a guarantor under the 2025 Notes, 2026 Notes and Revolving Facility (each as defined in the Annual Report). The Bridge Term Loans were secured by substantially the same collateral as the first lien obligations under the 2025 Notes, 2026 Notes and Revolving Facility. The Bridge Term Loan Agreement contained usual and customary representations and warranties, and usual and customary affirmative and negative covenants, including requirements to maintain certain levels of total debt to capitalization and total first lien debt to EBITDA, and the ratios required to be maintained were consistent with the requirements under the Revolving Facility.

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Equipment Notes

In June 2023, we executed a Master Loan and Security Agreement with a lender to borrow up to $200.0 million under promissory notes secured by certain turbines acquired in the first quarter of 2023 to support the grid stabilization project in Puerto Rico (the “Equipment Notes”). During the second and third quarters of 2023, we borrowed the full capacity bearing interest at approximately 7.7%, and the principal is partially repayable in monthly installments over the 36 month term of the loan with the balance due upon maturity in July 2026.

The Equipment Notes contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. The Equipment Notes do not contain any restrictive financial covenants.

EB-5 Loan Agreement

On July 21, 2023, we entered into a loan agreement under the U.S. Citizenship and Immigration Services EB-5 Program (“EB-5 Loan Agreement”) to pay for the development and construction of a new green hydrogen facility in Texas. The maximum aggregate principal amount available under the EB-5 Loan Agreement is $100.0 million, and outstanding borrowings bear interest at a fixed rate of 4.75%. The loan matures in 5 years from the initial advance with an option to extend the maturity by two one-year periods. It is expected that the loan will be secured by NFE's green hydrogen facility, and NFE has provided a guarantee of the obligations under the EB-5 Loan Agreement. In the third quarter of 2023, $37.9 million was funded under the EB-5 Loan Agreement.

The EB-5 Loan Agreement contains usual and customary representations and warranties, and usual and customary affirmative and negative covenants. The EB-5 Loan Agreement does not contain any restrictive financial covenants.

Short-term Borrowings

We may, from time to time, enter into sales and repurchase agreements with a financial institution, whereby we sell to the financial institution an LNG cargo and we concurrently enters into an agreement to repurchase the same LNG cargo immediately with the repurchase price payable at a future date, generally not to exceed 90-days from the date of the sale and repurchase (the “Short-term Borrowings”). As of September 30, 2023, we had $161.8 million due under repurchase arrangements with a weighted average interest rate of 9.74%.

Revolving Facility

In the first three quarters of 2023, we entered into amendments of our Revolving Facility which increased the commitments by $426.6 million, for a total capacity of $866.6 million. The interest rate for borrowings under the Revolving Facility based on the current usage of the facility has not changed, and no changes were made to the maturity date or covenants. In conjunction with these amendments, we incurred an additional $7.0 million in fees which have been capitalized within Other non-current assets.

Debt and lease restrictions

We are required to comply with covenants under the Revolving Facility and letter of credit facility, including requirements to maintain Debt to Capitalization Ratio of less than 0.7:1.0, and for quarters in which the Revolving Facility is greater than 50% drawn, the Debt to Annualized EBITDA Ratio must be less than 5.0:1.0 for fiscal quarters ending December 31, 2021 until September 30, 2023 and less than 4.0:1.0 for the fiscal quarter ended December 31, 2023. We were in compliance with all covenants as of September 30, 2023.

Critical Accounting Policies and Estimates

A complete discussion of our critical accounting policies and estimates is included in our Annual Report. As of September 30, 2023, there have been no significant changes to our critical accounting estimates since our Annual Report.

Recent Accounting Standards

For descriptions of recently issued accounting standards, see “Note 3. Adoption of new and revised standards” to our notes to condensed consolidated financial statements included elsewhere in this Quarterly Report.

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Item 3.    Quantitative and Qualitative Disclosures About Market Risk.

In the normal course of business, the Company encounters several significant types of market risks including commodity and interest rate risks.

Commodity Price Risk

Commodity price risk is the risk of loss arising from adverse changes in market rates and prices. Our exposure to market risk associated with LNG price changes may adversely impact our business. We are able to limit our exposure to fluctuations in natural gas prices as our pricing in contracts with downstream customers is largely based on the Henry Hub index price plus a contractual spread. In 2022, we entered into a commodity swap transaction as an economic hedge to reduce the risks associated with commodity prices which settled in the first quarter of 2023 resulting in a realized gain of $146.1 million. In January 2023, we entered into a series of commodity swap transactions, and we have recognized an unrealized loss of $1.8 million for the nine months ended September 30, 2023. We currently do not have other derivative instruments to mitigate the effect of fluctuations in LNG prices on our operations; in the future we may enter into additional derivative instruments.

Interest Rate Risk

The 2025 Notes, 2026 Notes, Equipment Notes, and South Power 2029 Bonds (each defined above or in our Annual Report) were issued with a fixed rate of interest, and as such, a change in interest rates would impact the fair value of the debt outstanding but such a change would have no impact on our results of operations or cash flows. A 100-basis point increase or decrease in the market interest rate would decrease or increase the fair value of our fixed rate debt by approximately $69 million. The sensitivity analysis presented is based on certain simplifying assumptions, including instantaneous change in interest rate and parallel shifts in the yield curve.

Interest under the Barcarena Term Loan has a component based on the Secured Overnight Financing Rate ("SOFR"). A 100-basis point increase or decrease in the market interest rate would decrease or increase our annual interest expense by approximately $2 million.

Foreign Currency Exchange Risk

We have transactions, assets and liabilities denominated in Brazilian reais, and our Brazilian subsidiaries and investments receive income and pay expenses in Brazilian reais. Based on our Brazilian reais revenues and expenses, a 10% depreciation of the U.S. dollar against the Brazilian reais would not significantly decrease our revenue or expenses. As our operations expand in Brazil, our results of operations will be exposed to changes in fluctuations in the Brazilian real, which may materially impact our results of operations.

Outside of Brazil, our operations are primarily conducted in U.S. dollars, and as such, our results of operations and cash flows have not materially been impacted by fluctuations due to changes in foreign currency exchange rates. We currently incur a limited amount of costs in foreign jurisdictions other than Brazil that are paid in local currencies. As we expect our international operations to continue to grow in the near term, we may enter into derivative or hedging transactions with third parties to manage our exposure to changes in foreign currency exchange risks as we expand our international operations.

Item 4.    Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

In accordance with Rules 13a-15(b) of the Securities Exchange Act of 1934, as amended ("Exchange Act"), we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of September 30, 2023. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based

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upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of September 30, 2023 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There has been no change in our internal control over financial reporting (as defined in Rule 13a-15(f) and Rule 15d-15(f) under the Exchange Act) that occurred during the quarter ended September 30, 2023 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting

In the fourth quarter of 2023, we completed an implementation of our core financial systems, including our general ledger and other applications. As part of this implementation, we are making certain changes to our processes and procedures, which in turn, could result in changes to our internal control over financial reporting.

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PART II

OTHER INFORMATION

Item 1.     Legal Proceedings.

We are not currently a party to any material legal proceedings. In the ordinary course of business, various legal and regulatory claims and proceedings may be pending or threatened against us. If we become a party to proceedings in the future, we may be unable to predict with certainty the ultimate outcome of such claims and proceedings.

Item 1A.     Risk Factors.

An investment in our Class A common stock involves a high degree of risk. You should carefully consider the risks described below. If any of the following risks were to occur, the value of our Class A common stock could be materially adversely affected or our business, financial condition and results of operations could be materially adversely affected and thus indirectly cause the value of our Class A common stock to decline. Additional risks not presently known to us or that we currently deem immaterial could also materially affect our business and the value of our Class A common stock. As a result of any of these risks, known or unknown, you may lose all or part of your investment in our Class A common stock. The risks discussed below also include forward-looking statements, and actual results may differ substantially from those discussed in these forward-looking statements. See “Cautionary Statement on Forward-Looking Statements.”

Summary Risk Factors

Some of the factors that could materially and adversely affect our business, financial condition, results of operations or prospects include the following:

Risks Related to Our Business

•We have a limited operating history, which may not be sufficient to evaluate our business and prospects;

•Our ability to implement our business strategy may be materially and adversely affected by many known and unknown factors;

•     We are subject to various construction risks;

•     Operation of our infrastructure, facilities and vessels involves significant risks;

•     We depend on third-party contractors, operators and suppliers;

•     Failure of LNG to be a competitive source of energy in the markets in which we operate, and seek to operate, could adversely affect our expansion strategy;

•     We operate in a highly regulated environment and our operations could be adversely affected by actions by governmental entities or changes to regulations and legislation;

•     Failure to obtain and maintain permits, approvals and authorizations from governmental and regulatory agencies and third parties on favorable terms could impede operations and construction;

•     When we invest significant capital to develop a project, we are subject to the risk that the project is not successfully developed and that our customers do not fulfill their payment obligations to us following our capital investment in a project;

•     Failure to maintain sufficient working capital could limit our growth and harm our business, financial condition and results of operations;

•     Our ability to generate revenues is substantially dependent on our current and future long-term agreements and the performance by customers under such agreements;

•     Our current lack of asset and geographic diversification could have an adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects;

•     Because we are currently dependent upon a limited number of customers, the loss of a significant customer could adversely affect our operating results;

•     We may not be able to convert our anticipated customer pipeline into binding long-term contracts, and if we fail to convert potential sales into actual sales, we will not generate the revenues and profits we anticipate;

•     Our contracts with our customers are subject to termination under certain circumstances;

•     Competition in the LNG industry is intense, and some of our competitors have greater financial, technological and other resources than we currently possess;

•     Cyclical or other changes in the demand for and price of LNG and natural gas may adversely affect our business and the performance of our customers;

•     Our risk management strategies cannot eliminate all LNG price and supply risks. In addition, any non-compliance with our risk management strategies could result in significant financial losses;

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•     We are dependent on third-party LNG suppliers and the development of our own portfolio is subject to various risks and assumptions;

•     We seek to develop innovative and new technologies as part of our strategy that are not yet proven and may not realize the time and cost savings we expect to achieve;

•     Our Fast LNG technology is not yet proven and we may not be able to implement it as planned or at all;

•     We have incurred, and may in the future incur, a significant amount of debt;

•     Our business is dependent upon obtaining substantial additional funding from various sources, which may not be available or may only be available on unfavorable terms;

•     Weather events or other natural or manmade disasters or phenomena, some of which may be adversely impacted by global climate change, could have a material adverse effect on our operations and projects, as well as on the economies in the markets in which we operate or plan to operate;

•    We may experience increased labor costs and regulation, and the unavailability of skilled workers or our failure to attract and retain qualified personnel, as well as our ability to comply with such labor laws, could adversely affect us;

Risks Related to the Jurisdictions in Which We Operate

•     We are subject to the economic, political, social and other conditions in the jurisdictions in which we operate;

•     Our financial condition and operating results may be adversely affected by foreign exchange fluctuations;    

Risks Related to Ownership of Our Class A Common Stock

•A small number of our original investors have the ability to direct the voting of a majority of our stock, and their interests may conflict with those of our other stockholders;

•The declaration and payment of dividends to holders of our Class A common stock is at the discretion of our board of directors and there can be no assurance that we will continue to pay dividends in amounts or on a basis consistent with prior distributions to our investors, if at all;

General Risks

•We are a holding company and our operational and consolidated financial results are dependent on the results of our subsidiaries, affiliates, joint ventures and special purpose entities in which we invest;

•We may engage in mergers, sales and acquisitions, reorganizations or similar transactions related to our businesses or assets in the future and we may fail to successfully complete such transaction or to realize the expected value;

•We are unable to predict the extent to which the global COVID-19 pandemic will negatively affect our operations, financial performance, nor our ability to achieve our strategic objectives. We are also unable to predict how this global pandemic may affect our customers and suppliers; and

•A change in tax laws in any country in which we operate could adversely affect us.

Risks Related to Our Business

We have a limited operating history, which may not be sufficient to evaluate our business and prospects.

We have a limited operating history and track record. As a result, our prior operating history and historical financial statements may not be a reliable basis for evaluating our business prospects or the value of our Class A common stock. We commenced operations on February 25, 2014, and we had net losses of approximately $78.2 million in 2018, $204.3 million in 2019, and $264.0 million in 2020. We recognized income of $92.7 million in 2021, $184.8 million in 2022 and $62.3 million in the third quarter of 2023. Our limited operating history also means that we continue to develop and implement our strategies, policies and procedures, including those related to project development planning, operational supply chain planning, data privacy and other matters. We cannot give you any assurance that our strategy will be successful or that we will be able to implement our strategy on a timely basis, if at all, or achieve our internal model or that our assumptions will be accurate.

Our ability to implement our business strategy may be materially and adversely affected by many known and unknown factors.

Our business strategy relies on a variety of factors, including our ability to successfully market LNG, natural gas, steam, and power to end-users, develop and maintain cost-effective logistics in our supply chain and construct, develop and

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operate energy-related infrastructure in the countries where we operate, and expand our projects and operations to other countries where we do not currently operate, among others. These assumptions are subject to significant economic, competitive, regulatory and operational uncertainties, contingencies and risks, many of which are beyond our control, including, among others:

•     inability to achieve our target costs for the purchase, liquefaction and export of natural gas and/or LNG and our target pricing for long-term contracts;

•     failure to develop strategic relationships;

•     failure to obtain required governmental and regulatory approvals for the construction and operation of these projects and other relevant approvals;

•     unfavorable laws and regulations, changes in laws or unfavorable interpretation or application of laws and regulations; and

•     uncertainty regarding the timing, pace and extent of an economic recovery in the United States, the other jurisdictions in which we operate and elsewhere, which in turn will likely affect demand for crude oil and natural gas.

Furthermore, as part of our business strategy, we target customers who have not been traditional purchasers of natural gas, including customers in developing countries, and these customers may have greater credit risk than typical natural gas purchasers. Therefore, we may be exposed to greater customer credit risk than other companies in the industry. Our credit procedures and policies may be inadequate to sufficiently eliminate risks of nonpayment and nonperformance.

Our strategy may evolve over time. Our future ability to execute our business strategy is uncertain, and it can be expected that one or more of our assumptions will prove to be incorrect and that we will face unanticipated events and circumstances that may adversely affect our ability to execute our business strategy and adversely affect our business, financial condition and results of operations.

We are subject to various construction risks.

We are involved in the development of complex small, medium and large-scale engineering and construction projects, including our facilities, liquefaction facilities, power plants, and related infrastructure, which are often developed in multiple stages involving commercial and governmental negotiations, site planning, due diligence, permit requests, environmental impact studies, permit applications and review, marine logistics planning and transportation and end-user delivery logistics. In addition to our facilities, these infrastructure projects can include the development and construction of facilities as part of our customer contracts. Projects of this type are subject to a number of risks including, among others:

•engineering, environmental or geological problems;

•shortages or delays in the delivery of equipment and supplies;

•government or regulatory approvals, permits or other authorizations;

•failure to meet technical specifications or adjustments being required based on testing or commissioning;

•construction accidents that could result in personal injury or loss of life;

•lack of adequate and qualified personnel to execute the project;

•weather interference; and

•potential labor shortages, work stoppages or labor union disputes.

Furthermore, because of the nature of our infrastructure, we are dependent on interconnection with transmission systems and other infrastructure projects of third parties, including our customers, and/or governmental entities. Such third-party projects can be greenfield or brownfield projects, including modifications to existing infrastructure or increases in capacity to existing facilities, among others, and are subject to various construction risks and additional operational monitoring and balancing requirements that may impact the design of facilities to be constructed. Delays from such third parties or governmental entities could prevent connection to our projects and generate delays in our ability to develop our own projects. In addition, a primary focus of our business is the development of projects in foreign jurisdictions, including in locations where we have no prior development experience, and we expect to continue expanding into new jurisdictions in the future. These risks can be increased in jurisdictions where legal processes, language differences, cultural expectations, currency exchange requirements, political relations with the U.S. government, changes in the political views and structure, government representatives, new regulations, regulatory reviews, employment laws and diligence requirements can make it more difficult, time-consuming and expensive to develop a project. See “–Risks Related to the Jurisdictions in Which We Operate—We are subject to the economic, political, social and other conditions in the jurisdictions in which we operate.”

The occurrence of any one of these factors, whatever the cause, could result in unforeseen delays or cost overruns to our projects. Delays in the development beyond our estimated timelines, or amendments or change orders to our

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construction contracts, could result in increases to our development costs beyond our original estimates, which could require us to obtain additional financing or funding and could make the project less profitable than originally estimated or possibly not profitable at all. Further, any such delays could cause a delay in our anticipated receipt of revenues, a loss of one or more customers in the event of significant delays, and our inability to meet milestones or conditions precedents in our customer contracts, which could lead to delay penalties and potentially a termination of agreements with our customers. We have experienced time delays and cost overruns in the construction and development of our projects as a result of the occurrence of various of the above factors, and no assurance can be given that we will not continue to experience in the future similar events, any of which could have a material adverse effect on our business, operating results, cash flows and liquidity.

Operation of our infrastructure, facilities and vessels involves significant risks.

Our existing infrastructure, facilities and vessels and expected future operations and businesses face operational risks, including, but not limited to, the following:

•performing below expected levels of efficiency or capacity or required changes to specifications for continued operations;

•breakdowns or failures of equipment or shortages or delays in the delivery of supplies;

•operational errors by trucks, including trucking accidents while transporting natural gas, LNG or any other chemical or hazardous substance;

•risks related to operators and service providers of tankers or tugs used in our operations;

•operational errors by us or any contracted facility, port or other operator of related third-party infrastructure;

•failure to maintain the required government or regulatory approvals, permits or other authorizations;

•accidents, fires, explosions or other events or catastrophes;

•lack of adequate and qualified personnel;

•potential labor shortages, work stoppages or labor union disputes;

•weather-related or natural disaster interruptions of operations;

•pollution, release of or exposure to toxic substances or environmental contamination affecting operations;

•inability, or failure, of any counterparty to any facility-related agreements to perform their contractual obligations;

•decreased demand by our customers, including as a result of the COVID-19 pandemic; and

•planned and unplanned power outages or failures to supply due to scheduled or unscheduled maintenance.

In particular, we are subject to risks related to the operation of power plants, liquefaction facilities, marine and other LNG operations with respect to our facilities, floating storage regasification units ("FSRU") and LNG carriers, which operations are complex and technically challenging and subject to mechanical risks and problems. In particular, marine LNG operations are subject to a variety of risks, including, among others, marine disasters, piracy, bad weather, mechanical failures, environmental accidents, epidemics, grounding, fire, explosions and collisions, human error, and war and terrorism. An accident involving our cargos or any of our chartered vessels could result in death or injury to persons, loss of property or environmental damage; delays in the delivery of cargo; loss of revenues; termination of charter contracts; governmental fines, penalties or restrictions on conducting business; higher insurance rates; and damage to our reputation and customer relationships generally. Any of these circumstances or events could increase our costs or lower our revenues. If our chartered vessels suffer damage as a result of such an incident, they may need to be repaired. Repairs and maintenance costs for existing vessels are difficult to predict and may be substantially higher than for vessels we have operated since they were built and result in higher than anticipated operating expenses or require additional capital expenditures. The loss of earnings while these vessels are being repaired would decrease our results of operations. If a vessel we charter were involved in an accident with the potential risk of environmental impacts or contamination, the resulting media coverage could have a material adverse effect on our reputation, our business, our results of operations and cash flows and weaken our financial condition. Our offshore operating expenses depend on a variety of factors including crew costs, provisions, deck and engine stores and spares, lubricating oil, insurance, maintenance and repairs and shipyard costs, many of which are beyond its control, such as the overall economic impacts caused by the global COVID-19 outbreak. Other factors, such as increased cost of qualified and experienced seafaring crew and changes in regulatory requirements, could also increase operating expenditures. Future increases to operational costs are likely to occur. If costs rise, they could materially and adversely affect our results of operations. In addition, operational problems may lead to loss of revenue or higher than anticipated operating expenses or require additional capital expenditures. Any of these results could harm our business, financial condition and results of operations.

We cannot assure you that future occurrences of any of the events listed above or any other events of a similar or dissimilar nature would not significantly decrease or eliminate the revenues from, or significantly increase the costs of operating, our facilities or assets.

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We depend on third-party contractors, operators and suppliers.

We rely on third-party contractors, equipment manufacturers, suppliers and operators for the development, construction and operation of our projects and assets. We have not yet entered into binding contracts for the construction, development and operation of all of our facilities and assets, and we cannot assure you that we will be able to enter into the contracts required on commercially favorable terms, if at all, which could expose us to fluctuations in pricing and potential changes to our planned schedule. If we are unable to enter into favorable contracts, we may not be able to construct and operate these assets as expected, or at all. Furthermore, these agreements are the result of arms-length negotiations and subject to change. There can be no assurance that contractors and suppliers will perform their obligations successfully under their agreements with us. If any contractor is unable or unwilling to perform according to the negotiated terms and timetable of its respective agreement for any reason or terminates its agreement for any reason, we would be required to engage a substitute contractor, which could be particularly difficult in certain of the markets in which we plan to operate. For example, each of our vessels is operated and maintained by GLNG or its affiliates pursuant to ship management agreements. Any failure by GLNG or its affiliates in the operation of our vessels could have an adverse effect on our maritime operations and could result in our failure to deliver LNG to our customers as required under our customer agreements. Although some agreements may provide for liquidated damages if the contractor or supplier fails to perform in the manner required with respect to its obligations, the events that trigger such liquidated damages may delay or impair the completion or operation of the facility, and any liquidated damages that we receive may be delayed or insufficient to cover the damages that we suffer as a result of any such delay or impairment, including, among others, any covenants or obligations by us to pay liquidated damages or penalties under our agreements with our customers, development services, the supply of natural gas, LNG or steam and the supply of power, as well as increased expenses or reduced revenue. Such liquidated damages may also be subject to caps on liability, and we may not have full protection to seek payment from our contractors to compensate us for such payments and other consequences. We may hire contractors to perform work in jurisdictions where they do not have previous experience, or contractors we have not previously hired to perform work in jurisdictions we are beginning to develop, which may lead to such contractors being unable to perform according to its respective agreement. Furthermore, we may have disagreements with our contractors about different elements of the construction process, which could lead to the assertion of rights and remedies under their contracts and increase the cost of the applicable facility or result in a contractor’s unwillingness to perform further work. If we are unable to construct and commission our facilities and assets as expected, or, when and if constructed, they do not accomplish our goals or performance expectations, or if we experience delays or cost overruns in design, construction, commissioning or operation, our business, operating results, cash flows and liquidity could be materially and adversely affected.

Failure of LNG to be a competitive source of energy in the markets in which we operate, and seek to operate, could adversely affect our expansion strategy.

Our operations are, and will be, dependent upon LNG being a competitive source of energy in the markets in which we operate. In the United States, due mainly to a historic abundant supply of natural gas and discoveries of substantial quantities of unconventional or shale natural gas, imported LNG has not developed into a significant energy source. The success of the domestic liquefaction component of our business plan is dependent, in part, on the extent to which natural gas can, for significant periods and in significant volumes, be produced in the United States at a lower cost than the cost to produce some domestic supplies of other alternative energy sources, and that it can be transported at reasonable rates through appropriately scaled infrastructure. Since August 2021, LNG prices have increased materially, and global events, such as the COVID-19 pandemic, Russia’s invasion of Ukraine and global inflationary pressures, have generated further energy pricing volatility, which can have an adverse effect on market pricing of LNG and global demand for our products, as well as our ability to remain competitive in the markets in which we operate. Potential expansion in the Caribbean, Latin America and other parts of the world where we may operate is primarily dependent upon LNG being a competitive source of energy in those geographical locations. For example, in the Caribbean, due mainly to a lack of regasification infrastructure and an underdeveloped international market for natural gas, natural gas has not yet developed into a significant energy source. In Brazil, hydroelectric power generation is the predominant source of electricity and LNG is one of several other energy sources used to supplement hydroelectric generation. The success of our operations is dependent, in part, on the extent to which LNG can, for significant periods and in significant volumes, be produced internationally and delivered to our customers at a lower cost than the cost to deliver other alternative energy sources.

Political instability in foreign countries that export LNG, or strained relations between such countries and countries in the Caribbean and Latin America, may also impede the willingness or ability of LNG suppliers and merchants in such countries to export LNG to the Caribbean, Latin America and other countries where we operate or seek to operate. Furthermore, some foreign suppliers of LNG may have economic or other reasons to direct their LNG to other markets or from or to our competitors’ LNG facilities. Natural gas also competes with other sources of energy, including coal, oil, nuclear, hydrogen, hydroelectric, wind and solar energy, which may become available at a lower cost in certain markets. As a result of these and other factors, natural gas may not be a competitive source of energy in the markets we intend to serve or elsewhere. The failure of natural gas to be a competitive supply alternative to oil and other alternative energy

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sources could adversely affect our ability to deliver LNG or natural gas to our customers on a commercial basis, which could have a material adverse effect on our business, ability to realize benefits from future projects, results of operations, financial condition, liquidity and prospects.

We operate in a highly regulated environment and our operations could be adversely affected by actions by governmental entities or changes to regulations and legislation

Our business is highly regulated and subject to numerous governmental laws, rules, regulations and requires permits, authorizations and various governmental and agency approvals, in the various jurisdictions in which we operate, that impose various restrictions and obligations that may have material effects on our business and results of operations. Each of the applicable regulatory requirements and limitations is subject to change, either through new regulations enacted on the federal, state or local level, or by new or modified regulations that may be implemented under existing law. The nature and extent of any changes in these laws, rules, regulations and permits may be unpredictable, have retroactive effects, and may have material effects on our business. Future legislation and regulations or changes in existing legislation and regulations, or interpretations thereof, such as those relating to power, natural gas or LNG operations, including exploration, development and production activities, liquefaction, regasification or transportation of our products, could cause additional expenditures, restrictions and delays in connection with our operations as well as other future projects, the extent of which cannot be predicted and which may require us to limit substantially, delay or cease operations in some circumstances.

In addition, these rules and regulations are assessed, managed, administered and enforced by various governmental agencies and bodies, whose actions and decisions could adversely affect our business or operations. In the United States and Puerto Rico, approvals of the Department of Energy (“DOE”) under Section 3 of the NGA, as well as several other material governmental and regulatory permits, approvals and authorizations, including under the CAA and the CWA and their state analogues, may be required in order to construct and operate an LNG facility and export LNG. Permits, approvals and authorizations obtained from the DOE and other federal and state regulatory agencies also contain ongoing conditions, and additional requirements may be imposed. Certain federal permitting processes may trigger the requirements of the National Environmental Policy Act (“NEPA”), which requires federal agencies to evaluate major agency actions that have the potential to significantly impact the environment. Compliance with NEPA may extend the time and/or increase the costs for obtaining necessary governmental approvals associated with our operations and create independent risk of legal challenges to the adequacy of the NEPA analysis, which could result in delays that may adversely affect our business, contracts, financial condition, operating results, cash flow, liquidity and profitability. On July 15, 2020, the White House Council on Environmental Quality issued a final rule revising its NEPA regulations. These regulations have taken legal effect, and although they have been challenged in court, they have not been stayed. The Council on Environmental Quality has announced that it is engaged in an ongoing and comprehensive review of the revised regulations and is assessing whether and how the Council may ultimately undertake a new rulemaking to revise the regulations. The impacts of any such future revisions that may be adopted are uncertain and indeterminable for the foreseeable future. On June 18, 2020, we received an order from FERC, which asked us to explain why our San Juan Facility is not subject to FERC’s jurisdiction under section 3 of the NGA. On March 19, 2021, as upheld on rehearing on July 15, 2021, FERC determined that our San Juan Facility is subject to its jurisdiction and directed us to file an application for authorization to operate the San Juan Facility within 180 days of the order, which was September 15, 2021, but also found that allowing operation of the San Juan Facility to continue during the pendency of an application is in the public interest. The FERC orders were affirmed by the United States Court of Appeals for the District of Columbia Circuit on June 14, 2022. In order to comply with the FERC’s directive, on September 15, 2021, we filed an application for authorization to operate the San Juan Facility, which remains pending.

We may not comply with each of these requirements in the future, or at all times, including any changes to such laws and regulations or their interpretation. The failure to satisfy any applicable legal requirements may result in the suspension of our operations, the imposition of fines and/or remedial measures, suspension or termination of permits or other authorization, as well as potential administrative, civil and criminal penalties, which may significantly increase compliance costs and the need for additional capital expenditures.

Failure to obtain and maintain permits, approvals and authorizations from governmental and regulatory agencies and third parties on favorable terms could impede operations and construction.

The design, construction and operation of our infrastructure, facilities and businesses, including our FSRUs, FLNG units and LNG carriers, the import and export of LNG, exploration and development activities, and the transportation of natural gas, among others, are highly regulated activities at the national, state and local levels and are subject to various approvals and permits. The process to obtain the permits, approvals and authorizations we need to conduct our business, and the interpretations of those rules, is complex, time-consuming, challenging and varies in each jurisdiction in which we operate. We may be unable to obtain such approvals on terms that are satisfactory for our operations and on a timeline that meets our commercial obligations. Many of these permits, approvals and authorizations require public notice and comment

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before they can be issued, which can lead to delays to respond to such comments, and even potentially to revise the permit application. We may also be (and have been in select circumstances) subject to local opposition, including citizens groups or non-governmental organizations such as environmental groups, which may create delays and challenges in our permitting process and may attract negative publicity, which may create an adverse impact on our reputation. In addition, such rules change frequently and are often subject to discretionary interpretations, including administrative and judicial challenges by regulators, all of which may make compliance more difficult and may increase the length of time it takes to receive regulatory approval for our operations, particularly in countries where we operate, such as Mexico and Brazil. For example, in Mexico, we have obtained substantially all permits but are awaiting final approvals for our power plant and permits necessary to operate our terminal. In connection with our application to the U.S. Maritime Administration ("MARAD") related to our FLNG project off the coast of Louisiana, MARAD announced it had initially paused the statutory 356-day application review timeline on August 16, 2022 pending receipt of additional information, and restarted the timeline on October 28, 2022. MARAD issued a second stop notice on November 23, 2022 and on December 22, 2022, MARAD issued a third data request for supplemental information. Following review of NFE's response to the December 2022 data requests, MARAD extended the stop-clock on February 21, 2023 pending clarification of responses and receipt of additional information. No assurance can be given that we will be able to obtain approval of this application and receive the required permits, approvals and authorizations from governmental and regulatory agencies related to our project on a timely basis or at all. We intend to apply for updated permits for the Pennsylvania Facility with the aim of obtaining these permits to coincide with the commencement of construction activities. We cannot assure if or when we will receive these permits, which are needed prior to commencing certain construction activities related to the facility. Any administrative and judicial challenges can delay and protract the process for obtaining and implementing permits and can also add significant costs and uncertainty. We cannot control the outcome of any review or approval process, including whether or when any such permits and authorizations will be obtained, the terms of their issuance, or possible appeals or other potential interventions by third parties that could interfere with our ability to obtain and maintain such permits and authorizations or the terms thereof. Furthermore, we are developing new technologies and operate in jurisdictions that may lack mature legal and regulatory systems and may experience legal instability, which may be subject to regulatory and legal challenges, instability or clarity of application of laws, rules and regulations to our business and new technology, which can result in difficulties and instability in obtaining or securing required permits or authorizations. There is no assurance that we will obtain and maintain these permits and authorizations on favorable terms, or that we will be able to obtain them on a timely basis, and we may not be able to complete our projects, start or continue our operations, recover our investment in our projects and may be subject to financial penalties or termination under our customer and other agreements, which could have a material adverse effect on our business, financial condition, operating results, liquidity and prospects.

When we invest significant capital to develop a project, we are subject to the risk that the project is not successfully developed and that our customers do not fulfill their payment obligations to us following our capital investment in a project.

A key part of our business strategy is to attract new customers by agreeing to finance and develop new facilities, power plants, liquefaction facilities and related infrastructure in order to win new customer contracts for the supply of natural gas, LNG, steam or power. This strategy requires us to invest capital and time to develop a project in exchange for the ability to sell our products and generate fees from customers in the future. When we develop these projects, our required capital expenditure may be significant, and we typically do not generate meaningful fees from customers until the project has commenced commercial operations, which may take a year or more to achieve. If the project is not successfully developed for any reason, we face the risk of not recovering some or all of our invested capital, which may be significant. If the project is successfully developed, we face the risks that our customers may not fulfill their payment obligations or may not fulfill other performance obligations that impact our ability to collect payment. Our customer contracts and development agreements do not fully protect us against this risk and, in some instances, may not provide any meaningful protection from this risk. This risk is heightened in foreign jurisdictions, particularly if our counterparty is a government or government-related entity because any attempt to enforce our contractual or other rights may involve long and costly litigation where the ultimate outcome is uncertain. If we invest capital in a project where we do not receive the payments we expect, we will have less capital to invest in other projects, our liquidity, results of operations and financial condition could be materially and adversely affected, and we could face the inability to comply with the terms of our existing debt or other agreements, which would exacerbate these adverse effects.

Failure to maintain sufficient working capital could limit our growth and harm our business, financial condition and results of operations.

We have significant working capital requirements, primarily driven by the delay between the purchase of and payment for natural gas and the extended payment terms that we offer our customers. Differences between the date when we pay our suppliers and the date when we receive payments from our customers may adversely affect our liquidity and our cash flows. We expect our working capital needs to increase as our total business increases. If we do not have sufficient working capital, we may not be able to pursue our growth strategy, respond to competitive pressures or fund key strategic

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initiatives, such as the development of our facilities, which may harm our business, financial condition and results of operations.

Our ability to generate revenues is substantially dependent on our current and future long-term agreements and the performance by customers under such agreements.

Our business strategy relies upon our ability to successfully market our products to our existing and new customers and enter into or replace our long-term supply and services agreements for the sale of natural gas, LNG, steam and power. If we contract with our customers on short-term contracts, our pricing can be subject to more fluctuations and less favorable terms, and our earnings are likely to become more volatile. An increasing emphasis on the short-term or spot LNG market may in the future require us to enter into contracts based on variable market prices, as opposed to contracts based on a fixed rate, which could result in a decrease in its cash flow in periods when the market price for shipping LNG is depressed or insufficient funds are available to cover its financing costs for related vessels. Our ability to generate cash is dependent on these customers’ continued willingness and ability to continue purchasing our products and services and to perform their obligations under their respective contracts. Their obligations may include certain nomination or operational responsibilities, construction or maintenance of their own facilities which are necessary to enable us to deliver and sell natural gas or LNG, and compliance with certain contractual representations and warranties. Further, adverse economic conditions in our industry increase the risk of nonpayment and nonperformance by customers, particularly customers that have sub-investment grade credit ratings. The COVID-19 pandemic could adversely impact our customers through decreased demand for power due to decreased economic activity and tourism, or through the adverse economic impact of the pandemic on their power customers. The impact of the COVID-19 pandemic, including governmental and other third-party responses thereto, on our customers could enhance the risk of nonpayment by such customers under our contracts, which would negatively affect our business, results of operations and financial condition. In particular, JPS and SJPC, which are public utility companies in Jamaica, could be subject to austerity measures imposed on Jamaica by the International Monetary Fund (the “IMF”) and other international lending organizations. Jamaica is currently subject to certain public spending limitations imposed by agreements with the IMF, and any changes under these agreements could limit JPS’s and SJPC’s ability to make payments under their long-term GSAs and, in the case of JPS, its ability to make payments under its PPA, with us. In addition, PREPA is currently subject to bankruptcy proceedings pending in the U.S. District Court for the District of Puerto Rico. As a result, PREPA’s ability to meet its payment obligations under its contracts will be largely dependent upon funding from federal sources. Specifically, PREPA’s contracting practices in connection with restoration and repair of PREPA’s electrical grid in Puerto Rico, and the terms of certain of those contracts, have been subject to comment and are the subject of review and hearings by U.S. federal and Puerto Rican governmental entities. Certain of our subsidiaries are counterparties to contracts with governmental entities, including PREPA. Although these contracts require payment and performance of certain obligations, we remain subject to the statutory limitations on enforcement of those contractual provisions that protect these governmental entities. In the event that PREPA or any applicable governmental counterparty does not have or does not obtain the funds necessary to satisfy their obligations to us under our agreements, or if they terminate our agreements prior to the end of the agreed term, our financial condition, results of operations and cash flows could be materially and adversely affected. If any of these customers fails to perform its obligations under its contract for the reasons listed above or for any other reason, our ability to provide products or services and our ability to collect payment could be negatively impacted, which could materially adversely affect our operating results, cash flow and liquidity, even if we were ultimately successful in seeking damages from such customer for a breach of contract.

Our current lack of asset and geographic diversification could have an adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Our results of operations for the year ended December 31, 2022 and the nine months ended September 30, 2023, include our Montego Bay Facility, Old Harbour Facility, San Juan Facility, certain industrial end-users and our Miami Facility. In addition, we placed a portion of our La Paz Facility into service in 2022, and our revenue and results of operations have begun to be impacted by operations in Mexico, including agreements with certain power generation facilities in Baja California Sur. Our results for 2023 exclude other developments, including our Puerto Sandino Facility, the Barcarena Facility, Santa Catarina Facility and Ireland Facility. Jamaica, Mexico and Puerto Rico have historically experienced economic volatility and the general condition and performance of their economies, over which we have no control, may affect our business, financial condition and results of operations. Jamaica, Mexico and Puerto Rico are subject to acts of terrorism or sabotage and natural disasters, in particular hurricanes, extreme weather conditions, crime and similar other risks which may negatively impact our operations in the region. See “—Risks Related to the Jurisdictions in Which We Operate—We are subject to the economic, political, social and other conditions in the jurisdictions in which we operate.” We may also be affected by trade restrictions, such as tariffs or other trade controls. Additionally, tourism is a significant driver of economic activity in these geographies and directly and indirectly affects local demand for our LNG and therefore our results of operations. Trends in tourism in these geographies are primarily driven by the economic

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condition of the tourists’ home country or territory, the condition of their destination, and the availability, affordability and desirability of air travel and cruises. Additionally, unexpected factors could reduce tourism at any time, including local or global economic recessions, terrorism, travel restrictions, pandemics, including the COVID-19 pandemic, severe weather or natural disasters. Due to our current lack of asset and geographic diversification, an adverse development at our operating facilities, in the energy industry or in the economic conditions in these geographies, would have a significantly greater impact on our financial condition and operating results than if we maintained more diverse assets and operating areas.

Because we are currently dependent upon a limited number of customers, the loss of a significant customer could adversely affect our operating results.

Our current results of operations and liquidity are, and will continue to be in the near future, substantially dependent upon a limited number of customers, including JPS (as defined herein), SJPC (as defined herein) and PREPA (as defined herein), which have each entered into long-term GSAs and, in the case of JPS, a PPA in relation to the power produced at the CHP Plant (as defined herein), with us, and Jamalco (as defined herein), which has entered into a long-term SSA with us, and which represent a substantial majority of our income. Our operating results are currently contingent on our ability to maintain LNG, natural gas, steam and power sales to these customers. Our near-term ability to generate cash is dependent on these customers’ continued willingness and ability to continue purchasing our products and services and to perform their obligations under their respective contracts. The loss of any of these customers could have an adverse effect on our revenues and we may not be able to enter into a replacement agreement on terms as favorable as the terminated agreement. We may be unable to accomplish our business plan to diversify and expand our customer base by attracting a broad array of customers, which could negatively affect our business, results of operations and financial condition.

We may not be able to convert our anticipated customer pipeline into binding long-term contracts, and if we fail to convert potential sales into actual sales, we will not generate the revenues and profits we anticipate.

We are actively pursuing a significant number of new contracts for the sale of LNG, natural gas, steam, and power with multiple counterparties in multiple jurisdictions. Counterparties commemorate their purchasing commitments for these products in various degrees of formality ranging from traditional contracts to less formal arrangements, including non-binding letters of intent, non-binding memorandums of understanding, non-binding term sheets and responding to requests for proposals with potential customers. These agreements and any award following a request for proposals are subject to negotiating final definitive documents. The negotiation process may cause us or our potential counterparty to adjust the material terms of the agreement, including the price, term, schedule and any related development obligations. We cannot assure you if or when we will enter into binding definitive agreements for transactions initially described in non-binding agreements, and the terms of our binding agreements may differ materially from the terms of the related non-binding agreements. In addition, the effectiveness of our binding agreements can be subject to a number of conditions precedent that may not materialize, rendering such agreements non-effective. Moreover, while certain of our long-term contracts contain minimum volume commitments, our expected sales to customers under existing contracts may be substantially in excess of such minimum volume commitments. Our near-term ability to generate cash is dependent on these customers’ continued willingness and ability to nominate in excess of such minimum quantities and to perform their obligations under their respective contracts. Given the variety of sales processes and counterparty acknowledgements of the volumes they will purchase, we sometimes identify potential sales volumes as being either “Committed” or “In Discussion.” “Committed” volumes generally refer to the volumes that management expects to be sold under binding contracts or awards under requests for proposals. “In Discussion” volumes generally refer to volumes related to potential customers that management is actively negotiating, responding to a request for proposals, or with respect to which management anticipates a request for proposals or competitive bid process to be announced based on discussions with potential customers. Management’s estimations of “Committed” and “In Discussion” volumes may prove to be incorrect. Accordingly, we cannot assure you that “Committed” or “In Discussion” volumes will result in actual sales, and such volumes should not be used to predict the Company’s future results. We may never sign a binding agreement to sell our products to the counterparty, or we may sell much less volume than we estimate, which could result in our inability to generate the revenues and profits we anticipate, having a material adverse effect on our results of operations and financial condition.

Our contracts with our customers are subject to termination under certain circumstances.

Our contracts with our customers contain various termination rights. For example, each of our long-term customer contracts, including the contracts with JPS, SJPC, Jamalco and PREPA, contain various termination rights allowing our customers to terminate the contract, including, without limitation:

•upon the occurrence of certain events of force majeure;

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•if we fail to make available specified scheduled cargo quantities;

•the occurrence of certain uncured payment defaults;

•the occurrence of an insolvency event;

•the occurrence of certain uncured, material breaches; and

•if we fail to commence commercial operations or achieve financial close within the agreed timeframes.

We may not be able to replace these contracts on desirable terms, or at all, if they are terminated. Contracts that we enter into in the future may contain similar provisions. If any of our current or future contracts are terminated, such termination could have a material adverse effect on our business, contracts, financial condition, operating results, cash flows, liquidity and prospects.

Competition in the LNG industry is intense, and some of our competitors have greater financial, technological and other resources than we currently possess.

A substantial majority of our revenue is dependent upon our LNG sales to third parties. We operate in the highly competitive industry for LNG and face intense competition from independent, technology-driven companies as well as from both major and other independent oil and natural gas companies and utilities, in the various markets in which we operate and many of which have been in operation longer than us. Various factors relating to competition may prevent us from entering into new or replacement customer contracts on economically comparable terms to existing customer contracts, or at all, including, among others:

•increases in worldwide LNG production capacity and availability of LNG for market supply;

•increases in demand for natural gas but at levels below those required to maintain current price equilibrium with respect to supply;

•increases in the cost to supply natural gas feedstock to our liquefaction projects;

•increases in the cost to supply LNG feedstock to our facilities;

•decreases in the cost of competing sources of natural gas, LNG or alternate fuels such as coal, heavy fuel oil and automotive diesel oil (“ADO”);

•decreases in the price of LNG; and

•displacement of LNG or fossil fuels more broadly by alternate fuels or energy sources or technologies (including but not limited to nuclear, wind, solar, biofuels and batteries) in locations where access to these energy sources is not currently available or prevalent.

In addition, we may not be able to successfully execute on our strategy to supply our existing and future customers with LNG produced primarily at our own liquefaction facilities upon completion of the Pennsylvania Facility or through our Fast LNG solution. Various competitors have and are developing LNG facilities in other markets, which will compete with our LNG facilities, including our Fast LNG solution. Some of these competitors have longer operating histories, more development experience, greater name recognition, larger staffs, larger and more versatile fleets, and substantially greater financial, technical and marketing resources than we currently possess. We also face competition for the contractors needed to build our facilities and skilled employees. See “—We may experience increased labor costs and regulation, and the unavailability of skilled workers or our failure to attract and retain qualified personnel, as well as our ability to comply with such labor laws, could adversely affect us.” The superior resources that some of these competitors have available for deployment could allow them to compete successfully against us, which could have a material adverse effect on our business, ability to realize benefits from future projects, results of operations, financial condition, liquidity and prospects. We anticipate that an increasing number of offshore transportation companies, including many with strong reputations and extensive resources and experience will enter the LNG transportation market and the FSRU market. This increased competition may cause greater price competition for our products. As a result of these factors, we may be unable to expand our relationships with existing customers or to obtain new customers on a favorable basis, if at all, which would have a material adverse effect on our business, results of operations and financial condition.

Cyclical or other changes in the demand for and price of LNG and natural gas may adversely affect our business and the performance of our customers.

Our business and the development of energy-related infrastructure and projects generally is based on assumptions about the future availability and price of natural gas and LNG and the prospects for international natural gas and LNG markets. Natural gas and LNG prices have at various times been and may become volatile due to one or more of the following factors:

•additions to competitive regasification capacity in North America, Brazil, Europe, Asia and other markets, which could divert LNG or natural gas from our business;

•imposition of tariffs by China or any other jurisdiction on imports of LNG from the United States;

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•insufficient or oversupply of natural gas liquefaction or export capacity worldwide;

•insufficient LNG tanker capacity;

•weather conditions and natural disasters;

•reduced demand and lower prices for natural gas;

•increased natural gas production deliverable by pipelines, which could suppress demand for LNG;

•decreased oil and natural gas exploration activities, including shut-ins and possible proration, which may decrease the production of natural gas;

•cost improvements that allow competitors to offer LNG regasification services at reduced prices;

•changes in supplies of, and prices for, alternative energy sources, such as coal, oil, nuclear, hydroelectric, wind and solar energy, which may reduce the demand for natural gas;

•changes in regulatory, tax or other governmental policies regarding imported or exported LNG, natural gas or alternative energy sources, which may reduce the demand for imported or exported LNG and/or natural gas;

•political conditions in natural gas producing regions;

•adverse relative demand for LNG compared to other markets, which may decrease LNG imports into or exports from North America; and

•cyclical trends in general business and economic conditions that cause changes in the demand for natural gas.

Adverse trends or developments affecting any of these factors, including the timing of the impact of these factors in relation to our purchases and sales of natural gas and LNG could result in increases in the prices we have to pay for natural gas or LNG, which could materially and adversely affect the performance of our customers, and could have a material adverse effect on our business, contracts, financial condition, operating results, cash flows, liquidity and prospects. The COVID-19 pandemic and certain actions by the Organization of Petroleum Exporting Countries ("OPEC") related to the supply of oil in the market have caused volatility and disruption in the price of oil which may negatively impact our potential customers’ willingness or ability to enter into new contracts for the purchase of natural gas. Additionally, in situations where our supply chain has capacity constraints and as a result we are unable to receive all volumes under our long-term LNG supply agreements, our supplier may sell volumes of LNG in a mitigation sale to third parties. In these cases, the factors above may impact the price and amount we receive under mitigation sales and we may incur losses that would have an adverse impact on our financial condition, results of operations and cash flows. Conversely, current market conditions have increased LNG values to historically high levels. The elevated market values could increase the economic incentives an LNG seller has to fail to deliver LNG cargos to us if they can sell the same LNG cargos at a higher price to another buyer in the market after giving effect to any contractual penalties the seller would owe to us for failing to deliver. Our contracts may not require an LNG seller to compensate us for the full current market value of an LNG cargo that we have purchased, and if so, we may not be contractually entitled to receive full economic indemnification upon an LNG seller’s failure to deliver an LNG cargo to us. Recently, the LNG industry has experienced increased volatility. If market disruptions and bankruptcies of third-party LNG suppliers and shippers negatively impacts our ability to purchase a sufficient amount of LNG or significantly increases our costs for purchasing LNG, our business, operating results, cash flows and liquidity could be materially and adversely affected. There can be no assurance we will achieve our target cost or pricing goals. In particular, because we have not currently procured fixed-price, long-term LNG supply to meet all future customer demand, increases in LNG prices and/or shortages of LNG supply could adversely affect our profitability. Our actual costs and any profit realized on the sale of our LNG may vary from the estimated amounts on which our contracts for feedgas were originally based. There is inherent risk in the estimation process, including significant changes in the demand for and price of LNG as a result of the factors listed above, many of which are outside of our control. If LNG were to become unavailable for current or future volumes of natural gas due to repairs or damage to supplier facilities or tankers, lack of capacity, impediments to international shipping or any other reason, our ability to continue delivering natural gas, power or steam to end-users could be restricted, thereby reducing our revenues. Any permanent interruption at any key LNG supply chains that caused a material reduction in volumes transported on or to our tankers and facilities could have a material adverse effect on our business, financial condition, operating results, cash flow, liquidity and prospects.

Our risk management strategies cannot eliminate all LNG price and supply risks. In addition, any non-compliance with our risk management strategies could result in significant financial losses.

Our strategy is to maintain a manageable balance between LNG purchases, on the one hand, and sales or future delivery obligations, on the other hand. Through these transactions, we seek to earn a margin for the LNG purchased by selling LNG for physical delivery to third-party users, such as public utilities, shipping/marine cargo companies, industrial users, railroads, trucking fleets and other potential end-users converting from traditional ADO or oil fuel to natural gas. These strategies cannot, however, eliminate all price risks. For example, any event that disrupts our anticipated supply chain could expose us to risk of loss resulting from price changes if we are required to obtain alternative supplies to cover these transactions. We are also exposed to basis risks when LNG is purchased against one pricing index and sold against a different index. Moreover, we are also exposed to other risks, including price risks on LNG we own, which must be maintained in order to facilitate transportation of the LNG to our customers or to our facilities. If we were to incur a

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material loss related to commodity price risks, it could have a material adverse effect on our financial position, results of operations and cash flows.

Any use of hedging arrangements may adversely affect our future operating results or liquidity.

To reduce our exposure to fluctuations in the price, volume and timing risk associated with the purchase of natural gas, we have entered and may in the future enter into futures, swaps and option contracts traded or cleared on the Intercontinental Exchange and the New York Mercantile Exchange or over-the-counter (“OTC”) options and swaps with other natural gas merchants and financial institutions. Hedging arrangements would expose us to risk of financial loss in some circumstances, including when expected supply is less than the amount hedged, the counterparty to the hedging contract defaults on its contractual obligations, or there is a change in the expected differential between the underlying price in the hedging agreement and actual prices received. The use of derivatives also may require the posting of cash collateral with counterparties, which can impact working capital when commodity prices change.

We are dependent on third-party LNG suppliers and the development of our own portfolio is subject to various risks and assumptions.

Under our GSAs, PPAs and SSAs, we are required to deliver to our customers specified amounts of LNG, natural gas, power and steam, respectively, at specified times and within certain specifications, all of which requires us to obtain sufficient amounts of LNG from third-party LNG suppliers or our own portfolio. We may not be able to purchase or receive physical delivery of sufficient quantities of LNG to satisfy those delivery obligations, which may provide a counterparty with the right to terminate its GSA, PPA or SSA, as applicable, or subject us to remedial obligations under those agreements. While we have entered into supply agreements for the purchase of LNG between 2023 and 2030, we may need to purchase significant additional LNG volumes to meet our delivery obligations to our downstream customers. Price fluctuations in natural gas and LNG may make it expensive or uneconomical for us to acquire adequate supply of these items or to sell our inventory of natural gas or LNG at attractive prices. Failure to secure contracts for the purchase of a sufficient amount of LNG or at favorable prices could materially and adversely affect our business, operating results, cash flows and liquidity.

The development of our own portfolio of LNG is subject to various risks and assumptions. In particular, the estimation of proved gas reserves involves subjective judgements and determinations based on available geological, technical, contractual, and economic information. Estimates can change over time because of new information from production or drilling activities, changes in economic factors, such as oil and gas prices, alterations in the regulatory policies of host governments, or other events. Estimates also change to reflect acquisitions, divestments, new discoveries, extensions of existing fields and mines, and improved recovery techniques. Published proved gas reserves estimates could also be subject to correction because of errors in the application of rules and changes in guidance. Downward adjustments could indicate lower future production volumes and could also lead to impairment of assets. This could have a material adverse effect on our business, operating results, cash flows and liquidity.

Additionally, we are dependent upon third-party LNG suppliers and shippers and other tankers and facilities to provide delivery options to and from our tankers and energy-related infrastructure. If any third parties were to default on their obligations under our contracts or seek bankruptcy protection, we may not be able to replace such contracts or purchase LNG on the spot market or receive a sufficient quantity of LNG in order to satisfy our delivery obligations under our GSAs, PPAs and SSAs or at favorable terms. Under tanker charters, we will be obligated to make payments for our chartered tankers regardless of use. We may not be able to enter into contracts with purchasers of LNG in quantities equivalent to or greater than the amount of tanker capacity we have purchased, as our vessels may be too small for those obligations. Any such failure to purchase or receive delivery of LNG or natural gas in sufficient quantities could result in our failure to satisfy our obligations to our customers, which could lead to losses, penalties, indemnification and potentially a termination of agreements with our customers. Furthermore, we may seek to litigate any such breaches by our third-party LNG suppliers and shippers. Such legal proceedings may involve claims for substantial amounts of money and we may not be successful in pursing such claims. Even if we are successful, any litigation may be costly and time-consuming. If any such proceedings were to result in an unfavorable outcome, we may not be able to recover our losses (including lost profits) or any damages sustained from our agreements with our customers. See “—General Risks—We are and may be involved in legal proceedings and may experience unfavorable outcomes.” These actions could also expose us to adverse publicity, which might adversely affect our reputation and therefore, our results of operations. Further, if, it could have an adverse effect on our business, operating results, cash flows and liquidity, which could in turn materially and adversely affect our liquidity to make payments on our debt or comply with our financial ratios and other covenants. See “—We have incurred, and may in the future incur, a significant amount of debt.”

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We may not be able to fully utilize the capacity of our FSRUs and other facilities.

Our FSRU facilities have significant excess capacity that is currently not dedicated to a particular anchor customer. Part of our business strategy is to utilize undedicated excess capacity of our FSRU facilities to serve additional downstream customers in the regions in which we operate. However, we have not secured, and we may be unable to secure, commitments for all of our excess capacity. Factors which could cause us to contract less than full capacity include difficulties in negotiations with potential counterparties and factors outside of our control such as the price of and demand for LNG. Failure to secure commitments for less than full capacity could impact our future revenues and materially adversely affect our business, financial condition and operating results.

LNG that is processed and/or stored on FSRUs and transported via pipeline is subject to risk of loss or damage.

LNG processed and stored on FSRUs may be subject to loss or damage resulting from equipment malfunction, faulty handling, ageing or otherwise. Where we have chartered in, but subsequently not outchartered an FSRU, which in turn results in our being unable to transfer risk of loss or damage, we could bear the risk of loss or damage to all those volumes of LNG for the period of time during which those applicable volumes of LNG are stored on an FSRU or are dispatched to a pipeline. Any such disruption to the supply of LNG and natural gas may lead to delays, disruptions or curtailments in the production of power at our facilities, which could materially and adversely affect our revenues, financial condition and results of operations.

The operation of our vessels is dependent on our ability to deploy our vessels to an NFE terminal or to long-term charters.

Our principal strategy for our FSRU and LNG carriers is to provide steady and reliable shipping, regasification and offshore operations to NFE terminals and, to the extent favorable to our business, replace or enter into new long-term carrier time charters for our vessels. Most requirements for new LNG projects continue to be provided on a long-term basis, though the level of spot voyages and short-term time charters of less than 12 months in duration together with medium term charters of up to five years has increased in recent years. This trend is expected to continue as the spot market for LNG expands. More frequent changes to vessel sizes, propulsion technology and emissions profile, together with an increasing desire by charterers to access modern tonnage could also reduce the appetite of charterers to commit to long-term charters that match their full requirement period. As a result, the duration of long-term charters could also decrease over time. We may also face increased difficulty entering into long-term time charters upon the expiration or early termination of our contracts. The process of obtaining long-term charters for FSRUs and LNG carriers is highly competitive and generally involves an intensive screening process and competitive bids, and often extends for several months. If we lose any of our charterers and are unable to re-deploy the related vessel to a NFE terminal or into a new replacement contract for an extended period of time, we will not receive any revenues from that vessel, but we will be required to pay expenses necessary to maintain the vessel in seaworthy operating condition and to service any associated debt.

We rely on tankers and other vessels outside of our fleet for our LNG transportation and transfer.

In addition to our own fleet of vessels, we rely on third-party ocean-going tankers and freight carriers (for ISO containers) for the transportation of LNG and ship-to-ship kits to transfer LNG between ships. We may not be able to successfully enter into contracts or renew existing contracts to charter tankers on favorable terms or at all, which may result in us not being able to meet our obligations. Our ability to enter into contracts or renew existing contracts will depend on prevailing market conditions upon expiration of the contracts governing the leasing or charter of the applicable assets. Therefore, we may be exposed to increased volatility in terms of charter rates and contract provisions. Fluctuations in rates result from changes in the supply of and demand for capacity and changes in the demand for seaborne carriage of commodities. Because the factors affecting the supply and demand are outside of our control and are highly unpredictable, the nature, timing, direction and degree of changes in industry conditions are also unpredictable. Likewise, our counterparties may seek to terminate or renegotiate their charters or leases with us. If we are not able to renew or obtain new charters or leases in direct continuation, or if new charters or leases are entered into at rates substantially above the existing rates or on terms otherwise less favorable compared to existing contractual terms, our business, prospects, financial condition, results of operations and cash flows could be materially adversely affected.

Furthermore, our ability to provide services to our customers could be adversely impacted by shifts in tanker market dynamics, shortages in available cargo carrying capacity, changes in policies and practices such as scheduling, pricing, routes of service and frequency of service, or increases in the cost of fuel, taxes and labor, emissions standards, maritime regulatory changes and other factors not within our control. The availability of the tankers could be delayed to the detriment of our LNG business and our customers because the construction and delivery of LNG tankers require significant capital and long construction lead times. Changes in ocean freight capacity, which are outside our control, could negatively

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impact our ability to provide natural gas if LNG shipping capacity is adversely impacted and LNG transportation costs increase because we may bear the risk of such increases and may not be able to pass these increases on to our customers.

The operation of ocean-going tankers and kits carries inherent risks. These risks include the possibility of natural disasters; mechanical failures; grounding, fire, explosions and collisions; piracy; human error; epidemics; and war and terrorism. We do not currently maintain a redundant supply of ships, ship-to-ship kits or other equipment. As a result, if our current equipment fails, is unavailable or insufficient to service our LNG purchases, production, or delivery commitments we may need to procure new equipment, which may not be readily available or be expensive to obtain. Any such occurrence could delay the start of operations of facilities we intend to commission, interrupt our existing operations and increase our operating costs. Any of these results could have a material adverse effect on our business, financial condition and operating results.

Hire rates for FSRUs and LNG carriers may fluctuate substantially. If rates are lower when we are seeking a new charter, our earnings may decline.

Hire rates for FSRUs and LNG carriers fluctuate over time as a result of changes in the supply-demand balance relating to current and future FSRU and LNG carrier capacity. This supply-demand relationship largely depends on a number of factors outside of our control. For example, driven in part by an increase in LNG production capacity, the market supply particularly of LNG carriers has been increasing. We believe that this and any future expansion of the global LNG carrier fleet may have a negative impact on charter hire rates, vessel utilization and vessel values, the impact of which could be amplified if the expansion of LNG production capacity does not keep pace with fleet growth. The LNG market is also closely connected to world natural gas prices and energy markets, which it cannot predict. A substantial or extended decline in demand for natural gas or LNG could adversely affect our ability to charter or re-charter our vessels at acceptable rates or to acquire and profitably operate new vessels. Accordingly, this could have a material adverse effect on our earnings, financial condition, operating results and prospects.

Vessel values may fluctuate substantially and, if these values are lower at a time when we are attempting to dispose of vessels, we may incur a loss.

Vessel values can fluctuate substantially over time due to a number of different factors, including:

•prevailing economic conditions in the natural gas and energy markets;

•a substantial or extended decline in demand for LNG;

•increases in the supply of vessel capacity without a commensurate increase in demand;

•the size and age of a vessel; and

•the cost of retrofitting, steel or modifying existing vessels, as a result of technological advances in vessel design or equipment, changes in applicable environmental or other regulations or standards, customer requirements or otherwise.

As our vessels age, the expenses associated with maintaining and operating them are expected to increase, which could have an adverse effect on our business and operations if we do not maintain sufficient cash reserves for maintenance and replacement capital expenditures. Moreover, the cost of a replacement vessel would be significant.

During the period a vessel is subject to a charter, we will not be permitted to sell it to take advantage of increases in vessel values without the charterers’ consent. If a charter terminates, we may be unable to re-deploy the affected vessels at attractive rates or for our operations and, rather than continue to incur costs to maintain and finance them, we may seek to dispose of them. When vessel values are low, we may not be able to dispose of vessels at a reasonable price when we wish to sell vessels, and conversely, when vessel values are elevated, we may not be able to acquire additional vessels at attractive prices when we wish to acquire additional vessels, which could adversely affect our business, results of operations, cash flow, and financial condition.

The carrying values of our vessels may not represent their fair market value at any point in time because the market prices of secondhand vessels tend to fluctuate with changes in charter rates and the cost of new build vessels. Our vessels are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Although we did not recognize an impairment charge on any vessels for the year ended December 31, 2022, we cannot assure you that we will not recognize impairment losses on our vessels in future years. Any impairment charges incurred as a result of declines in charter rates could negatively affect our business, financial condition, or operating results.

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Maritime claimants could arrest our vessels, which could interrupt our cash flow.

If we are in default on certain kinds of obligations related to our vessels, such as those to our lenders, crew members, suppliers of goods and services to our vessels or shippers of cargo, these parties may be entitled to a maritime lien against one or more of our vessels. In many jurisdictions, a maritime lien holder may enforce its lien by arresting a vessel through foreclosure proceedings. In a few jurisdictions, claimants could try to assert “sister ship” liability against one vessel in our fleet for claims relating to another of our vessels. The arrest or attachment of one or more of our vessels could interrupt our cash flow and require us to pay to have the arrest lifted. Under some of our present charters, if the vessel is arrested or detained (for as few as 14 days in the case of one of our charters) as a result of a claim against us, we may be in default of our charter and the charterer may terminate the charter. This would negatively impact our revenues and cash flows.

We seek to develop innovative and new technologies as part of our strategy that are not yet proven and may not realize the time and cost savings we expect to achieve.

We analyze and seek to implement innovative and new technologies that complement our businesses to reduce our costs, achieve efficiencies for our business and our customers and advance our long-term goals, such as our ISO container distribution system, our Fast LNG solution and our green hydrogen project. The success of our current operations and future projects will depend in part on our ability to create and maintain a competitive position in the natural gas liquefaction industry. We have developed our Fast LNG strategy to procure and deliver LNG to our customers more quickly and cost-effectively than traditional LNG procurement and delivery strategies used by other market participants. See “—Our Fast LNG technology is not yet proven and we may not be able to implement it as planned or at all.” We are also making investments to develop green hydrogen energy technologies as part of our long-term goal to become one of the world’s leading providers of carbon-free energy. We continue to develop our ISO container distribution systems in the various markets where we operate. We expect to make additional investments in this field in the future. Because these technologies are innovative, we may be making investments in unproven business strategies and technologies with which we have limited or no prior development or operating experience. As an investor in these technologies, it is also possible that we could be exposed to claims and liabilities, expenses, regulatory challenges and other risks. We may not be able to successfully develop these technologies, and even if we succeed, we may ultimately not be able to realize the time, revenues and cost savings we currently expect to achieve from these strategies, which could adversely affect our financial results.

Technological innovation may impair the economic attractiveness of our projects.

The success of our current operations and future projects will depend in part on our ability to create and maintain a competitive position in the natural gas liquefaction industry. In particular, although we plan to build out our delivery logistics chain in Northern Pennsylvania using proven technologies such as those currently in operation at our Miami Facility, we do not have any exclusive rights to any of these technologies. In addition, such technologies may be rendered obsolete or uneconomical by legal or regulatory requirements, technological advances, more efficient and cost-effective processes or entirely different approaches developed by one or more of our competitors or others, which could materially and adversely affect our business, ability to realize benefits from future projects, results of operations, financial condition, liquidity and prospects.

Our Fast LNG technology is not yet proven and we may not be able to implement it as planned or at all.

We have developed our Fast LNG strategy to procure and deliver LNG to our customers more quickly and cost-effectively than traditional LNG procurement and delivery strategies used by other market participants. Our ability to create and maintain a competitive position in the natural gas liquefaction industry may be adversely affected by our inability to effectively implement our Fast LNG technology. We are finalizing construction of our first Fast LNG solution, and are therefore subject to construction risks, risks associated with third-party contracting and service providers, permitting and regulatory risks. See “—We are subject to various construction risks” and “—We depend on third-party contractors, operators and suppliers.” Because our Fast LNG technology has not been previously implemented, tested or proven, we are also exposed to unknown and unforeseen risks associated with the development of new technologies, including failure to meet design, engineering, or performance specifications, incompatibility of systems, inability to contract or employ third parties with sufficient experience in technologies used or inability by contractors to perform their work, delays and schedule changes, high costs and expenses that may be subject to increase or difficult to anticipate, regulatory and legal challenges, instability or clarity of application of laws, rules and regulations to the technology, and added difficulties in obtaining or securing required permits or authorizations, among others. See “—Failure to obtain and maintain permits, approvals and authorizations from governmental and regulatory agencies and third parties on favorable terms could impede operations and construction.” The success and profitability of our Fast LNG technology is also dependent on the volatility of the price of natural gas and LNG compared to the related levels of capital spending required to implement the technology. Natural gas and LNG prices have at various times been and may become volatile due to one

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or more factors. Volatility or weakness in natural gas or LNG prices could render our LNG procured through Fast LNG too expensive for our customers, and we may not be able to obtain our anticipated return on our investment or make our technology profitable. In addition, we may seek to construct and develop floating offshore liquefaction units as part of our Fast LNG in jurisdictions which could potentially expose us to increased political, economic, social and legal instability, a lack of regulatory clarity of application of laws, rules and regulations to our technology, or additional jurisdictional risks related to currency exchange, tariffs and other taxes, changes in laws, civil unrest, and similar risks. See “—Risks Related to the Jurisdictions in Which We Operate—We are subject to the economic, political, social and other conditions in the jurisdictions in which we operate.” Furthermore, as part of our business strategy for Fast LNG, we may enter into tolling agreements with third parties, including in developing countries, and these counterparties may have greater credit risk than typical. Therefore, we may be exposed to greater customer credit risk than other companies in the industry. Our credit procedures and policies may be inadequate to sufficiently eliminate risks of nonpayment and nonperformance. We may not be able to successfully develop, construct and implement our Fast LNG solution, and even if we succeed in developing and constructing the technology, we may ultimately not be able to realize the cost savings and revenues we currently expect to achieve from it, which could result in a material adverse effect upon our operations and business.

We have incurred, and may in the future incur, a significant amount of debt.

On an ongoing basis, we engage with lenders and other financial institutions in an effort to improve our liquidity and capital resources. As of December 31, 2022 and September 30, 2023, we had approximately $4.5 billion and $5.5 billion, respectively, aggregate principal amount of indebtedness outstanding on a consolidated basis. The terms and conditions of our indebtedness include restrictive covenants that may limit our ability to operate our business, to incur or refinance our debt, engage in certain transactions, and require us to maintain certain financial ratios, among others, any of which may limit our ability to finance future operations and capital needs, react to changes in our business and in the economy generally, and to pursue business opportunities and activities. If we fail to comply with any of these restrictions or are unable to pay our debt service when due, our debt could be accelerated or cross-accelerated, and we cannot assure you that we will have the ability to repay such accelerated debt. Any such default could also have adverse consequences to our status and reporting requirements, reducing our ability to quickly access the capital markets. Our ability to service our existing and any future debt will depend on our performance and operations, which is subject to factors that are beyond our control and compliance with covenants in the agreements governing such debt. We may incur additional debt to fund our business and strategic initiatives. If we incur additional debt and other obligations, the risks associated with our substantial leverage and the ability to service such debt would increase, which could have a material adverse effect on our business, results of operation and financial condition.

Our business is dependent upon obtaining substantial additional funding from various sources, which may not be available or may only be available on unfavorable terms.

We believe we will have sufficient liquidity, cash flow from operations and access to additional capital sources to fund our capital expenditures and working capital needs for the next 12 months and the reasonably foreseeable future. In the future, we expect to incur additional indebtedness to assist us in developing our operations and we are considering alternative financing options, including in specific markets or the opportunistic sale of one of our non-core assets. We also historically have relied, and in the future will likely rely, on borrowings under term loans and other debt instruments to fund our capital expenditures. If any of the lenders in the syndicates backing these debt instruments were unable to perform on its commitments, we may need to seek replacement financing. We cannot assure you that such additional funding will be available on acceptable terms, or at all. Our ability to raise additional capital on acceptable terms will depend on financial, economic and market conditions, which have increased in volatility and at times have been negatively impacted due to the COVID-19 pandemic, our progress in executing our business strategy and other factors, many of which are beyond our control, including domestic or international economic conditions, increases in key benchmark interest rates and/or credit spreads, the adoption of new or amended banking or capital market laws or regulations, the re-pricing of market risks and volatility in capital and financial markets, risks relating to the credit risk of our customers and the jurisdictions in which we operate, as well as general risks applicable to the energy sector. Additional debt financing, if available, may subject us to increased restrictive covenants that could limit our flexibility in conducting future business activities and could result in us expending significant resources to service our obligations. Additionally, we may need to adjust the timing of our planned capital expenditures and facilities development depending on the requirements of our existing financing and availability of such additional funding. If we are unable to obtain additional funding, approvals or amendments to our financings outstanding from time to time, or if additional funding is only available on terms that we determine are not acceptable to us, we may be unable to fully execute our business plan, we may be unable to pay or refinance our indebtedness or to fund our other liquidity needs, and our financial condition or results of operations may be materially adversely affected.

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We have entered into, and may in the future enter into or modify existing, joint ventures that might restrict our operational and corporate flexibility or require credit support.

We have entered into, and may in the future enter, into joint venture arrangements with third parties in respect of our projects and assets. In August 2022, we established Energos, as a joint venture platform with certain funds or investment vehicles managed by Apollo, for the development of a global marine infrastructure platform, of which we own 20%. As we do not operate the assets owned by these joint ventures, our control over their operations is limited by provisions of the agreements we have entered into with our joint venture partners and by our percentage ownership in such joint ventures. Because we do not control all of the decisions of our joint ventures, it may be difficult or impossible for us to cause the joint venture to take actions that we believe would be in its or the joint venture’s best interests. For example, we cannot unilaterally cause the distribution of cash by our joint ventures. Additionally, as the joint ventures are separate legal entities, any right we may have to receive assets of any joint venture or other payments upon their liquidation or reorganization will be effectively subordinated to the claims of the creditors of that joint venture (including tax authorities, trade creditors and any other third parties that require such subordination, such as lenders and other creditors). Moreover, joint venture arrangements involve various risks and uncertainties, such as our commitment to fund operating and/or capital expenditures, the timing and amount of which we may not control, and our joint venture partners may not satisfy their financial obligations to the joint venture. We have provided and may in the future provide guarantees or other forms of credit support to our joint ventures and/or affiliates. Failure by any of our joint ventures, equity method investees and/or affiliates to service their debt requirements and comply with any provisions contained in their commercial loan agreements, including paying scheduled installments and complying with certain covenants, may lead to an event of default under the related loan agreement. As a result, if our joint ventures, equity method investees and/or affiliates are unable to obtain a waiver or do not have enough cash on hand to repay the outstanding borrowings, the relevant lenders may foreclose their liens on the relevant assets or vessels securing the loans or seek repayment of the loan from us, or both. Either of these possibilities could have a material adverse effect on our business. Further, by virtue of our guarantees with respect to our joint ventures and/or affiliates, this may reduce our ability to gain future credit from certain lenders.

The swaps regulatory and other provisions of the Dodd-Frank Act and the rules adopted thereunder and other regulations, including EMIR and REMIT, could adversely affect our ability to hedge risks associated with our business and our operating results and cash flows.

We have entered and may in the future enter into futures, swaps and option contracts traded or cleared on the Intercontinental Exchange and the New York Mercantile Exchange or OTC options and swaps with other natural gas merchants and financial institutions. Title VII of the Dodd-Frank Act established federal regulation of the OTC derivatives market and made other amendments to the Commodity Exchange Act that are relevant to our business. The provisions of Title VII of the Dodd-Frank Act and the rules adopted thereunder by the Commodity Futures Trading Commission (the “CFTC”), the SEC and other federal regulators may adversely affect the cost and availability of the swaps that we may use for hedging, including, without limitation, rules setting limits on the positions in certain contracts, rules regarding aggregation of positions, requirements to clear through specific derivatives clearing organizations and trading platforms, requirements for posting of margins, regulatory requirements on swaps market participants. Our counterparties that are also subject to the capital requirements set out by the Basel Committee on the Banking Supervision in 2011, commonly referred to as “Basel III,” may increase the cost to us of entering into swaps with them or, although not required to collect margin from us under the margin rules, require us to post collateral with them in connection with such swaps in order to offset their increased capital costs or to reduce their capital costs to maintain those swaps on their balance sheets. Our subsidiaries and affiliates operating in Europe and the Caribbean may be subject to the European Market Infrastructure Regulation (“EMIR”) and the Regulation on Wholesale Energy Market Integrity and Transparency (“REMIT”) as wholesale energy market participants, which may impose increased regulatory obligations, including a prohibition to use or disclose insider information or to engage in market manipulation in wholesale energy markets, and an obligation to report certain data, as well as requiring liquid collateral. These regulations could significantly increase the cost of derivative contracts (including through requirements to post margin or collateral), materially alter the terms of derivative contracts, reduce the availability of derivatives to protect against certain risks that we encounter, and reduce our ability to monetize or restructure derivative contracts and to execute our hedging strategies. If, as a result of the swaps regulatory regime discussed above, we were to forgo the use of swaps to hedge our risks, such as commodity price risks that we encounter in our operations, our operating results and cash flows may become more volatile and could be otherwise adversely affected.

We may incur impairments to long-lived assets.

We test our long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of these assets may not be recoverable. Significant negative industry or economic trends, decline of our market capitalization, reduced estimates of future cash flows for our business segments or disruptions to our business, or adverse actions by governmental entities, changes to regulation or legislation could lead to an impairment charge of our long-lived assets. Our valuation methodology for assessing impairment requires management to make judgments and assumptions

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based on historical experience and to rely heavily on projections of future operating performance. Projections of future operating results and cash flows may vary significantly from results. In addition, if our analysis results in an impairment to our long-lived assets, we may be required to record a charge to earnings in our condensed consolidated financial statements during a period in which such impairment is determined to exist, which may negatively impact our operating results.

Weather events or other natural or manmade disasters or phenomena, some of which may be adversely impacted by global climate change, could have a material adverse effect on our operations and projects, as well as on the economies in the markets in which we operate or plan to operate.

Weather events such as storms and related storm activity and collateral effects, or other disasters, accidents, catastrophes or similar events, natural or manmade, such as explosions, fires, seismic events, floods or accidents, could result in damage to our facilities, liquefaction facilities, or related infrastructure, interruption of our operations or our supply chain, as well as delays or cost increases in the construction and the development of our proposed facilities or other infrastructure. Changes in the global climate may have significant physical effects, such as increased frequency and severity of storms, floods and rising sea levels; if any such effects were to occur, they could have an adverse effect on our onshore and offshore operations. Due to the nature of our operations, we are particularly exposed to the risks posed by hurricanes, tropical storms and their collateral effects, in particular with respect to fleet operations, floating offshore liquefaction units and other infrastructure we may develop in connection with our Fast LNG technology. In particular, we may seek to construct and develop floating offshore liquefaction units as part of our Fast LNG in locations that are subject to risks posed by hurricanes and similar severe weather conditions or natural disasters or other adverse events or conditions that could severely affect our infrastructure, resulting in damage or loss, contamination to the areas, and suspension of our operations. For example, our operations in coastal regions in southern Florida, the Caribbean, the Gulf of Mexico and Latin America are frequently exposed to natural hazards such as sea-level rise, coastal flooding, cyclones, extreme heat, hurricanes, and earthquakes. These climate risks can affect our operations, potentially even damaging or destroying our facilities, leading to production downgrades, costly delays, reduction in workforce productivity, and potential injury to our people. In addition, jurisdictions with increased political, economic, social and legal instability, lack of regulatory clarity of application of laws, rules and regulations to our technology, and could potentially expose us to additional jurisdictional risks related to currency exchange, tariffs and other taxes, changes in laws, civil unrest, and similar risks. In addition, because of the location of some of our operations, we are subject to other natural phenomena, including earthquakes, such as the one that occurred near Puerto Rico in January 2020, which resulted in a temporary delay of development of our Puerto Rico projects, hurricanes and tropical storms. If one or more tankers, pipelines, facilities, liquefaction facilities, vessels, equipment or electronic systems that we own, lease or operate or that deliver products to us or that supply our facilities, liquefaction facilities, and customers’ facilities are damaged by severe weather or any other disaster, accident, catastrophe or similar event, our construction projects and our operations could be significantly interrupted, damaged or destroyed. These delays, interruptions and damages could involve substantial damage to people, property or the environment, and repairs could take a significant amount of time, particularly in the event of a major interruption or substantial damage. We do not, nor do we intend to, maintain insurance against all of these risks and losses. We may not be able to maintain desired or required insurance in the future at rates that we consider reasonable. See “—Our insurance may be insufficient to cover losses that may occur to our property or result from our operations.” The occurrence of a significant event, or the threat thereof, could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Existing and future environmental, social, health and safety laws and regulations could result in increased or more stringent compliance requirements, which may be difficult to comply with or result in additional costs and may otherwise lead to significant liabilities and reputational damage.

Our business is now and will in the future be subject to extensive national, federal, state, municipal and local laws, rules and regulations, in the United States and in the jurisdictions where we operate, relating to the environment, social, health and safety and hazardous substances. These requirements regulate and restrict, among other things: the siting and design of our facilities; discharges to air, land and water, with particular respect to the protection of human health, the environment and natural resources and safety from risks associated with storing, receiving and transporting LNG, natural gas and other substances; the handling, storage and disposal of hazardous materials, hazardous waste and petroleum products; and remediation associated with the release of hazardous substances. Many of these laws and regulations, such as the CAA and the CWA, and analogous laws and regulations in the jurisdictions in which we operate, restrict or prohibit the types, quantities and concentrations of substances that can be emitted into the environment in connection with the construction and operation of our facilities and vessels, and require us to obtain and maintain permits and provide governmental authorities with access to our facilities and vessels for inspection and reports related to our compliance. For example, the Pennsylvania Department of Environmental Protection laws and regulations will apply to the construction and operation of the Pennsylvania Facility. Changes or new environmental, social, health and safety laws and regulations could cause additional expenditures, restrictions and delays in our business and operations, the extent of which cannot be predicted and which may require us to limit substantially, delay or cease operations in some circumstances. For example, in

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October 2017, the U.S. Government Accountability Office issued a legal determination that a 2013 interagency guidance document was a “rule” subject to the Congressional Review Act (“CRA”). This legal determination could open a broader set of agency guidance documents to potential disapproval and invalidation under the CRA, potentially increasing the likelihood that laws and regulations applicable to our business will become subject to revised interpretations in the future that we cannot predict. Revised, reinterpreted or additional laws and regulations that result in increased compliance costs or additional operating or construction costs and restrictions could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Any failure in environmental, social, health and safety performance from our operations may result in an event that causes personal harm or injury to our employees, other persons, and/or the environment, as well as the imposition of injunctive relief and/or penalties or fines for non-compliance with relevant regulatory requirements or litigation. Such a failure, or a similar failure elsewhere in the energy industry (including, in particular, LNG liquefaction, storage, transportation or regasification operations), could generate public concern, which may lead to new laws and/or regulations that would impose more stringent requirements on our operations, have a corresponding impact on our ability to obtain permits and approvals, and otherwise jeopardize our reputation or the reputation of our industry as well as our relationships with relevant regulatory agencies and local communities. As the owner and operator of our facilities and owner or charterer of our vessels, we may be liable, without regard to fault or the lawfulness of the original conduct, for the release of certain types or quantities of hazardous substances into the environment at or from our facilities and for any resulting damage to natural resources, which could result in substantial liabilities, fines and penalties, capital expenditures related to cleanup efforts and pollution control equipment, and restrictions or curtailment of our operations. Any such liabilities, fines and penalties could exceed the limits of our insurance coverage. See “—Our insurance may be insufficient to cover losses that may occur to our property or result from our operations.” Individually or collectively, these developments could adversely impact our ability to expand our business, including into new markets.

Greenhouse Gases/Climate Change. The threat of climate change continues to attract considerable attention in the United States and around the world. Numerous proposals have been made and could continue to be made at the international, national, regional and state government levels to monitor and limit existing and future GHG emissions. As a result, our operations are subject to a series of risks associated with the processing, transportation, and use of fossil fuels and emission of GHGs. In the United States to date, no comprehensive climate change legislation has been implemented at the federal level, although various individual states and state coalitions have adopted or considered adopting legislation, regulations or other regulatory initiatives, including GHG cap and trade programs, carbon taxes, reporting and tracking programs, and emission restrictions, pollution reduction incentives, or renewable energy or low-carbon replacement fuel quotas. At the international level, the United Nations-sponsored “Paris Agreement” was signed by 197 countries who agreed to limit their GHG emissions through non-binding, individually-determined reduction goals every five years after 2020. The United States rejoined the Paris Agreement, effective February 19, 2021, and other countries where we operate or plan to operate, including Jamaica, Brazil, Ireland, Mexico, and Nicaragua, have signed or acceded to this agreement. However, the scope of future climate and GHG emissions-focused regulatory requirements, if any, remain uncertain. Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political uncertainty in the United States and worldwide. For example, based in part on the publicized climate plan and pledges by President Biden, there may be significant legislation, rulemaking, or executive orders that seek to address climate change, incentivize low-carbon infrastructure or initiatives, or ban or restrict the exploration and production of fossil fuels. For example, executive orders may be issued or federal legislation or regulatory initiatives may be adopted to achieve U.S. goals under the Paris Agreement.

Climate-related litigation and permitting risks are also increasing, as a number of cities, local governments and private organizations have sought to either bring suit against oil and natural gas companies in state or federal court, alleging various public nuisance claims, or seek to challenge permits required for infrastructure development. Fossil fuel producers are also facing general risks of shifting capital availability due to stockholder concern over climate change and potentially stranded assets in the event of future, comprehensive climate and GHG-related regulation. While several of these cases have been dismissed, there is no guarantee how future lawsuits might be resolved.

The adoption and implementation of new or more comprehensive international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent restrictions on GHG emissions could result in increased compliance costs, and thereby reduce demand for or erode value for, the natural gas that we process and market. The potential increase in our operating costs could include new costs to operate and maintain our facilities, install new emission controls on our facilities, acquire allowances to authorize our GHG emissions, pay taxes related to our GHG emissions, and administer and manage a GHG emissions program. We may not be able to recover such increased costs through increases in customer prices or rates. In addition, changes in regulatory policies that result in a reduction in the demand for hydrocarbon products that are deemed to contribute to GHGs, or restrict their use, may reduce volumes available to us for processing, transportation, marketing and storage. Furthermore, political, litigation, and financial risks may result in reduced natural gas production activities, increased liability for infrastructure damages as a result of climatic changes, or an

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impaired ability to continue to operate in an economic manner. One or more of these developments could have a material adverse effect on our business, financial condition and results of operation.

Fossil Fuels. Our business activities depend upon a sufficient and reliable supply of natural gas feedstock, and are therefore subject to concerns in certain sectors of the public about the exploration, production and transportation of natural gas and other fossil fuels and the consumption of fossil fuels more generally. For example, PHMSA has promulgated detailed regulations governing LNG facilities under its jurisdiction to address siting, design, construction, equipment, operations, maintenance, personnel qualifications and training, fire protection and security. While the Miami Facility is subject to these regulations, none of our LNG facilities currently under development are subject to PHMSA’s jurisdiction, but regulators and governmental agencies in the jurisdictions in which we operate can impose similar siting, design, construction and operational requirements that can affect our projects, facilities, infrastructure and operations. Legislative and regulatory action, and possible litigation, in response to such public concerns may also adversely affect our operations. We may be subject to future laws, regulations, or actions to address such public concern with fossil fuel generation, distribution and combustion, greenhouse gases and the effects of global climate change. Our customers may also move away from using fossil fuels such as LNG for their power generation needs for reputational or perceived risk-related reasons. These matters represent uncertainties in the operation and management of our business, and could have a material adverse effect on our financial position, results of operations and cash flows.

Hydraulic Fracturing. Certain of our suppliers of natural gas and LNG employ hydraulic fracturing techniques to stimulate natural gas production from unconventional geological formations (including shale formations), which currently entails the injection of pressurized fracturing fluids (consisting of water, sand and certain chemicals) into a well bore. Moreover, hydraulically fractured natural gas wells account for a significant percentage of the natural gas production in the U.S.; the U.S. Energy Information Administration reported in 2016 that hydraulically fractured wells provided two-thirds of U.S. marketed gas production in 2015. Hydraulic fracturing activities can be regulated at the national, federal or local levels, with governmental agencies asserting authority over certain hydraulic fracturing activities and equipment used in the production, transmission and distribution of oil and natural gas, including such oil and natural gas produced via hydraulic fracturing. Such authorities may seek to further regulate or even ban such activities. For example, the Delaware River Basin Commission (“DRBC”), a regional body created via interstate compact responsible for, among other things, water quality protection, water supply allocation, regulatory review, water conservation initiatives, and watershed planning in the Delaware River Basin, has implemented a de facto ban on hydraulic fracturing activities in that basin since 2010 pending the approval of new regulations governing natural gas production activity in the basin. More recently, the DRBC has stated that it will consider new regulations that would ban natural gas production activity, including hydraulic fracturing, in the basin. If additional levels of regulation or permitting requirements were imposed on hydraulic fracturing operations, natural gas prices in North America could rise, which in turn could materially adversely affect the relative pricing advantage that has existed in recent years in favor of domestic natural gas prices (based on Henry Hub pricing).

The requirements for permits or authorizations to conduct these activities vary depending on the location where such drilling and completion activities will be conducted. Several jurisdictions have adopted or considered adopting regulations to impose more stringent permitting, public disclosure or well construction requirements on hydraulic fracturing operations, or to ban hydraulic fracturing altogether. As with most permitting and authorization processes, there is a degree of uncertainty as to whether a permit will be granted, the time it will take for a permit or approval to be issued and any conditions which may be imposed in connection with the granting of the permit. See “—Failure to obtain and maintain permits, approvals and authorizations from governmental and regulatory agencies and third parties on favorable terms could impede operations and construction.” Certain regulatory authorities have delayed or suspended the issuance of permits or authorizations while the potential environmental impacts associated with issuing such permits can be studied and appropriate mitigation measures evaluated. In addition, some local jurisdictions have adopted or considered adopting land use restrictions, such as city or municipal ordinances, that may restrict the performance of or prohibit the well drilling in general and/or hydraulic fracturing in particular. Increased regulation or difficulty in permitting of hydraulic fracturing, and any corresponding increase in domestic natural gas prices, could materially adversely affect demand for LNG and our ability to develop commercially viable LNG facilities.

Indigenous Communities. Indigenous communities—including, in Brazil, Afro-indigenous (“Quilombola”) communities—are subject to certain protections under international and national laws. Brazil has ratified the International Labor Organization’s Indigenous and Tribal Peoples Convention (“ILO Convention 169”), which states that governments are to ensure that members of tribes directly affected by legislative or administrative measures, including the grant of government authorizations, such as are required for our Brazilian operations, are consulted through appropriate procedures and through their representative institutions, particularly using the principle of consultation and participation of indigenous and traditional communities under the basis of free, prior, and informed consent (“FPIC”). Brazilian law does not specifically regulate the FPIC process for indigenous and traditional people affected by undertakings, nor does it set forth that individual members of an affected community shall render their FPIC on an undertaking that may impact them. However, in order to obtain certain environmental licenses for our operations, we are required to comply with the

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requirements of, consult with, and obtain certain authorizations from a number of institutions regarding the protection of indigenous interests: IBAMA, local environmental authorities in the localities in which we operate, the Federal Public Prosecutor’s Office and the National Indian Foundation (Fundação Nacional do Índio or “FUNAI”) (for indigenous people) or Palmares Cultural Foundation (Fundação Cultural Palmares) (for Quilombola communities).

Additionally, the American Convention on Human Rights (“ACHR”), to which Brazil is a party, sets forth rights and freedoms prescribed for all persons, including property rights without discrimination due to race, language, and national or social origin. The ACHR also provides for consultation with indigenous communities regarding activities that may affect the integrity of their land and natural resources. If Brazil’s legal process for consultation and the protection of indigenous rights is challenged under the ACHR and found to be inadequate, it could result in orders or judgments that could ultimately adversely impact its operations. For example, in February 2020, the Interamerican Court of Human Rights (“IACtHR”) found that Argentina had not taken adequate steps, in law or action, to ensure the consulting of indigenous communities and obtaining those communities’ free prior and informed consent for a project impacting their territories. IACtHR further found that Argentina had thus violated the ACHR due to infringements on the indigenous communities’ rights to property, cultural identity, a healthy environment, and adequate food and water by failing to take effective measures to stop harmful, third-party activities on the indigenous communities’ traditional land. As a result, IACtHR ordered Argentina, among other things, to achieve the demarcation and grant of title to the indigenous communities over their territory and the removal of third parties from the indigenous territory. We cannot predict whether this decision will result in challenges regarding the adequacy of existing Brazilian legal requirements related to the protection of indigenous rights, changes to the existing Brazilian government body consultation process, or impact our existing development agreements or negotiations for outstanding development agreements with indigenous communities in the areas in which we operate.

There are several indigenous communities that surround our operations in Brazil. Certain of our subsidiaries have entered into agreements with some of these communities that mainly provide for the use of their land for our operations, provide compensation for any potential adverse impact that our operations may indirectly cause to them, and negotiations with other such communities are ongoing. If we are not able to timely obtain the necessary authorizations or obtain them on favorable terms for our operations in areas where indigenous communities reside, our relationship with these communities deteriorates in future, or that such communities do not comply with any existing agreements related to our operations, we could face construction delays, increased costs, or otherwise experience adverse impacts on its business and results of operations.

Offshore operations. Our operations in international waters and in the territorial waters of other countries are regulated by extensive and changing international, national and local environmental protection laws, regulations, treaties and conventions in force in international waters, the jurisdictional waters of the countries in which we operate, as well as the countries of our vessels’ registration, including those governing oil spills, discharges to air and water, the handling and disposal of hazardous substances and wastes and the management of ballast water. The International Maritime Organization (“IMO”) International Convention for the Prevention of Pollution from Ships of 1973, as amended from time to time, and generally referred to as “MARPOL,” can affect operations of our chartered vessels. In addition, our chartered LNG vessels may become subject to the International Convention on Liability and Compensation for Damage in Connection with the Carriage of Hazardous and Noxious Substances by Sea (the “HNS Convention”), adopted in 1996 and subsequently amended by a Protocol to the HNS Convention in April 2010. Other regulations include, but are not limited to, the designation of Emission Control Areas under MARPOL, the IMO International Convention on Civil Liability for Oil Pollution Damage of 1969, as amended from time to time, the International Convention on Civil Liability for Bunker Oil Pollution Damage, the IMO International Convention for the Safety of Life at Sea of 1974, as amended from time to time, the International Safety Management Code for the Safe Operations of Ships and for Pollution Prevention, the IMO International Convention on Load Lines of 1966, as amended from time to time and the International Convention for the Control and Management of Ships’ Ballast Water and Sediments in February 2004.

In particular, development of offshore operations of natural gas and LNG are subject to extensive environmental, industry, maritime and social regulations. For example, any development and future operation of the potential Lakach project, which would be developed as a deepwater natural gas field in Mexico, as well as the development of a new FLNG hub off the coast of Altamira, State of Tamaulipas, would be subject to regulation by Mexico’s Ministry of Energy (Secretaría de Energía) (“SENER”), Mexico's National Hydrocarbon Commission (“CNH”), the National Agency of Industrial Safety and Environmental Protection of the Hydrocarbons Sector (“ASEA”), among other relevant Mexican regulatory bodies. The laws and regulations governing activities in the Mexican energy sector have undergone significant reformation over the past decade, and the legal regulatory framework continues to evolve as SENER, the CNH and other Mexican regulatory bodies issue new regulations and guidelines as the industry develops. Such regulations are subject to change, so it is possible that SENER, the CNH or other Mexican regulatory bodies may impose new or revised requirements that could increase our operating costs and/or capital expenditures for operations in Mexican offshore waters. In addition, our operations in waters off the coast of Mexico are subject to regulation by ASEA. The laws and regulations governing the protection of health, safety and the environment from activities in the Mexican energy sector are also

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relatively new, having been significantly reformed in 2013 and 2014, and the legal regulatory framework continues to evolve as ASEA and other Mexican regulatory bodies issue new regulations and guidelines as the industry modernizes and adapts to market changes. Such regulations are subject to change, and it is possible that ASEA or other Mexican regulatory bodies may impose new or revised requirements that could increase our operating costs and/or capital expenditures for operations in Mexican offshore waters.

Moreover, the overall trends are towards more regulations and more stringent requirements which are likely to add to our costs of doing business. For example, IMO regulations, which became applicable on January 1, 2020, limit the sulfur content of fuel oil for ships to 0.5 weight percent starting , thus increasing the cost of fuel and increasing expenses for us. Likewise, the European Union is considering extending its emissions trading scheme to maritime transport to reduce GHG emissions from vessels. We contract with industry leading vessel providers in the LNG market and look for them to take the lead in maintaining compliance with all such requirements, although the terms of our charter agreements may call for us to bear some or all of the associated costs. While we believe we are similarly situated with respect to other companies that charter vessels, we cannot assure you that these requirements will not have a material effect on our business.

Our chartered vessels operating in U.S. waters, now or in the future, will also be subject to various federal, state and local laws and regulations relating to protection of the environment, including the OPA, the CERCLA, the CWA and the CAA. In some cases, these laws and regulations require governmental permits and authorizations before conducting certain activities. These environmental laws and regulations may impose substantial penalties for noncompliance and substantial liabilities for pollution. Failure to comply with these laws and regulations may result in substantial civil and criminal fines and penalties. As with the industry generally, our chartered vessels’ operations will entail risks in these areas, and compliance with these laws and regulations, which may be subject to frequent revisions and reinterpretation, may increase our overall cost of business.

We are subject to numerous governmental export laws, and trade and economic sanctions laws and regulations, and anti-corruption laws and regulation.

We conduct business throughout the world, and our business activities and services are subject to various applicable import and export control laws and regulations of the United States and other countries, particularly countries in the Caribbean, Latin America, Europe and the other countries in which we seek to do business. We must also comply with trade and economic sanctions laws, including the U.S. Commerce Department’s Export Administration Regulations and economic and trade sanctions regulations maintained by the U.S. Treasury Department’s Office of Foreign Assets Control. For example, in 2018, U.S. legislation was approved to restrict U.S. aid to Nicaragua and between 2018 and 2022, U.S. and European governmental authorities imposed a number of sanctions against entities and individuals in or associated with the governments of Nicaragua and Venezuela. Following the invasion of Ukraine by Russia in 2022, U.S. and European governmental authorities imposed a number of sanctions against entities and individuals in Russia or connected to Russia, including sanctions specifically targeting the Russian oil and gas industry. Although we take precautions to comply with all such laws and regulations, violations of governmental export control and economic sanctions laws and regulations could result in negative consequences to us, including government investigations, sanctions, criminal or civil fines or penalties, more onerous compliance requirements, loss of authorizations needed to conduct aspects of our international business, reputational harm and other adverse consequences. Moreover, it is possible that we could invest both time and capital into a project involving a counterparty who may become subject to sanctions. If any of our counterparties becomes subject to sanctions as a result of these laws and regulations, changes thereto or otherwise, we may face an array of issues, including, but not limited to, (i) having to suspend our development or operations on a temporary or permanent basis, (ii) being unable to recuperate prior invested time and capital or being subject to lawsuits, or (iii) investigations or regulatory proceedings that could be time-consuming and expensive to respond to and which could lead to criminal or civil fines or penalties.

We are also subject to anti-corruption laws and regulations, including the U.S. Foreign Corrupt Practices Act (“FCPA”), which generally prohibit companies and their intermediaries from making improper payments to foreign officials for the purpose of obtaining or keeping business and/or other benefits. Some of the jurisdictions in which we currently, or may in the future, operate may present heightened risks for FCPA issues, such as Nicaragua, Jamaica, Brazil and Mexico or other countries in Latin America, Asia and Africa. Although we have adopted policies and procedures that are designed to ensure that we, our employees and other intermediaries comply with the FCPA, it is highly challenging to adopt policies and procedures that ensure compliance in all respects with the FCPA, particularly in high-risk jurisdictions. Developing and implementing policies and procedures is a complex endeavor. There is no assurance that these policies and procedures will work effectively all of the time or protect us against liability under anti-corruption laws and regulations, including the FCPA, for actions taken by our employees and other intermediaries with respect to our business or any businesses that we may acquire.

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If we are not in compliance with trade and economic sanctions laws and anti-corruption laws and regulations, including the FCPA, we may be subject to costly and intrusive criminal and civil investigations as well as significant potential criminal and civil penalties and other remedial measures, including changes or enhancements to our procedures, policies and controls, the imposition of an independent compliance monitor, as well as potential personnel changes and disciplinary actions. In addition, non-compliance with such laws could constitute a breach of certain covenants in operational or debt agreements, and cross-default provisions in certain of our agreements could mean that an event of default under certain of our commercial agreements could trigger an event of default under our other agreements, including our debt agreements. Any adverse finding against us could also negatively affect our relationship and reputation with current and potential customers. In addition, in certain countries we serve or expect to serve our customers through third-party agents and other intermediaries. Violations of applicable import, export, trade and economic sanctions, and anti-corruption laws and regulations by these third-party agents or intermediaries may also result in adverse consequences and repercussions to us. There can be no assurance that we and our agents and other intermediaries will be in compliance with these provisions in the future. The occurrence of any of these events could have a material adverse impact on our business, results of operations, financial condition, liquidity and future business prospects. The U.S. sanctions and embargo laws and regulations vary in their application, as they do not all apply to the same covered persons or proscribe the same activities, and such sanctions and embargo laws and regulations may be amended or strengthened over time.

Although we believe that we have been in compliance with all applicable sanctions, embargo and anti-corruption laws and regulations, and intend to maintain such compliance, there can be no assurance that we will be in compliance in the future, particularly as the scope of certain laws may be unclear and may be subject to changing interpretations. Any such violation could result in fines, penalties or other sanctions that could severely impact our ability to access U.S. capital markets and conduct our business. In addition, certain financial institutions may have policies against lending or extending credit to companies that have contracts with U.S. embargoed countries or countries identified by the U.S. government as state sponsors of terrorism, which could adversely affect our ability to access funding and liquidity, our financial condition and prospects.

Our charterers may inadvertently violate applicable sanctions and/or call on ports located in, or engage in transactions with, countries that are subject to restrictions imposed by the U.S. or other governments, which could adversely affect its business.

None of our vessels have called on ports located in countries subject to comprehensive sanctions and embargoes imposed by the U.S. government or countries identified by the U.S. government as state sponsors of terrorism. When we charter our vessels to third parties we conduct comprehensive due diligence of the charterer and include prohibitions on the charterer calling on ports in countries subject to comprehensive U.S. sanctions or otherwise engaging in commerce with such countries. However, our vessels may be sub-chartered out to a sanctioned party or call on ports of a sanctioned nation on charterers’ instruction, and without our knowledge or consent. If our charterers or sub-charterers violate applicable sanctions and embargo laws and regulations as a result of actions that do not involve us, those violations could in turn negatively affect our reputation and cause us to incur significant costs associated with responding to any investigation into such violations.

Increasing transportation regulations may increase our costs and negatively impact our results of operations.

We are developing a transportation system specifically dedicated to transporting LNG using ISO tank containers and trucks to our customers and facilities. This transportation system may include trucks that we or our affiliates own and operate. Any such operations would be subject to various trucking safety regulations in the various countries where we operate, including those which are enacted, reviewed and amended by the Federal Motor Carrier Safety Administration (“FMCSA”). These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations, driver licensing, insurance requirements, and transportation of hazardous materials. To a large degree, intrastate motor carrier operations are subject to state and/or local safety regulations that mirror federal regulations but also regulate the weight and size dimensions of loads. Any trucking operations would be subject to possible regulatory and legislative changes that may increase our costs. Some of these possible changes include changes in environmental regulations, changes in the hours of service regulations which govern the amount of time a driver may drive or work in any specific period, onboard black box recorder device requirements or limits on vehicle weight and size. In addition to increased costs, fines and penalties, any non-compliance or violation of these regulations, could result in the suspension of our operations, which could have a material adverse effect on our business and consolidated results of operations and financial position.

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Our chartered vessels operating in certain jurisdictions, including the United States, now or in the future, may be subject to cabotage laws, including the Merchant Marine Act of 1920, as amended (the “Jones Act”).

Certain activities related to our logistics and shipping operations may constitute “coastwise trade” within the meaning of laws and regulations of the U.S. and other jurisdictions in which we operate. Under these laws and regulations, often referred to as cabotage laws, including the Jones Act in the U.S., only vessels meeting specific national ownership and registration requirements or which are subject to an exception or exemption, may engage in such “coastwise trade.” When we operate or charter foreign-flagged vessels, we do so within the current interpretation of such cabotage laws with respect to permitted activities for foreign-flagged vessels. Significant changes in cabotage laws or to the interpretation of such laws in the places where we operate could affect our ability to operate or charter, or competitively operate or charter, our foreign-flagged vessels in those waters. If we do not continue to comply with such laws and regulations, we could incur severe penalties, such as fines or forfeiture of any vessels or their cargo, and any noncompliance or allegations of noncompliance could disrupt our operations in the relevant jurisdiction. Any noncompliance or alleged noncompliance could have a material adverse effect on our reputation, our business, our results of operations and cash flows, and could weaken our financial condition.

We do not own the land on which our projects are located and are subject to leases, rights-of-ways, easements and other property rights for our operations.

We have obtained long-term leases and corresponding rights-of-way agreements and easements with respect to the land on which various of our projects are located, including the Jamaica Facilities, the pipeline connecting the Montego Bay Facility to the Bogue Power Plant (as defined herein), the Miami Facility, the San Juan Facility and the CHP Plant are situated, facilities in Brazil such as the Garuva-Itapoa pipeline connecting the TBG pipeline to the Sao Francisco do Sul terminal, rights of way to the Petrobras/Transpetro OSPAR oil pipeline facilities, among others. In addition, our operations will require agreements with ports proximate to our facilities capable of handling the transload of LNG direct from our occupying vessel to our transportation assets. We do not own the land on which these facilities are located. As a result, we are subject to the possibility of increased costs to retain necessary land use rights as well as applicable law and regulations, including permits and authorizations from governmental agencies or third parties. If we were to lose these rights or be required to relocate, we would not be able to continue our operations at those sites and our business could be materially and adversely affected. For example, our ability to operate the CHP Plant is dependent on our ability to enforce the related lease. General Alumina Jamaica Limited (“GAJ”), one of the lessors, is a subsidiary of Noble Group, which completed a financial restructuring in 2018. If GAJ is involved in a bankruptcy or similar proceeding, such proceeding could negatively impact our ability to enforce the lease. If we are unable to enforce the lease due to the bankruptcy of GAJ or for any other reason, we could be unable to operate the CHP Plant or to execute on our contracts related thereto. If we are unable to enter into favorable contracts or to obtain the necessary regulatory and land use approvals on favorable terms, we may not be able to construct and operate our assets as anticipated, or at all, which could negatively affect our business, results of operations and financial condition.

We could be negatively impacted by environmental, social, and governance (“ESG”) and sustainability-related matters.

Governments, investors, customers, employees and other stakeholders are increasingly focusing on corporate ESG practices and disclosures, and expectations in this area are rapidly evolving. We have announced, and may in the future announce, sustainability-focused goals, initiatives, investments and partnerships. These initiatives, aspirations, targets or objectives reflect our current plans and aspirations and are not guarantees that we will be able to achieve them. Our efforts to accomplish and accurately report on these initiatives and goals present numerous operational, regulatory, reputational, financial, legal, and other risks, any of which could have a material negative impact, including on our reputation and stock price.

In addition, the standards for tracking and reporting on ESG matters are relatively new, have not been harmonized and continue to evolve. Our selection of disclosure frameworks that seek to align with various voluntary reporting standards may change from time to time and may result in a lack of comparative data from period to period. Moreover, our processes and controls may not always align with evolving voluntary standards for identifying, measuring, and reporting ESG metrics, our interpretation of reporting standards may differ from those of others, and such standards may change over time, any of which could result in significant revisions to our goals or reported progress in achieving such goals. In this regard, the criteria by which our ESG practices and disclosures are assessed may change due to the quickly evolving landscape, which could result in greater expectations of us and cause us to undertake costly initiatives to satisfy such new criteria. The increasing attention to corporate ESG initiatives could also result in increased investigations and litigation or threats thereof. If we are unable to satisfy such new criteria, investors may conclude that our ESG and sustainability practices are inadequate. If we fail or are perceived to have failed to achieve previously announced initiatives or goals or to accurately disclose our progress on such initiatives or goals, our reputation, business, financial condition and results of operations could be adversely impacted.

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Information technology failures and cyberattacks could affect us significantly.

We rely on electronic systems and networks to communicate, control and manage our operations and prepare our financial management and reporting information. If we record inaccurate data or experience infrastructure outages, our ability to communicate and control and manage our business could be adversely affected. We face various security threats, including cybersecurity threats from third parties and unauthorized users to gain unauthorized access to sensitive information or to render data or systems unusable, threats to the security of our facilities, liquefaction facilities, and infrastructure or third-party facilities and infrastructure, such as processing plants and pipelines, and threats from terrorist acts. Our network systems and storage and other business applications, and the systems and storage and other business applications maintained by our third-party providers, have been in the past, and may be in the future, subjected to attempts to gain unauthorized access to our network or information, malfeasance or other system disruptions.

Our implementation of various procedures and controls to monitor and mitigate security threats and to increase security for our information, facilities, liquefaction facilities, and infrastructure may result in increased capital and operating costs. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security breaches from occurring. If security breaches were to occur, they could lead to losses of sensitive information, critical infrastructure or capabilities essential to our operations. If we were to experience an attack and our security measures failed, the potential consequences to our business and the communities in which we operate could be significant and could harm our reputation and lead to financial losses from remedial actions, loss of business or potential liability.

Our insurance may be insufficient to cover losses that may occur to our property or result from our operations.

Our current operations and future projects are subject to the inherent risks associated with construction of energy-related infrastructure, LNG, natural gas, power and maritime operations, shipping and transportation of hazardous substances, including explosions, pollution, release of toxic substances, fires, seismic events, hurricanes and other adverse weather conditions, acts of aggression or terrorism, and other risks or hazards, each of which could result in significant delays in commencement or interruptions of operations and/or result in damage to or destruction of the facilities, liquefaction facilities and assets or damage to persons and property. We do not, nor do we intend to, maintain insurance against all of these risks and losses. In particular, we do not generally carry business interruption insurance or political risk insurance with respect to political disruption in the countries in which we operate and that may in the future experience significant political volatility. Therefore, the occurrence of one or more significant events not fully insured or indemnified against could create significant liabilities and losses or delays to our development timelines, which could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects. Even if we choose to carry insurance for these events in the future, it may not be adequate to protect us from loss, which may include, for example, losses as a result of project delays or losses as a result of business interruption related to a political disruption. Any attempt to recover from loss from political disruption may be time-consuming and expensive, and the outcome may be uncertain. In addition, our insurance may be voidable by the insurers as a result of certain of our actions. Furthermore, we may be unable to procure adequate insurance coverage at commercially reasonable rates in the future. For example, environmental regulations have led in the past to increased costs for, and in the future may result in the lack of availability of, insurance against risks of environmental damage or pollution. Changes in the insurance markets attributable to terrorist attacks or political change may also make certain types of insurance more difficult or costly for us to obtain.

Our success depends on key members of our management, the loss of any of whom could disrupt our business operations.

We depend to a large extent on the services of our chief executive officer, Wesley R. Edens, some of our other executive officers and other key employees. Mr. Edens does not have an employment agreement with us. The loss of the services of Mr. Edens or one or more of our other key executives or employees could disrupt our operations and increase our exposure to the other risks described in this Item 1A. Risk Factors. We do not maintain key man insurance on Mr. Edens or any of our employees. As a result, we are not insured against any losses resulting from the death of our key employees.

We may experience increased labor costs and regulation, and the unavailability of skilled workers or our failure to attract and retain qualified personnel, as well as our ability to comply with such labor laws, could adversely affect us.

We are dependent upon the available labor pool of skilled employees for the construction and operation of our facilities and liquefaction facilities, as well as our FSRUs, FLNGs and LNG carriers. We compete with other energy companies and other employers to attract and retain qualified personnel with the technical skills and experience required to construct and operate our infrastructure and assets and to provide our customers with the highest quality service. In addition, the tightening of the labor market due to the shortage of skilled employees may affect our ability to hire and retain

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skilled employees, impair our operations and require us to pay increased wages. We are subject to labor laws in the jurisdictions in which we operate and hire our personnel, which can govern such matters as minimum wage, overtime, union relations, local content requirements and other working conditions. For example, Brazil and Indonesia, where some of our vessels operate, require we hire a certain portion of local personnel to crew our vessels. Any inability to attract and retain qualified local crew members could adversely affect our operations, business, results of operations and financial condition. Furthermore, should there be an outbreak of COVID-19 on our facilities or vessels, adequate staffing or crewing may not be available to fulfill the obligations under our contracts. Due to COVID-19, we could face (i) difficulty in finding healthy qualified replacement employees; (ii) local or international transport or quarantine restrictions limiting the ability to transfer infected employees from or to our facilities or vessels, and (iii) restrictions in availability of supplies needed for our projects due to disruptions to third-party suppliers or transportation alternatives. See “—General Risks—We are unable to predict the extent to which the global COVID-19 pandemic will negatively affect our operations, financial performance, nor our ability to achieve our strategic objectives. We are also unable to predict how this global pandemic may affect our customers and suppliers.” A shortage in the labor pool of skilled workers or other general inflationary pressures or changes in applicable laws and regulations, could make it more difficult for us to attract and retain qualified personnel and could require an increase in the wage and benefits packages that we offer, thereby increasing our operating costs. Any increase in our operating costs could materially and adversely affect our business, financial condition, operating results, liquidity and prospects.

Our business could be affected adversely by labor disputes, strikes or work stoppages.

Some of our employees, particularly those in our Latin American operations, are represented by a labor union and are covered by collective bargaining agreements pursuant to applicable labor legislation. As a result, we are subject to the risk of labor disputes, strikes, work stoppages and other labor-relations matters. We could experience a disruption of our operations or higher ongoing labor costs, which could have a material adverse effect on our operating results and financial condition. Future negotiations with the unions or other certified bargaining representatives could divert management attention and disrupt operations, which may result in increased operating expenses and lower net income. Moreover, future agreements with unionized and non-unionized employees may be on terms that are not as attractive as our current agreements or comparable to agreements entered into by our competitors. Labor unions could also seek to organize some or all of our non-unionized workforce.

Risks Related to the Jurisdictions in Which We Operate

We are subject to the economic, political, social and other conditions in the jurisdictions in which we operate.

Our projects are located in Jamaica and the United States (including Puerto Rico), the Caribbean, Brazil, Mexico, Ireland, Nicaragua and other geographies and we have operations and derive revenues from additional markets. Furthermore, part of our strategy consists in seeking to expand our operations to other jurisdictions. As a result, our projects, operations, business, results of operations, financial condition and prospects are materially dependent upon economic, political, social and other conditions and developments in these jurisdictions. Some of these countries have experienced political, security, and social economic instability in the recent past and may experience instability in the future, including changes, sometimes frequent or marked, in energy policies or the personnel administering them, expropriation of property, cancellation or modification of contract rights, changes in laws and policies governing operations of foreign-based companies, unilateral renegotiation of contracts by governmental entities, redefinition of international boundaries or boundary disputes, foreign exchange restrictions or controls, currency fluctuations, royalty and tax increases and other risks arising out of governmental sovereignty over the areas in which our operations are conducted, as well as risks of loss due to acts of social unrest, terrorism, corruption and bribery. For example, in 2019, public demonstrations in Puerto Rico led to the governor’s resignation and the resulting political change interrupted the bidding process for the privatization of PREPA’s transmission and distribution systems. While our operations to date have not been materially impacted by the demonstrations or political changes in Puerto Rico, any substantial disruption in our ability to perform our obligations under any agreements with PREPA could have a material adverse effect on our financial condition, results of operations and cash flows. Furthermore, we cannot predict how our relationship with PREPA could change given PREPA’s privatization of its transmission, distribution and power generation system. PREPA may seek to find alternative power sources or purchase substantially less natural gas from us than what we currently expect to sell to PREPA. In addition, we cannot predict how local sentiment and support for our subsidiaries’ operations in Puerto Rico could change following the privatization of Puerto Rico’s power generation systems. Should our operations face material local opposition, it could materially adversely affect our ability to perform our obligations under our contracts or could materially adversely impact PREPA or any applicable governmental counterparty’s performance of its obligations to us. The governments in these jurisdictions differ widely with respect to structure, constitution and stability and some countries lack mature legal and regulatory systems. As our operations depend on governmental approval and regulatory decisions, we may be adversely affected by changes in the political structure or government representatives in each of the countries in

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which we operate. In addition, these jurisdictions, particularly emerging countries, are subject to risk of contagion from the economic, political and social developments in other emerging countries and markets.

Furthermore, some of the regions in which we operate have been subject to significant levels of terrorist activity and social unrest, particularly in the shipping and maritime industries. Past political conflicts in certain of these regions have included attacks on vessels, mining of waterways and other efforts to disrupt shipping in the area. In addition to acts of terrorism, vessels trading in these and other regions have also been subject, in limited instances, to piracy. Tariffs, trade embargoes and other economic sanctions by the United States or other countries against countries in the Middle East, Southeast Asia, Africa or elsewhere as a result of terrorist attacks, hostilities or otherwise may limit trading activities with those countries. See “—Our Charterers may inadvertently violate applicable sanctions and/or call on ports located in, or engage in transactions with, countries that are subject to restrictions imposed by the U.S. or other governments, which could adversely affect its business.” We do not, nor do we intend to, maintain insurance (such as business interruption insurance or terrorism) against all of these risks and losses. Any claims covered by insurance will be subject to deductibles, which may be significant, and we may not be fully reimbursed for all the costs related to any losses created by such risks. See “—Our insurance may be insufficient to cover losses that may occur to our property or result from our operations.” As a result, the occurrence of any economic, political, social and other instability or adverse conditions or developments in the jurisdictions in which we operate, could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Our financial condition and operating results may be adversely affected by foreign exchange fluctuations.

While our condensed consolidated financial statements are presented in U.S. dollars, we generate revenues and incur operating expenses and indebtedness in local currencies in the countries where we operate, such as, among others, the euro, the Mexican peso and the Brazilian real. The amount of our revenues denominated in a particular currency in a particular country typically varies from the amount of expenses or indebtedness incurred by our operations in that country given that certain costs may be incurred in a currency different from the local currency of that country, such as the U.S. dollar. Therefore, fluctuations in exchange rates used to translate other currencies into U.S. dollars could result in potential losses and reductions in our margins resulting from currency fluctuations, which may impact our reported consolidated financial condition, results of operations and cash flows from period to period. These fluctuations in exchange rates will also impact the value of our investments and the return on our investments. Additionally, some of the jurisdictions in which we operate may limit our ability to exchange local currency for U.S. dollars and elect to intervene by implementing exchange rate regimes, including sudden devaluations, periodic mini devaluations, exchange controls, dual exchange rate markets and a floating exchange rate system. There can be no assurance that non-U.S. currencies will not be subject to volatility and depreciation or that the current exchange rate policies affecting these currencies will remain the same. For example, the Mexican peso and the Brazilian real have experienced significant fluctuations relative to the U.S. dollar in the past. We may choose not to hedge, or we may not be effective in efforts to hedge, this foreign currency risk. See “—Risks Related to our Business—Any use of hedging arrangements may adversely affect our future operating results or liquidity.” Depreciation or volatility of these currencies against the U.S. dollar could cause counterparties to be unable to pay their contractual obligations under our agreements or to lose confidence in us and may cause our expenses to increase from time to time relative to our revenues as a result of fluctuations in exchange rates, which could affect the amount of net income that we report in future periods.

Risks Related to Ownership of Our Class A Common Stock

The market price and trading volume of our Class A common stock may be volatile, which could result in rapid and substantial losses for our stockholders.

The market price of our Class A common stock may be highly volatile and could be subject to wide fluctuations. In addition, the trading volume in our Class A common stock may fluctuate and cause significant price variations to occur. If the market price of our Class A common stock declines significantly, you may be unable to resell your shares at or above your purchase price, if at all. The market price of our Class A common stock may fluctuate or decline significantly in the future. Some of the factors that could negatively affect our share price or result in fluctuations in the price or trading volume of our Class A common stock include:

•a shift in our investor base;

•our quarterly or annual earnings, or those of other comparable companies;

•actual or anticipated fluctuations in our operating results;

•changes in accounting standards, policies, guidance, interpretations or principles;

•announcements by us or our competitors of significant investments, acquisitions or dispositions;

•the failure of securities analysts to cover our Class A common stock;

•changes in earnings estimates by securities analysts or our ability to meet those estimates;

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•the operating and share price performance of other comparable companies;

•overall market fluctuations;

•general economic conditions; and

•developments in the markets and market sectors in which we participate.

Stock markets in the United States have experienced extreme price and volume fluctuations. Market fluctuations, as well as general political and economic conditions such as acts of terrorism, prolonged economic uncertainty, a recession or interest rate or currency rate fluctuations, could adversely affect the market price of our Class A common stock.

We are a “controlled company” within the meaning of Nasdaq rules and, as a result, qualify for and intend to rely on exemptions from certain corporate governance requirements.

Affiliates of certain entities controlled by Wesley R. Edens, Randal A. Nardone and affiliates of Fortress Investment Group LLC (“Founder Entities”), together with affiliates of Energy Transition Holdings LLC, hold a majority of the voting power of our stock. In addition, pursuant to the Shareholders’ Agreement, dated as of February 4, 2019, by and among the Company and the respective parties thereto (the “Shareholders’ Agreement”), the Founder Entities currently have the right to nominate a majority of the members of our Board of Directors. Furthermore, the Shareholders’ Agreement provides that the parties thereto will use their respective reasonable efforts (including voting or causing to be voted all of the Company’s voting shares beneficially owned by each) to cause to be elected to the Board, and to cause to continue to be in office the director nominees selected by the Founder Entities. Affiliates of Energy Transition Holdings LLC are parties to the Shareholders’ Agreement and as of September 30, 2023 hold approximately 12.5% of the voting power of our stock. As a result, we are a controlled company within the meaning of the Nasdaq corporate governance standards. Under Nasdaq rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, a group or another company is a controlled company and may elect not to comply with certain Nasdaq corporate governance requirements, including the requirements that:

•a majority of the board of directors consist of independent directors as defined under the rules of Nasdaq;

•the nominating and governance committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities; and

•the compensation committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities.

These requirements will not apply to us as long as we remain a controlled company. A controlled company does not need its board of directors to have a majority of independent directors or to form independent compensation and nominating and governance committees. We intend to utilize some or all of these exemptions. Accordingly, our corporate governance may not afford the same protections as companies that are subject to all of the corporate governance requirements of Nasdaq.

A small number of our original investors have the ability to direct the voting of a majority of our stock, and their interests may conflict with those of our other stockholders.

As of September 30, 2023, affiliates of the Founder Entities own an aggregate of approximately 87,136,768 shares of Class A common stock, representing approximately 42.5% of our voting power, and affiliates of Energy Transition Holdings LLC, party to the Shareholders' Agreement, own an aggregate of approximately 25,559,846 shares of our Class A common stock, representing approximately 12.5% of the voting power of our Class A common stock. The beneficial ownership of greater than 50% of our voting stock means affiliates of the Founder Entities and Energy Transition Holdings LLC are able to control matters requiring stockholder approval, including the election of directors, changes to our organizational documents and significant corporate transactions. This concentration of ownership makes it unlikely that any other holder or group of holders of our Class A common stock will be able to affect the way we are managed or the direction of our business. The interests of these parties with respect to matters potentially or actually involving or affecting us, such as future acquisitions, financings and other corporate opportunities and attempts to acquire us, may conflict with the interests of our other stockholders, including holders of the Class A common stock.

Given this concentrated ownership, the affiliates of the Founder Entities and Energy Transition Holdings LLC would have to approve any potential acquisition of us. The existence of a significant stockholder may have the effect of deterring hostile takeovers, delaying or preventing changes in control or changes in management, or limiting the ability of our other stockholders to approve transactions that they may deem to be in the best interests of our company. Moreover, the concentration of stock ownership with affiliates of the Founder Entities and Energy Transition Holdings LLC may adversely affect the trading price of our securities, including our Class A common stock, to the extent investors perceive a disadvantage in owning securities of a company with a significant stockholder.

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Furthermore, New Fortress Energy Holdings has assigned, pursuant to the terms of the Shareholders’ Agreement, to the Founder Entities, New Fortress Energy Holdings’ right to designate a certain number of individuals to be nominated for election to our board of directors so long as its assignees collectively beneficially own at least 5% of the outstanding Class A common stock. The Shareholders’ Agreement provides that the parties to the Shareholders’ Agreement (including certain former members of New Fortress Energy Holdings) shall vote their stock in favor of such nominees. In addition, our Certificate of Incorporation provides the Founder Entities the right to approve certain material transactions so long as the Founder Entities and their affiliates collectively, directly or indirectly, own at least 30% of the outstanding Class A common stock.

Our Certificate of Incorporation and By-Laws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our Class A common stock and could deprive our investors of the opportunity to receive a premium for their Class A common stock.

Our Certificate of Incorporation and By-Laws authorize our board of directors to issue preferred stock without stockholder approval in one or more series, designate the number of stock constituting any series, and fix the rights, preferences, privileges and restrictions thereof, including dividend rights, voting rights, rights and terms of redemption, redemption price or prices and liquidation preferences of such series. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our Certificate of Incorporation and By-Laws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our securityholders. These provisions include:

•dividing our board of directors into three classes of directors, with each class serving staggered three-year terms;

•providing that any vacancies may, except as otherwise required by law, or, if applicable, the rights of holders of a series of preferred stock, only be filled by the affirmative vote of a majority of directors then in office, even if less than a quorum (provided that vacancies that results from newly created directors requires a quorum);

•permitting special meetings of our stockholders to be called only by (i) the chairman of our board of directors, (ii) a majority of our board of directors, or (iii) a committee of our board of directors that has been duly designated by the board of directors and whose powers include the authority to call such meetings;

•prohibiting cumulative voting in the election of directors;

•establishing advance notice provisions for stockholder proposals and nominations for elections to the board of directors to be acted upon at meetings of the stockholders; and

•providing that the board of directors is expressly authorized to adopt, or to alter or repeal certain provisions of our organizational documents to the extent permitted by law.

Additionally, our Certificate of Incorporation provides that we have opted out of Section 203 of the Delaware General Corporation Law. However, our Certificate of Incorporation includes a similar provision, which, subject to certain exceptions, prohibits us from engaging in a business combination with an “interested stockholder,” unless the business combination is approved in a prescribed manner. Subject to certain exceptions, an “interested stockholder” means any person who, together with that person’s affiliates and associates, owns 15% or more of our outstanding voting stock or an affiliate or associate of ours who owned 15% or more of our outstanding voting stock at any time within the previous three years, but shall not include any person who acquired such stock from the Founder Entities or Energy Transition Holdings LLC (except in the context of a public offering) or any person whose ownership of stock in excess of 15% of our outstanding voting stock is the result of any action taken solely by us. Our Certificate of Incorporation provides that the Founder Entities and Energy Transition Holdings LLC and any of their respective direct or indirect transferees, and any group as to which such persons are a party, do not constitute “interested stockholders” for purposes of this provision.

Our By-Laws designate the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, which could limit our stockholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

Our By-Laws provide that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware is, to the fullest extent permitted by applicable law, the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our stockholders, (iii) any action asserting a claim against us or any of our directors, officers or employees arising pursuant to any provision of our organizational documents or the Delaware General Corporation Law, or (iv) any action asserting a claim against us or any of our directors, officers or employees that is governed by the internal affairs doctrine, in each such case subject to such Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. Any person or entity purchasing or otherwise acquiring any interest in our stock will be deemed to have notice of, and consented to, the provisions described in the preceding sentence. This choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that it considers more likely to be favorable for disputes with us or our directors, officers, employees or agents,

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which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our organizational documents inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition, results of operations or prospects.

The declaration and payment of dividends to holders of our Class A common stock is at the discretion of our board of directors and there can be no assurance that we will continue to pay dividends in amounts or on a basis consistent with prior distributions to our investors, if at all.

The declaration and payment of dividends to holders of our Class A common stock will be at the discretion of our board of directors in accordance with applicable law after taking into account various factors, including actual results of operations, liquidity and financial condition, net cash provided by operating activities, restrictions imposed by applicable law, our taxable income, our operating expenses and other factors our board of directors deem relevant. There can be no assurance that we will continue to pay dividends in amounts or on a basis consistent with prior distributions to our investors, if at all. Because we are a holding company and have no direct operations, we will only be able to pay dividends from our available cash on hand and any funds we receive from our subsidiaries and our ability to receive distributions from our subsidiaries may be limited by the financing agreements to which they are subject.

The incurrence or issuance of debt which ranks senior to our Class A common stock upon our liquidation and future issuances of equity or equity-related securities, which would dilute the holdings of our existing Class A common stockholders and may be senior to our Class A common stock for the purposes of making distributions, periodically or upon liquidation, may negatively affect the market price of our Class A common stock.

We have incurred and may in the future incur or issue debt or issue equity or equity-related securities to finance our operations, acquisitions or investments. Upon our liquidation, lenders and holders of our debt and holders of our preferred stock (if any) would receive a distribution of our available assets before Class A common stockholders. Any future incurrence or issuance of debt would increase our interest cost and could adversely affect our results of operations and cash flows. We are not required to offer any additional equity securities to existing Class A common stockholders on a preemptive basis. Therefore, additional issuances of Class A common stock, directly or through convertible or exchangeable securities (including limited partnership interests in our operating partnership), warrants or options, will dilute the holdings of our existing Class A common stockholders and such issuances, or the perception of such issuances, may reduce the market price of our Class A common stock. Any preferred stock issued by us would likely have a preference on distribution payments, periodically or upon liquidation, which could eliminate or otherwise limit our ability to make distributions to Class A common stockholders. Because our decision to incur or issue debt or issue equity or equity-related securities in the future will depend on market conditions and other factors beyond our control, we cannot predict or estimate the amount, timing, nature or success of our future capital raising efforts. Thus, Class A common stockholders bear the risk that our future incurrence or issuance of debt or issuance of equity or equity-related securities will adversely affect the market price of our Class A common stock.

We may issue preferred stock, the terms of which could adversely affect the voting power or value of our Class A common stock.

Our Certificate of Incorporation and By-Laws authorize us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, including preferences over our Class A common stock in respect of dividends and distributions, as our board of directors may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our Class A common stock. For example, we might grant holders of preferred stock the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred stock could affect the residual value of the Class A common stock.

Sales or issuances of our Class A common stock could adversely affect the market price of our Class A common stock.

Sales of substantial amounts of our Class A common stock in the public market, or the perception that such sales might occur, could adversely affect the market price of our Class A common stock. The issuance of our Class A common stock in connection with property, portfolio or business acquisitions or the exercise of outstanding options or otherwise could also have an adverse effect on the market price of our Class A common stock.

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An active, liquid and orderly trading market for our Class A common stock may not be maintained and the price of our Class A common stock may fluctuate significantly.

Prior to January 2019, there was no public market for our Class A common stock. An active, liquid and orderly trading market for our Class A common stock may not be maintained. Active, liquid and orderly trading markets usually result in less price volatility and more efficiency in carrying out investors’ purchase and sale orders. The market price of our Class A common stock could vary significantly as a result of a number of factors, some of which are beyond our control. In the event of a drop in the market price of our Class A common stock, you could lose a substantial part or all of your investment in our Class A common stock.

General Risks

We are a holding company and our operational and consolidated financial results are dependent on the results of our subsidiaries, affiliates, joint ventures and special purpose entities in which we invest.

We conduct our business mainly through our operating subsidiaries and affiliates, including joint ventures and other special purpose entities, which are created specifically to participate in projects or manage a specific asset. Our ability to meet our financial obligations is therefore related in part to the cash flow and earnings of our subsidiaries and affiliates and the ability or willingness of these entities to make distributions or other transfers of earnings to us in the form of dividends, loans or other advances and payments, which are governed by various shareholder agreements, joint venture financing and operating arrangements. In addition, some of our operating subsidiaries, joint venture and special purpose entities are subject to restrictive covenants related to their indebtedness, including restrictions on dividend distributions. Any additional debt or other financing could include similar restrictions, which would limit their ability to make distributions or other transfers of earnings to us in the form of dividends, loans or other advances and payments. Similarly, we may fail to realize anticipated benefits of any joint venture or similar arrangement, which could adversely affect our financial condition and results of operation.

We may engage in mergers, sales and acquisitions, divestments, reorganizations or similar transactions related to our businesses or assets in the future and we may fail to successfully complete such transaction or to realize the expected value.

In furtherance of our business strategy, we may engage in mergers, purchases or sales, divestments, reorganizations or other similar transactions related to our businesses or assets in the future. Any such transactions may be subject to significant risks and contingencies, including the risk of integration, valuation and successful implementation, and we may not be able to realize the benefits of any such transactions. We may also engage in sales of our assets or sale and leaseback transactions that seek to monetize our assets and there is no guarantee that such sales of assets will be executed at the prices we desire or higher than the values we currently carry these assets at on our balance sheet. We do not know if we will be able to successfully complete any such transactions or whether we will be able to retain key personnel, suppliers or distributors. Our ability to successfully implement our strategy through such transactions depends upon our ability to identify, negotiate and complete suitable transactions and to obtain the required financing on terms acceptable to us. These efforts could be expensive and time consuming, disrupt our ongoing business and distract management. If we are unable to successfully complete our transactions, our business, financial condition, results of operations and prospects could be materially adversely affected.

We are unable to predict the extent to which the global pandemics and health crisis, such as the COVID-19 pandemic, will negatively affect our operations, financial performance, nor our ability to achieve our strategic objectives. We are also unable to predict how this global pandemic may affect our customers and suppliers.

The COVID-19 pandemic has caused, and is expected to continue to cause, economic disruptions in various regions, disruptions in global supply chains, significant volatility and disruption of financial markets and in the price of oil and other commodities. In addition, the pandemic has made, and any future global health crisis or pandemic could make, travel and commercial activity significantly more cumbersome and less efficient compared to pre-pandemic conditions. Because the severity, magnitude and duration of any such crisis or pandemic and its economic consequences are uncertain, rapidly-changing and difficult to predict, its impact on our operations and financial performance, as well as its impact on our ability to successfully execute our business strategies and initiatives, remains or could be uncertain and difficult to predict. Further, the ultimate impact of any such pandemic or crisis on our operations and financial performance depends on many factors that are not within our control, including, but not limited, to: governmental, business and individuals’ actions that have been and continue to be taken in response to the COVID-19 pandemic (including restrictions on travel and transport and workforce pressures); the impact of such pandemic or crisis and actions taken in response on global and regional economies, travel, and economic activity; the availability of federal, state, local or non-U.S. funding programs, as well as

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other monetary and financial policies enacted by governments (including monetary policy, taxation, exchange controls, interest rates, regulation of banking and financial services and other industries, government budgeting and public sector financing); the duration and severity of resurgences of any variants; general economic uncertainty in key global markets and financial market volatility; global economic conditions and levels of economic growth; and the pace of recovery when the pandemic or crisis subsides. Our operations, financial performance and financial condition have been subjected to the COVID-19 pandemic and could be subjected to a number of operational financial risks in any such future pandemic or crisis. Although the services we provide are generally deemed essential, we may face negative impacts from increased operational challenges based on the need to protect employee health and safety, workplace disruptions and restrictions on the movement of people including our employees and subcontractors, and disruptions to supply chains related to raw materials and goods both at our own facilities, liquefaction facilities and at customers and suppliers. We may also experience a lower demand for natural gas at our existing customers and a decrease in interest from potential customers as a result of the pandemic’s impact on the operations and financial condition of our customers and potential customers, as well as the price of available fuel options, including oil-based fuels as well as strains the pandemic places on the capacity of potential customers to evaluate purchasing our goods and services. We may experience customer requests for potential payment deferrals or other contract modifications and delays of potential or ongoing construction projects due to government guidance or customer requests. Conditions in the financial and credit markets may limit the availability of funding and pose heightened risks to future financings we may require. These and other factors we cannot anticipate could adversely affect our business, financial position and results of operations. It is possible that the longer this period of economic and global supply chain and disruption continues, the greater the uncertainty will be regarding the possible adverse impact on our business operations, financial performance and results of operations.

A change in tax laws in any country in which we operate could adversely affect us.

Tax laws, regulations and treaties are highly complex and subject to interpretation. Consequently, we are subject to changing laws, treaties and regulations in and between the countries in which we operate. Our tax expense is based on our interpretation of the tax laws in effect at the time the expense was incurred. A change in tax laws, regulations, or treaties, or in the interpretation thereof, could result in a materially higher tax expense or a higher effective tax rate on our earnings. Our after-tax profitability could be affected by numerous factors, including the availability of tax credits, exemptions and other benefits to reduce our tax liabilities, changes in the relative amount of our earnings subject to tax in the various jurisdictions in which we operate, the potential expansion of our business into or otherwise becoming subject to tax in additional jurisdictions, changes to our existing businesses and operations, the extent of our intercompany transactions and the extent to which taxing authorities in the relevant jurisdictions respect those intercompany transactions. Our after-tax profitability may also be affected by changes in the relevant tax laws and tax rates, regulations, administrative practices and principles, judicial decisions, and interpretations, in each case, possibly with retroactive effect.

We have been and may be involved in legal proceedings and may experience unfavorable outcomes.

We have been and may in the future be subject to material legal proceedings in the course of our business or otherwise, including, but not limited to, actions relating to contract disputes, business practices, intellectual property, real estate and leases, and other commercial, tax, regulatory and permitting matters. Such legal proceedings may involve claims for substantial amounts of money or for other relief or might necessitate changes to our business or operations, and the defense of such actions may be both time-consuming and expensive. Moreover, the process of litigating requires substantial time, which may distract our management. Even if we are successful, any litigation may be costly, and may approximate the cost of damages sought. These actions could also expose us to adverse publicity, which might adversely affect our reputation and therefore, our results of operations. Further, if any such proceedings were to result in an unfavorable outcome, it could have an adverse effect on our business, financial position and results of operations.

If we fail to develop or maintain an effective system of internal controls, we may not be able to accurately report our financial results or prevent fraud. As a result, current and potential stockholders could lose confidence in our financial reporting, which would harm our business and the trading price of our Class A common stock.

Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and operate successfully as a publicly traded company. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. We cannot be certain that we will be able to maintain adequate controls over our financial processes and reporting in the future or that we will be able to comply with our obligations under Section 404 of the Sarbanes-Oxley Act. Any failure to develop or maintain effective internal controls, or difficulties encountered in implementing or improving our internal controls, could harm our operating results or cause us to fail to meet our reporting obligations. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our Class A common stock.

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Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds.

(a) None.

(b) None.

(c) None.

Some of our operating subsidiaries, joint venture and special purpose entities are subject to restrictive covenants related to their indebtedness, including restrictions on dividend distributions. For information on our long-term debt obligations and debt and lease restrictions, see “Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Long-Term Debt and Preferred Stock —Debt and lease restrictions.”

Item 3.    Defaults Upon Senior Securities.

None.

Item 4.    Mine Safety Disclosures.

Not applicable.

Item 5.    Other Information.

Not applicable.

Item 6.    Exhibits.

Exhibit Number			Description
3.1			Certificate of Conversion of New Fortress Energy Inc. (incorporated by reference to Exhibit 99.2 to the Registrant’s Quarterly Report on Form 10-Q filed with the SEC on August 4, 2020).
3.2			Certificate of Incorporation of New Fortress Energy Inc. (incorporated by reference to Exhibit 99.3 to the Registrant’s Quarterly Report on Form 10-Q filed with the SEC on August 4, 2020).
3.3			Bylaws of New Fortress Energy Inc. (incorporated by reference to Exhibit 99.4 to the Registrant’s Quarterly Report on Form 10-Q filed with the SEC on August 4, 2020).
10.1†			New Fortress Energy LLC 2019 Omnibus Incentive Plan (incorporated by reference to Exhibit 4.4 to the Registrant’s Registration Statement on Form S-8, filed with the SEC on February 4, 2019).
10.2†			Form of Director Restricted Share Unit Award Agreement (incorporated by reference to Exhibit 10.4 to the Registrant’s Registration Statement on Form S-1/A, filed with the SEC on December 24, 2018).
10.3†			Restricted Share Unit Award Agreement under the Amended and Restated New Fortress Energy Inc. 2019 Omnibus Incentive Plan (incorporated by reference to Exhibit 10.5 to the Registrant’s Quarterly Report on Form 10-Q, filed with the Commission on November 8, 2022).
10.4			Shareholders’ Agreement, dated February 4, 2019, by and among New Fortress Energy LLC, New Fortress Energy Holdings LLC, Wesley R. Edens and Randal A. Nardone (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.5			Administrative Services Agreement, dated February 4, 2019, by and between New Fortress Intermediate LLC and FIG LLC (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).

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10.6†			Indemnification Agreement (Edens) (incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.7†			Indemnification Agreement (Guinta) (incorporated by reference to Exhibit 10.5 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.8†			Indemnification Agreement (Catterall) (incorporated by reference to Exhibit 10.7 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.9†			Indemnification Agreement (Grain) (incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.10†			Indemnification Agreement (Griffin) (incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.11†			Indemnification Agreement (Mack) (incorporated by reference to Exhibit 10.10 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.12†			Indemnification Agreement (Nardone) (incorporated by reference to Exhibit 10.11 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.13†			Indemnification Agreement (Wanner) (incorporated by reference to Exhibit 10.12 to the Registrant’s Current Report on Form 8-K, filed with the SEC on February 5, 2019).
10.14†			Indemnification Agreement (Jay ) (incorporated by reference to Exhibit 10.15 to the Registrant's Quarterly Report on Form 10-Q, filed with the SEC on May 4, 2023).
10.15†			Indemnification Agreement, dated as of March 17, 2019, by and between New Fortress Energy LLC and Yunyoung Shin (incorporated by reference to Exhibit 10.29 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 26, 2019).
10.16			Letter Agreement, dated as of December 3, 2019, by and between NFE Management LLC and Yunyoung Shin. (incorporated by reference to Exhibit 10.3 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 6, 2020).
10.17			Letter Agreement, dated as of March 14, 2017, by and between NFE Management LLC and Christopher S. Guinta (incorporated by reference to Exhibit 10.17 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.18			Indenture, dated September 2, 2020, by and among the Company, the subsidiary guarantors from time to time party thereto, and U.S. Bank National Association, as trustee and as notes collateral agent (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on September 2, 2020).
10.19			Pledge and Security Agreement, dated September 2, 2020, by and among the Company, the subsidiary guarantors from time to time party thereto, and U.S. Bank National Association, as notes collateral agent (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K, filed with the SEC on September 2, 2020).
10.20			First Supplemental Indenture, dated December 17, 2020, by and among the Company, the subsidiary guarantors from time to time party thereto and U.S. Bank National Association, as trustee and as notes collateral agent (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on December 18, 2020).

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10.21			Second Supplemental Indenture, dated as of March 1, 2021, between NFE US Holdings LLC, as Guaranteeing Subsidiary, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.21 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.22			Third Supplemental Indenture, dated as of June 11, 2021, between Golar GP LLC (now known as NFE GP LLC), as Guaranteeing Subsidiary, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.22 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.23			Fourth Supplemental Indenture, dated as of September 13, 2021, between NFE Mexico Power Holdings Limited and NFE Mexico Terminal Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.23 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.24			Fifth Supplemental Indenture, dated as of November 24, 2021, between NFE International Shipping LLC, NFE Global Shipping LLC, NFE Grand Shipping LLC and NFE International Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.24 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.25			Sixth Supplemental Indenture, dated as of March 23, 2022, between NFE UK Holdings Limited, NFE Global Holdings Limited and NFE Bermuda Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.25 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.26			Seventh Supplemental Indenture, dated as of December 22, 2022, between NFE Andromeda Chartering LLC, as Guaranteeing Subsidiary, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.26 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.27			Indenture, dated April 12, 2021, by and among the Company, the subsidiary guarantors from time to time party thereto, and U.S. Bank National Association, as trustee and as notes collateral agent (incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on April 12, 2021).
10.28			Pledge and Security Agreement, dated April 12, 2021, by and among the Company, the subsidiary guarantors, from time to time party thereto, and U.S. Bank National Association, as notes collateral agent (incorporated by reference to Exhibit 4.2 to the Registrant’s Current Report on Form 8-K, filed with the SEC on April 12, 2021).
10.29			First Supplemental Indenture, dated as of June 11, 2021, between Golar GP LLC (now known as NFE GP LLC), as Guaranteeing Subsidiary, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.29 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.30			Second Supplemental Indenture, dated as of September 13, 2021, between NFE Mexico Power Holdings Limited and NFE Mexico Terminal Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.30 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.31			Third Supplemental Indenture, dated as of November 24, 2021, between NFE International Shipping LLC, NFE Global Shipping LLC, NFE Grand Shipping LLC and NFE International Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.31 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).

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10.32			Fourth Supplemental Indenture, dated as of March 23, 2022, between NFE UK Holdings Limited, NFE Global Holdings Limited and NFE Bermuda Holdings Limited, as Guaranteeing Subsidiaries, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.32 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.33			Fifth Supplemental Indenture, dated as of December 22, 2022, between NFE Andromeda Chartering LLC, as Guaranteeing Subsidiary, and U.S. Bank Trust Company, National Association (as successor in interest to U.S. Bank National Association), as trustee (incorporated by reference to Exhibit 10.33 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.34			Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders and issuing banks from time to time party thereto, and Morgan Stanley Senior Funding, Inc,. as administrative agent and collateral agent (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K, filed with the SEC on April 21, 2021).
10.35			First amendment to Credit Agreement, dated as of July 16, 2021 to the Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time partly thereto, the several lenders and issuing banks from time to time partly thereto, and Morgan Stanley Senior Funding, Inc., as administrative agent (incorporated by reference to Exhibit 10.30 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2022).
10.36			Second Amendment to Credit Agreement, dated as of February 28, 2022 to the Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders and issuing banks from time to time party thereto, and Morgan Stanley Senior Funding, Inc., as administrative agent and collateral agent (incorporated by reference to Exhibit 10.31 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2022).
10.37			Third Amendment to Credit Agreement, dated as of May 4, 2022 to the Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders and issuing banks from time to time party thereto, and Morgan Stanley Senior Funding, Inc., as administrative agent and collateral agent (incorporated by reference to Exhibit 10.32 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 6, 2022).
10.38			Fourth Amendment to Credit Agreement, dated as of February 7, 2023 to the Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders and issuing banks from time to time party thereto, and MUFG Bank Ltd., as administrative agent and collateral agent (incorporated by reference to Exhibit 10.38 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.39*			Fifth Amendment to Credit Agreement, dated as of September 15, 2023 to the Credit Agreement, dated as of April 15, 2021, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders and issuing banks from time to time party thereto, and MUFG Bank Ltd., as administrative agent and collateral agent.
10.40			Omnibus Agreement, dated as of April 15, 2021, by and among the Company, GLNG and certain other parties thereto (incorporated by reference to Exhibit 10.30 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 7, 2021).
10.41			Indemnity Agreement, dated as of April 15, 2021, by and among the Company, GLNG, and certain affiliates of Stonepeak (incorporated by reference to Exhibit 10.31 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 7, 2021).
10.42			Omnibus Agreement, dated as of April 15, 2021, by and among the Company, GMLP, GLNG and certain parties thereto (incorporated by reference to Exhibit 10.32 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 7, 2021).

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10.43			Tax Indemnification Agreement, dated as of April 15, 2021, by and between NFE International and GLNG (incorporated by reference to Exhibit 10.33 to the Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on May 7, 2021).
10.44#			Share Purchase Agreement, dated as of May 31, 2022, by and among LNG Power Limited, Ebrasil Energia Ltda., the individual DC Energia Sellers set forth therein, collectively as Sellers, Eneva S.A., as Buyer, and Eletricidade do Brasil S.A. -Ebrasil, as guarantor for the obligations of the DC Energia Sellers (incorporated by reference to Exhibit 10.38 to Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on August 5, 2022).
10.45			Equity Purchase and Contribution Agreement, dated as of July 2, 2022, by and among Golar LNG Partners LP and Hygo Energy Transition Ltd., as Sellers, AP Neptune Holdings Ltd, as Purchaser, Floating Infrastructure Holdings LLC, as the Company, and Floating Infrastructure Intermediate LLC, as Holdco Pledgor, and Floating Infrastructure Holdings finance LLC, as Borrower, and New Fortress Energy Inc.(incorporated by reference to Exhibit 10.39 to Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on August 5, 2022).
10.46			Second Amendment to Uncommitted Letter of Credit and Reimbursement Agreement, dated July 27, 2022, by and among New Fortress Energy Inc., the guarantors party thereto, Natixis, New York Branch, as Administrative Agent, Natixis, New York Branch, as ULCA Collateral Agent, Natixis, New York Branch, and each of the other financial institutions party thereto, as Lenders and Issuing Banks (incorporated by reference to Exhibit 10.40 to Registrant’s Quarterly Report on Form 10-Q, filed with the SEC on August 5, 2022).
10.47			Incremental Joinder Agreement Regarding to Uncommitted Letter of Credit and Reimbursement Agreement, dated February 6, 2023, by and among New Fortress Energy Inc., the guarantors party thereto, Natixis, New York Branch, as Administrative Agent and as Issuing Bank, Credit Agricole Corporate and Investment Bank, as Issuing Bank, and Sumitomo Mitsui Banking Corporation, as Issuing Bank (incorporated by reference to Exhibit 10.45 to the Registrant’s Annual Report on Form 10-K, filed with the SEC on March 1, 2023).
10.48			Underwriting Agreement, dated December 14, 2022, by and among New Fortress Energy Inc., Energy Transition Holdings LLC and J.P. Morgan Securities LLC (incorporated by reference to Exhibit 1.1 to the Registrant’s Current Report on Form 8-K, filed with the SEC on December 16, 2022).
10.49*			Credit Agreement, dated as of August 3, 2023, by and among the Company, as the borrower, the guarantors from time to time party thereto, the several lenders from time to time party thereto, and Morgan Stanley Senior Funding Inc., as lead arranger and bookrunner.
31.1*			Certification by Chief Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*			Certification by Chief Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) of the Exchange Act, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**			Certifications by Chief Executive Officer pursuant to Title 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**			Certifications by Chief Financial Officer pursuant to Title 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*			Inline XBRL Instance Document
101.SCH*			Inline XBRL Schema Document
101.CAL*			Inline XBRL Calculation Linkbase Document

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101.LAB*			Inline XBRL Label Linkbase Document
101.PRE*			Inline XBRL Presentation Linkbase Document
101.DEF*			Inline XBRL Taxonomy Extension Definition Linkbase Document
104*			Cover Page Interactive Data File, formatted in Inline XBRL and contained in Exhibit 101

* Filed as an exhibit to this Quarterly Report.

** Furnished as an exhibit to this Quarterly Report.

† Compensatory plan or arrangement.

# Portions of the exhibit (indicated by asterisks) have been omitted in pursuant to Item 601 (b)(10)(iv) of Regulation S-K.

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SIGNATURES

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

			NEW FORTRESS ENERGY INC.
Date: November 9, 2023
			By:			/s/ Wesley R. Edens
			Name:			Wesley R. Edens
			Title:			Chief Executive Officer and Chairman
						(Principal Executive Officer)
Date: November 9, 2023
			By:			/s/ Christopher S. Guinta
			Name:			Christopher S. Guinta
			Title:			Chief Financial Officer
						(Principal Financial Officer)
Date: November 9, 2023
			By:			/s/ Yunyoung Shin
			Name:			Yunyoung Shin
			Title:			Chief Accounting Officer
						(Principal Accounting Officer)

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