10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2021

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 001-16383

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware	95-4352386
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

700 Milam Street, Suite 1900

Houston, Texas 77002

(Address of principal executive offices) (Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

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

Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $ 0.003 par value	LNG	NYSE American

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒   No  ☐

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

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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes  ☐  No  ☒ 

As of October 29, 2021, the issuer had 253,588,453 shares of Common Stock outstanding.

CHENIERE ENERGY, INC.

TABLE OF CONTENTS

	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Statements of Operations	3
	Consolidated Balance Sheets	4
	Consolidated Statements of Stockholders’ Equity	5
	Consolidated Statements of Cash Flows	7
	Notes to Consolidated Financial Statements	8
	Note 1—Nature of Operations and Basis of Presentation	8
	Note 2—Restricted Cash	9
	Note 3—Accounts and Other Receivables, Net of Current Expected Credit Losses	9
	Note 4—Inventory	10
	Note 5—Property, Plant and Equipment, Net of Accumulated Depreciation	10
	Note 6—Derivative Instruments	11
	Note 7—Non-Controlling Interest and Variable Interest Entity	16
	Note 8—Accrued Liabilities	17
	Note 9—Debt	18
	Note 10—Leases	22
	Note 11—Revenues from Contracts with Customers	24
	Note 12—Related Party Transactions	25
	Note 13—Income Taxes	27
	Note 14—Share-Based Compensation	27
	Note 15—Net Income per Share Attributable to Common Stockholders	28
	Note 16—Stockholders’ Equity	28
	Note 17—Customer Concentration	29
	Note 18—Supplemental Cash Flow Information	29
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	52
Item 4.	Controls and Procedures	53
Part II. Other Information
Item 1.	Legal Proceedings	54
Item 1A.	Risk Factors	54
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	54
Item 6.	Exhibits	55
	Signatures	56

i

DEFINITIONS

As used in this quarterly report, the terms listed below have the following meanings: 

Common Industry and Other Terms

Bcf	billion cubic feet
Bcf/d	billion cubic feet per day
Bcf/yr	billion cubic feet per year
Bcfe	billion cubic feet equivalent
DOE	U.S. Department of Energy
EPC	engineering, procurement and construction
FERC	Federal Energy Regulatory Commission
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
Henry Hub	the final settlement price (in USD per MMBtu) for the New York Mercantile Exchange’s Henry Hub natural gas futures contract for the month in which a relevant cargo’s delivery window is scheduled to begin
IPM	integrated production marketing
LIBOR	London Interbank Offered Rate
LNG	liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state
MMBtu	million British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
mtpa	million tonnes per annum
non-FTA countries	countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC	U.S. Securities and Exchange Commission
SPA	LNG sale and purchase agreement
TBtu	trillion British thermal units; one British thermal unit measures the amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit
Train	an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA	terminal use agreement

1

Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of September 30, 2021, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:

Unless the context requires otherwise, references to “Cheniere,” the “Company,” “we,” “us” and “our” refer to Cheniere Energy, Inc. and its consolidated subsidiaries, including our publicly traded subsidiary, Cheniere Partners.

Unless the context requires otherwise, references to the “CCH Group” refer to CCH, CCL and CCP, collectively.

2

PART I.    FINANCIAL INFORMATION 

ITEM 1.    CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Revenues
LNG revenues	$	3,078	$	1,373	$	8,990	$	6,236
Regasification revenues	68		67		202		202
Other revenues	54		20		115		133
Total revenues	3,200		1,460		9,307		6,571
Operating costs and expenses
Cost of sales (excluding items shown separately below)	4,868		768		8,408		2,295
Operating and maintenance expense	350		317		1,057		988
Development expense	2		—		5		5
Selling, general and administrative expense	70		70		224		224
Depreciation and amortization expense	259		233		753		699
Impairment expense and loss on disposal of assets	1		—		—		5
Total operating costs and expenses	5,550		1,388		10,447		4,216
Income (loss) from operations	(2,350)		72		(1,140)		2,355
Other expense
Interest expense, net of capitalized interest	(364)		(355)		(1,088)		(1,174)
Loss on modification or extinguishment of debt	(36)		(171)		(95)		(215)
Interest rate derivative loss, net	(2)		—		(3)		(233)
Other expense, net	(24)		(129)		(14)		(115)
Total other expense	(426)		(655)		(1,200)		(1,737)
Income (loss) before income taxes and non-controlling interest	(2,776)		(583)		(2,340)		618
Less: income tax provision (benefit)	(1,860)		(75)		(1,864)		119
Net income (loss)	(916)		(508)		(476)		499
Less: net income (loss) attributable to non-controlling interest	168		(45)		544		390
Net income (loss) attributable to common stockholders	$	(1,084)	$	(463)	$	(1,020)	$	109
Net income (loss) per share attributable to common stockholders—basic and diluted	$	(4.27)	$	(1.84)	$	(4.03)	$	0.43
Weighted average number of common shares outstanding—basic	253.6		252.2		253.3		252.5
Weighted average number of common shares outstanding—diluted	253.6		252.2		253.3		253.2

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

3

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (1)

(in millions, except share data)

	September 30,		December 31,
	2021		2020
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	2,203	$	1,628
Restricted cash	419		449
Accounts and other receivables, net of current expected credit losses	983		647
Inventory	471		292
Current derivative assets	266		32
Margin deposits	336		25
Other current assets	185		96
Total current assets	4,863		3,169
Property, plant and equipment, net of accumulated depreciation	30,318		30,421
Operating lease assets	2,064		759
Derivative assets	71		376
Goodwill	77		77
Deferred tax assets	2,361		489
Other non-current assets, net	425		406
Total assets	$	40,179	$	35,697
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	73	$	35
Accrued liabilities	1,787		1,175
Current debt, net of discount and debt issuance costs	1,047		372
Deferred revenue	187		138
Current operating lease liabilities	458		161
Current derivative liabilities	1,979		313
Other current liabilities	129		2
Total current liabilities	5,660		2,196
Long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Operating lease liabilities	1,590		597
Finance lease liabilities	57		57
Derivative liabilities	2,158		151
Other non-current liabilities	20		7
Stockholders’ equity
Preferred stock, $0.0001 par value, 5.0 million shares authorized, none issued	—		—
Common stock, $0.003 par value, 480.0 million shares authorized; 275.1 million shares and 273.1 million shares issued at September 30, 2021 and December 31, 2020, respectively	1		1
Treasury stock: 21.6 million shares and 20.8 million shares at September 30, 2021 and December 31, 2020, respectively, at cost	(924)		(872)
Additional paid-in-capital	4,364		4,273
Accumulated deficit	(4,698)		(3,593)
Total stockholders' deficit	(1,257)		(191)
Non-controlling interest	2,470		2,409
Total equity	1,213		2,218
Total liabilities and stockholders’ equity	$	40,179	$	35,697

(1)Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

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

4

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(in millions)

(unaudited)

Three and Nine Months Ended September 30, 2021
	Total Stockholders’ Equity
	Common Stock			Treasury Stock			Additional Paid-in Capital		Accumulated Deficit		Non-controlling Interest		Total Equity
	Shares	Par Value Amount		Shares	Amount
Balance at December 31, 2020	252.3	$	1	20.8	$	(872)	$	4,273	$	(3,593)	$	2,409	$	2,218
Vesting of restricted stock units and performance stock units	1.8	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		33		—		—		33
Issued shares withheld from employees related to share-based compensation, at cost	(0.6)	—		0.6	(42)		—		—		—		(42)
Net income attributable to non-controlling interest	—	—		—	—		—		—		178		178
Distributions to non-controlling interest	—	—		—	—		—		—		(160)		(160)
Net income	—	—		—	—		—		393		—		393
Balance at March 31, 2021	253.5	1		21.4	(914)		4,306		(3,200)		2,427		2,620
Vesting of restricted stock units and performance stock units	0.1	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		31		—		—		31
Issued shares withheld from employees related to share-based compensation, at cost	—	—		—	(1)		—		—		—		(1)
Net income attributable to non-controlling interest	—	—		—	—		—		—		198		198
Distributions to non-controlling interest	—	—		—	—		—		—		(162)		(162)
Net loss	—	—		—	—		—		(329)		—		(329)
Balance at June 30, 2021	253.6	1		21.4	(915)		4,337		(3,529)		2,463		2,357
Vesting of restricted stock units and performance stock units	0.1	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		28		—		—		28
Issued shares withheld from employees related to share-based compensation, at cost	(0.1)	—		0.1	(3)		(1)		—		—		(4)
Shares repurchased, at cost	(0.1)	—		0.1	(6)		—		—		—		(6)
Net income attributable to non-controlling interest	—	—		—	—		—		—		168		168
Distributions to non-controlling interest	—	—		—	—		—		—		(161)		(161)
Dividends declared ($0.33 per common share)	—	—		—	—		—		(85)		—		(85)
Net loss	—	—		—	—		—		(1,084)		—		(1,084)
Balance at September 30, 2021	253.5	$	1	21.6	$	(924)	$	4,364	$	(4,698)	$	2,470	$	1,213

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

5

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY—CONTINUED

(in millions)

(unaudited)

Three and Nine Months Ended September 30, 2020
	Total Stockholders’ Equity
	Common Stock			Treasury Stock			Additional Paid-in Capital		Accumulated Deficit		Non-controlling Interest		Total Equity
	Shares	Par Value Amount		Shares	Amount
Balance at December 31, 2019	253.6	$	1	17.1	$	(674)	$	4,167	$	(3,508)	$	2,449	$	2,435
Vesting of restricted stock units and performance stock units	2.1	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		29		—		—		29
Issued shares withheld from employees related to share-based compensation, at cost	(0.7)	—		0.7	(39)		—		—		—		(39)
Shares repurchased, at cost	(2.9)	—		2.9	(155)		—		—		—		(155)
Net income attributable to non-controlling interest	—	—		—	—		—		—		228		228
Distributions to non-controlling interest	—	—		—	—		—		—		(154)		(154)
Net income	—	—		—	—		—		375		—		375
Balance at March 31, 2020	252.1	1		20.7	(868)		4,196		(3,133)		2,523		2,719
Vesting of restricted stock units and performance stock units	0.1	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		31		—		—		31
Issued shares withheld from employees related to share-based compensation, at cost	—	—		—	(2)		—		—		—		(2)
Net income attributable to non-controlling interest	—	—		—	—		—		—		207		207
Distributions to non-controlling interest	—	—		—	—		—		—		(156)		(156)
Net income	—	—		—	—		—		197		—		197
Balance at June 30, 2020	252.2	1		20.7	(870)		4,227		(2,936)		2,574		2,996
Vesting of restricted stock units and performance stock units	0.1	—		—	—		—		—		—		—
Share-based compensation	—	—		—	—		26		—		—		26
Issued shares withheld from employees related to share-based compensation, at cost	(0.1)	—		0.1	(2)		—		—		—		(2)
Net loss attributable to non-controlling interest	—	—		—	—		—		—		(45)		(45)
Reacquisition of equity component of convertible notes, net of tax	—	—		—	—		(7)		—		—		(7)
Distributions to non-controlling interest	—	—		—	—		—		—		(158)		(158)
Net loss	—	—		—	—		—		(463)		—		(463)
Balance at September 30, 2020	252.2	$	1	20.8	$	(872)	$	4,246	$	(3,399)	$	2,371	$	2,347

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

6

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)

	Nine Months Ended September 30,
	2021		2020
Cash flows from operating activities
Net income (loss)	$	(476)	$	499
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	753		699
Share-based compensation expense	91		84
Non-cash interest expense	16		43
Amortization of debt issuance costs, premium and discount	57		94
Reduction of right-of-use assets	269		222
Loss on modification or extinguishment of debt	95		215
Total losses (gains) on derivatives, net	4,230		(282)
Net cash provided by (used for) settlement of derivative instruments	(486)		61
Impairment expense and loss on disposal of assets	—		5
Impairment expense and loss on equity method investments	16		130
Deferred taxes	(1,872)		115
Repayment of paid-in-kind interest related to repurchase of convertible notes	(190)		(911)
Other	3		2
Changes in operating assets and liabilities:
Accounts and other receivables, net of current expected credit losses	(338)		101
Inventory	(174)		31
Margin deposits	(311)		(10)
Other current assets	(92)		(27)
Accounts payable and accrued liabilities	612		(93)
Deferred revenue	58		18
Operating lease liabilities	(285)		(205)
Finance lease liabilities	1		—
Other, net	80		(26)
Net cash provided by operating activities	2,057		765
Cash flows from investing activities
Property, plant and equipment	(761)		(1,437)
Proceeds from sale of fixed assets	68		—
Investment in equity method investment	—		(100)
Other	(14)		(8)
Net cash used in investing activities	(707)		(1,545)
Cash flows from financing activities
Proceeds from issuances of debt	4,104		7,683
Repayments of debt	(4,276)		(6,324)
Debt issuance and other financing costs	(38)		(124)
Debt modification or extinguishment costs	(67)		(170)
Distributions to non-controlling interest	(483)		(468)
Payments related to tax withholdings for share-based compensation	(47)		(43)
Repurchase of common stock	(6)		(155)
Other	8		—
Net cash provided by (used in) financing activities	(805)		399
Net increase (decrease) in cash, cash equivalents and restricted cash	545		(381)
Cash, cash equivalents and restricted cash—beginning of period	2,077		2,994
Cash, cash equivalents and restricted cash—end of period	$	2,622	$	2,613

Balances per Consolidated Balance Sheets:

	September 30,
	2021
Cash and cash equivalents	$	2,203
Restricted cash	419
Total cash, cash equivalents and restricted cash	$	2,622

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

7

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We operate two natural gas liquefaction and export facilities at Sabine Pass and Corpus Christi (respectively, the “Sabine Pass LNG Terminal” and “Corpus Christi LNG Terminal”).

Cheniere Partners owns the Sabine Pass LNG Terminal located in Cameron Parish, Louisiana, which has natural gas liquefaction facilities consisting of five operational natural gas liquefaction Trains and one additional Train that is undergoing commissioning and expected to be substantially completed in the first quarter of 2022, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include five LNG storage tanks, vaporizers and two marine berths, with an additional marine berth that is under construction. Cheniere Partners also owns a 94-mile pipeline that interconnects the Sabine Pass LNG Terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) through its subsidiary, CTPL. As of September 30, 2021, we owned 100% of the general partner interest and 48.6% of the limited partner interest in Cheniere Partners.

The Corpus Christi LNG Terminal is located near Corpus Christi, Texas. We currently operate three Trains, for a total production capacity of approximately 15 mtpa of LNG. We also own a 23-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Trains, the “CCL Project”) through our subsidiary CCP, as part of the CCH Group. The CCL Project also contains three LNG storage tanks and two marine berths.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG Terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) through our subsidiary CCL Stage III, for up to seven midscale Trains with an expected total production capacity of approximately 10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and operate the expansion project.

We remain focused on operational excellence and customer satisfaction. Increasing demand for LNG has allowed us to expand our liquefaction infrastructure in a financially disciplined manner. We have increased available liquefaction capacity at the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) as a result of debottlenecking and other optimization projects. We hold significant land positions at both the Sabine Pass LNG Terminal and the Corpus Christi LNG Terminal which provide opportunity for further liquefaction capacity expansion. The development of these sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a final investment decision (“FID”).

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

Results of operations for the three and nine months ended September 30, 2021 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2021.

Recent Accounting Standards

In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. This guidance simplifies the accounting for convertible instruments primarily by eliminating the existing cash conversion and beneficial conversion models within Subtopic 470-20, which will result in fewer embedded conversion options being accounted for separately from the debt host. The guidance also amends and simplifies the calculation of earnings per share relating to convertible instruments. This guidance is effective for annual periods beginning after December 15, 2021, including interim periods within that reporting period, with earlier adoption permitted for fiscal years beginning after December 15, 2020, including interim periods within that reporting period, using either a full or modified retrospective approach. We plan to adopt

8

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

this guidance on January 1, 2022 using the modified retrospective approach. Preliminarily, we anticipate the adoption of ASU 2020-06 will primarily result in the reclassification of the previously bifurcated equity component associated with the 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to debt as a result of the elimination of the cash conversion model. We currently estimate that the reclassification of the $194 million equity component will result in an approximate $190 million increase in the carrying value of our 2045 Cheniere Convertible Senior Notes, with the difference primarily impacting retained earnings as of January 1, 2022. We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures. See Note 9—Debt for further discussion on the 2045 Cheniere Convertible Senior Notes.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing contracts expected to arise from the market transition from LIBOR to alternative reference rates. We have various credit facilities and interest rate swaps indexed to LIBOR, as further described in Note 6—Derivative Instruments and Note 9—Debt. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time the optional expedients are no longer available.

NOTE 2—RESTRICTED CASH

Restricted cash consists of funds that are contractually or legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. As of September 30, 2021 and December 31, 2020, restricted cash consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Restricted cash
SPL Project	$	133	$	97
CCL Project	59		70
Cash held by our subsidiaries that is restricted to Cheniere	227		282
Total restricted cash	$	419	$	449

Pursuant to the accounts agreements entered into with the collateral trustees for the benefit of SPL’s debt holders and CCH’s debt holders, SPL and CCH are required to deposit all cash received into reserve accounts controlled by the collateral trustees.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Projects and other restricted payments. The majority of the cash held by our subsidiaries that is restricted to Cheniere relates to advance funding for operation and construction needs of the Liquefaction Projects.

NOTE 3—ACCOUNTS AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES

As of September 30, 2021 and December 31, 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Trade receivables
SPL and CCL	$	584	$	482
Cheniere Marketing	272		113
Other accounts receivable	127		52
Total accounts and other receivables, net of current expected credit losses	$	983	$	647

9

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 4—INVENTORY

As of September 30, 2021 and December 31, 2020, inventory consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Materials	$	168	$	150
LNG in-transit	145		88
LNG	125		27
Natural gas	31		26
Other	2		1
Total inventory	$	471	$	292

NOTE 5—PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION

As of September 30, 2021 and December 31, 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
LNG terminal
LNG terminal and interconnecting pipeline facilities	$	30,617	$	27,475
LNG site and related costs	441		324
LNG terminal construction-in-process	2,817		5,378
Accumulated depreciation	(3,663)		(2,935)
Total LNG terminal, net of accumulated depreciation	30,212		30,242
Fixed assets and other
Computer and office equipment	27		25
Furniture and fixtures	20		19
Computer software	122		117
Leasehold improvements	45		45
Land	1		59
Other	21		25
Accumulated depreciation	(181)		(164)
Total fixed assets and other, net of accumulated depreciation	55		126
Assets under finance lease
Tug vessels	60		60
Accumulated depreciation	(9)		(7)
Total assets under finance lease, net of accumulated depreciation	51		53
Property, plant and equipment, net of accumulated depreciation	$	30,318	$	30,421

The following table shows depreciation expense and offsets to LNG terminal costs during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Depreciation expense	$	257	$	231	$	749	$	694
Offsets to LNG terminal costs (1)	—		—		227		—

(1)We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Projects during the testing phase for its construction.

10

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 6—DERIVATIVE INSTRUMENTS

We have entered into the following derivative instruments that are reported at fair value:

•interest rate swaps (“CCH Interest Rate Derivatives”) to hedge the exposure to volatility in a portion of the floating-rate interest payments on CCH’s amended and restated term loan credit facility (the “CCH Credit Facility”) and previously, to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”);

•commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Projects and potential future development of Corpus Christi Stage 3 (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”);

•physical derivatives consisting of liquified natural gas contracts in which we have contractual net settlement (“Physical LNG Trading Derivatives”) and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”); and

•foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with cash flows denominated in currencies other than United States dollar (“FX Derivatives”), associated with both LNG Trading Derivatives and operations in countries outside of the United States.

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow or fair value hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process, in which case it is capitalized.

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 (in millions):

	Fair Value Measurements as of
	September 30, 2021								December 31, 2020
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
CCH Interest Rate Derivatives liability	$	—	$	(67)	$	—	$	(67)	$	—	$	(140)	$	—	$	(140)
Liquefaction Supply Derivatives asset (liability)	(21)		3		(2,611)		(2,629)		5		(6)		241		240
LNG Trading Derivatives asset (liability)	11		(444)		(680)		(1,113)		(3)		(131)		—		(134)
FX Derivatives asset (liability)	—		9		—		9		—		(22)		—		(22)

We value our Interest Rate Derivatives using an income-based approach utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our LNG Trading Derivatives and our Liquefaction Supply Derivatives using a market or option-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data. We value our FX Derivatives with a market approach using observable FX rates and other relevant data.

The fair value of our Physical Liquefaction Supply Derivatives and LNG Trading Derivatives are predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated events deriving fair value, including evaluating whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of September 30, 2021 and December 31, 2020, some of our Physical

11

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow.

We include our Physical LNG Trading Derivatives and a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity, volatility and contract duration.

The Level 3 fair value measurements of our Physical LNG Trading Derivatives and the natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives and Physical LNG Trading Derivatives as of September 30, 2021:

	Net Fair Value Liability (in millions)	Valuation Approach	Significant Unobservable Input	Range of Significant Unobservable Inputs / Weighted Average (1)
Physical Liquefaction Supply Derivatives	$(2,611)	Market approach incorporating present value techniques	Henry Hub basis spread	$(1.333) - $0.895 / $(0.006)
		Option pricing model	International LNG pricing spread, relative to Henry Hub (2)	158% - 516% / 224%
Physical LNG Trading Derivatives	$(680)	Market approach incorporating present value techniques	International LNG pricing spread, relative to Henry Hub or TTF, as applicable (2)	$(11.275) - $23.458 / $17.777

(1)Unobservable inputs were weighted by the relative fair value of the instruments.

(2)Spread contemplates U.S. dollar-denominated pricing.

Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Physical LNG Trading Derivatives and our Physical Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of our Level 3 Physical LNG Trading Derivatives and Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Balance, beginning of period	$	(389)	$	590	$	241	$	138
Realized and mark-to-market gains (losses):
Included in cost of sales	(2,982)		(27)		(2,898)		454
Purchases and settlements:
Purchases	5		1		(657)		2
Settlements	75		(31)		23		(61)
Balance, end of period	$	(3,291)	$	533	$	(3,291)	$	533
Change in unrealized gains (losses) relating to instruments still held at end of period	$	(2,982)	$	(27)	$	(2,898)	$	454

All counterparty derivative contracts provide for the unconditional right of set-off in the event of default. We have elected to report derivative assets and liabilities arising from our derivative contracts with the same counterparty on a net basis. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

12

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Interest Rate Derivatives

CCH has entered into interest rate swaps to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility. CCH previously also had interest rate swaps to hedge against changes in interest rates that could impact the anticipated future issuance of debt. In August 2020, we settled the outstanding CCH Interest Rate Forward Start Derivatives.

As of September 30, 2021, we had the following Interest Rate Derivatives outstanding:

	Notional Amounts
	September 30, 2021	December 31, 2020	Latest Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
CCH Interest Rate Derivatives	$4.5 billion	$4.6 billion	May 31, 2022	2.30%	One-month LIBOR

The following table shows the effect and location of our Interest Rate Derivatives on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
CCH Interest Rate Derivatives	Interest rate derivative loss, net	$	(2)	$	—	$	(3)	$	(138)
CCH Interest Rate Forward Start Derivatives	Interest rate derivative loss, net	—		—		—		(95)

Commodity Derivatives

SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges, including those associated with our IPM transactions, to purchase natural gas for the commissioning and operation of the Liquefaction Projects and potential future development of Corpus Christi Stage 3, respectively, which are primarily indexed to the natural gas market and international LNG indices. The remaining terms of the index-based physical natural gas supply contracts range up to approximately 15 years, some of which commence upon the satisfaction of certain events or states of affairs. The terms of the Financial Liquefaction Supply Derivatives range up to approximately three years.

Commencing in first quarter of 2021, we have entered into physical LNG transactions that provide for contractual net settlement. Such transactions are accounted for as LNG Trading Derivatives, and are designed to economically hedge exposure to the commodity markets in which we sell LNG. We have entered into, and may from time to time enter into, financial LNG Trading Derivatives in the form of swaps, forwards, options or futures. The terms of LNG Trading Derivatives range up to approximately two years.

The following table shows the notional amounts of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”):

	September 30, 2021		December 31, 2020
	Liquefaction Supply Derivatives	LNG Trading Derivatives	Liquefaction Supply Derivatives	LNG Trading Derivatives
Notional amount, net (in TBtu) (1)	11,291	(14)	10,483	20

(1)Includes notional amounts for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

13

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location (1)	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
LNG Trading Derivatives	LNG revenues	$	(1,098)	$	13	$	(1,539)	$	119
LNG Trading Derivatives	Cost of sales	55		(5)		136		(5)
Liquefaction Supply Derivatives (2)	LNG revenues	(4)		21		(3)		7
Liquefaction Supply Derivatives (2)	Cost of sales	(2,444)		(103)		(2,848)		372

(1)Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

(2)Does not include the realized value associated with derivative instruments that settle through physical delivery.

FX Derivatives

Cheniere Marketing has entered into FX Derivatives to protect against the volatility in future cash flows attributable to changes in international currency exchange rates. The FX Derivatives economically hedge the foreign currency exposure arising from cash flows expended for both physical and financial LNG transactions that are denominated in a currency other than the United States dollar. The terms of FX Derivatives range up to approximately one year.

The total notional amount of our FX Derivatives was $499 million and $786 million as of September 30, 2021 and December 31, 2020, respectively.

The following table shows the effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
FX Derivatives	LNG revenues	$	11	$	(5)	$	27	$	22

14

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Fair Value and Location of Derivative Assets and Liabilities on the Consolidated Balance Sheets

The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions):

	September 30, 2021
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	88	$	163	$	15	$	266
Derivative assets	—		71		—		—		71
Total derivative assets	—		159		163		15		337
Current derivative liabilities	(67)		(630)		(1,276)		(6)		(1,979)
Derivative liabilities	—		(2,158)		—		—		(2,158)
Total derivative liabilities	(67)		(2,788)		(1,276)		(6)		(4,137)
Derivative asset (liability), net	$	(67)	$	(2,629)	$	(1,113)	$	9	$	(3,800)
	December 31, 2020
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	27	$	—	$	5	$	32
Derivative assets	—		376		—		—		376
Total derivative assets	—		403		—		5		408
Current derivative liabilities	(100)		(54)		(134)		(25)		(313)
Derivative liabilities	(40)		(109)		—		(2)		(151)
Total derivative liabilities	(140)		(163)		(134)		(27)		(464)
Derivative asset (liability), net	$	(140)	$	240	$	(134)	$	(22)	$	(56)

(1)Does not include collateral posted with counterparties by us of $47 million and $9 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes derivative assets for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

(2)Does not include collateral posted with counterparties by us of $287 million and $7 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively.

15

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Consolidated Balance Sheets Presentation

Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions):

	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives		LNG Trading Derivatives		FX Derivatives
As of September 30, 2021
Gross assets	$	—	$	179	$	174	$	30
Offsetting amounts	—		(20)		(11)		(15)
Net assets	$	—	$	159	$	163	$	15
Gross liabilities	$	(67)	$	(2,816)	$	(1,427)	$	(34)
Offsetting amounts	—		28		151		28
Net liabilities	$	(67)	$	(2,788)	$	(1,276)	$	(6)
As of December 31, 2020
Gross assets	$	—	$	452	$	—	$	6
Offsetting amounts	—		(49)		—		(1)
Net assets	$	—	$	403	$	—	$	5
Gross liabilities	$	(140)	$	(184)	$	(163)	$	(62)
Offsetting amounts	—		21		29		35
Net liabilities	$	(140)	$	(163)	$	(134)	$	(27)

NOTE 7—NON-CONTROLLING INTEREST AND VARIABLE INTEREST ENTITY

We own a 48.6% limited partner interest in Cheniere Partners in the form of 239.9 million common units, with the remaining non-controlling limited partner interest held by The Blackstone Group Inc., Brookfield Asset Management Inc. and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. Cheniere Partners is accounted for as a consolidated VIE. See Note 9—Non-Controlling Interest and Variable Interest Entity of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the fiscal year ended December 31, 2020 for further information.

16

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table presents the summarized assets and liabilities (in millions) of Cheniere Partners, our consolidated VIE, which are included in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020. The assets in the table below may only be used to settle obligations of Cheniere Partners. In addition, there is no recourse to us for the consolidated VIE’s liabilities. The assets and liabilities in the table below include third-party assets and liabilities of Cheniere Partners only and exclude intercompany balances that eliminate in consolidation.

	September 30,		December 31,
	2021		2020
ASSETS
Current assets
Cash and cash equivalents	$	1,713	$	1,210
Restricted cash	133		97
Accounts and other receivables, net of current expected credit losses	358		318
Other current assets	283		182
Total current assets	2,487		1,807
Property, plant and equipment, net of accumulated depreciation	16,820		16,723
Other non-current assets, net	294		287
Total assets	$	19,601	$	18,817
LIABILITIES
Current liabilities
Accrued liabilities	$	846	$	658
Current debt, net of premium, discount and debt issuance costs	944		—
Other current liabilities	216		171
Total current liabilities	2,006		829
Long-term debt, net of premium, discount and debt issuance costs	17,171		17,580
Other non-current liabilities	98		126
Total liabilities	$	19,275	$	18,535

NOTE 8—ACCRUED LIABILITIES

As of September 30, 2021 and December 31, 2020, accrued liabilities consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Interest costs and related debt fees	$	360	$	245
Accrued natural gas purchases	900		576
LNG terminals and related pipeline costs	126		147
Compensation and benefits	88		123
Accrued LNG inventory	3		4
Accrued dividends	84		—
Other accrued liabilities	226		80
Total accrued liabilities	$	1,787	$	1,175

17

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 9—DEBT

As of September 30, 2021 and December 31, 2020, our debt consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Long-term debt:
SPL — 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 SPL Working Capital Facility”) (1)	$	13,128	$	13,650
Cheniere Partners — 3.250% to 5.625% senior notes due between October 2025 and January 2032 and credit facilities (“2019 CQP Credit Facilities”)	4,200		4,100
CCH — 2.742% to 7.000% senior secured notes due between June 2024 and December 2039 and CCH Credit Facility	10,128		10,217
Cheniere — 4.625% senior secured notes due October 2028 (the “2028 Cheniere Senior Notes”), convertible notes, revolving credit facility (“Cheniere Revolving Credit Facility”) and term loan facility (“Cheniere Term Loan Facility”)	2,625		3,145
Unamortized premium, discount and debt issuance costs, net of accumulated amortization	(600)		(641)
Total long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Current debt:
SPL — current portion of 6.25% senior secured notes due March 2022 (the “2022 SPL Senior Notes”) (1) (2)	522		—
Cheniere Partners — current portion of 5.625% senior notes due October 2026 (the “2026 CQP Senior Notes”) (3)	428		—
CCH — $1.2 billion CCH working capital facility (“CCH Working Capital Facility”) and current portion of CCH Credit Facility	104		271
Cheniere Marketing — trade finance facilities and letter of credit facility	—		—
Cheniere — current portion of the 4.875% convertible unsecured notes due May 2021 (“2021 Cheniere Convertible Notes”)	—		104
Unamortized discount and debt issuance costs, net of accumulated amortization	(7)		(3)
Total current debt, net of discount and debt issuance costs	1,047		372
Total debt, net of premium, discount and debt issuance costs	$	30,528	$	30,843

(1)A portion of the 2022 SPL Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 SPL Senior Notes and pay related fees, costs and expenses.

(2)In October 2021, $318 million of the 2022 SPL Senior Notes was redeemed with $100 million from the proceeds from Cheniere Partners’ issuance of the 3.250% senior notes due 2032 (the “2032 CQP Senior Notes”) and $218 million of cash on hand. See Issuances, Redemptions and Repayments section below for further discussion.

(3)In October 2021, Cheniere Partners redeemed the remaining outstanding aggregate principal amount of the 2026 CQP Senior Notes that were not purchased pursuant to the tender offer and consent solicitation in September 2021. See Issuances, Redemptions and Repayments section below for further discussion.

18

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Issuances, Redemptions and Repayments

The following table shows the issuances, redemptions and repayments of long-term debt during the nine months ended September 30, 2021, excluding intra-quarter borrowings and repayments (in millions):

Issuances	Principal Amount Issued
Three Months Ended March 31, 2021
Cheniere Partners — 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”) (1)	$	1,500
Three Months Ended June 30, 2021
Cheniere — Cheniere Term Loan Facility (2)	220
Cheniere — Cheniere Revolving Credit Facility	134
Three Months Ended September 30, 2021
CCH — 2.742% Senior Notes due 2039 (the “2.742% CCH Senior Secured Notes”) (3)	750
Cheniere Partners — 2032 CQP Senior Notes (4)	1,200
Nine Months Ended September 30, 2021 total	$	3,804
Redemptions and Repayments	Principal Amount Redeemed/Repaid
Three Months Ended March 31, 2021
Cheniere Partners — 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) (1)	$	1,500
Cheniere — Cheniere Term Loan Facility (5)	148
Three Months Ended June 30, 2021
Cheniere — 2021 Cheniere Convertible Notes (2)	476
Cheniere — Cheniere Term Loan Facility (2)	220
Three Months Ended September 30, 2021
Cheniere — Cheniere Revolving Credit Facility	134
CCH — CCH Credit Facility (3)	866
Cheniere Partners — 2026 CQP Senior Notes (4)	672
Nine Months Ended September 30, 2021 total	$	4,016

(1)Net proceeds from the issuance of the 2031 CQP Senior Notes, together with cash on hand, were used to redeem all of Cheniere Partners’ outstanding 2025 CQP Senior Notes, resulting in $54 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs.

(2)The 2021 Cheniere Convertible Notes were repaid using a combination of borrowings under the Cheniere Term Loan Facility and cash on hand upon the maturity date at par value.

(3)Net proceeds of the 2.742% CCH Senior Secured Notes, together with cash on hand, were used to prepay a portion of the principal amount outstanding under the CCH Credit Facility, resulting in $9 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized issuance costs.

(4)Net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem a portion of the 2026 CQP Senior Notes in September 2021 pursuant to a tender offer and consent solicitation, resulting in $27 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs. In October 2021, the remaining net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 2022 SPL Senior Notes.

(5)The remaining commitments under the Cheniere Term Loan Facility were terminated in accordance with the credit agreement, resulting in $4 million of loss on extinguishment of debt relating to the write off of unamortized issuance costs.

19

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Credit Facilities

Below is a summary of our credit facilities outstanding as of September 30, 2021 (in millions):

	2020 SPL Working Capital Facility (1)		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Original facility size	$	1,200	$	1,500	$	8,404	$	350	$	750
Incremental commitments	—		—		1,566		850		500
Less:
Outstanding balance	—		—		1,761		—		—
Commitments prepaid or terminated	—		750		8,209		—		—
Letters of credit issued	396		—		—		360		—
Available commitment	$	804	$	750	$	—	$	840	$	1,250
Priority ranking	Senior secured		Senior secured		Senior secured		Senior secured		Senior secured
Interest rate on available balance	LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750%		LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125%		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Weighted average interest rate of outstanding balance	n/a		n/a		1.83%		n/a		n/a
Maturity date	March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		December 13, 2022

(1)The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL pays a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.

Convertible Notes

Below is a summary of our convertible notes outstanding as of September 30, 2021 (in millions):

	2045 Cheniere Convertible Senior Notes
Aggregate original principal	$	625
Debt component, net of discount and debt issuance costs	$	320
Equity component	$	194
Interest payment method	Cash
Conversion by us (1)	(2)
Conversion by holders (1)	(3)
Conversion basis	Cash and/or stock
Conversion value in excess of principal	$	—
Maturity date	March 15, 2045
Contractual interest rate	4.25		%
Effective interest rate (4)	9.4		%
Remaining debt discount and debt issuance costs amortization period (5)	23.5 years

(1)Conversion is subject to various limitations and conditions, which have not been met as of the balance sheet date.

(2)Redeemable at any time at a redemption price payable in cash equal to the accreted amount of the $625 million aggregate principal amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date.

(3)Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes,

20

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).

(4)Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

(5)We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity.

Restrictive Debt Covenants

The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit us, our subsidiaries’ and its restricted subsidiaries’ ability to make certain investments or pay dividends or distributions.

As of September 30, 2021, each of our issuers was in compliance with all covenants related to their respective debt agreements.

Interest Expense

Total interest expense, net of capitalized interest, including interest expense related to our convertible notes, consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Interest cost on convertible notes:
Interest per contractual rate	$	6	$	20	$	29	$	140
Amortization of debt discount	1		7		9		41
Amortization of debt issuance costs	—		1		—		8
Total interest cost related to convertible notes	7		28		38		189
Interest cost on debt and finance leases excluding convertible notes	391		388		1,178		1,167
Total interest cost	398		416		1,216		1,356
Capitalized interest	(34)		(61)		(128)		(182)
Total interest expense, net of capitalized interest	$	364	$	355	$	1,088	$	1,174

Fair Value Disclosures

The following table shows the carrying amount and estimated fair value of our debt (in millions):

	September 30, 2021				December 31, 2020
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior notes — Level 2 (1)	$	25,978	$	28,565	$	24,700	$	27,897
Senior notes — Level 3 (2)	2,771		3,317		2,771		3,423
Credit facilities — Level 3 (3)	1,761		1,761		2,915		2,915
2021 Cheniere Convertible Notes — Level 3 (2)	—		—		476		480
2045 Cheniere Convertible Senior Notes — Level 1 (4)	625		538		625		496

(1)The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.

(2)The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 

21

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

(3)The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

(4)The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

NOTE 10—LEASES

Our leased assets consist primarily of LNG vessel time charters (“vessel charters”) and additionally include tug vessels, office space and facilities and land sites. All of our leases are classified as operating leases except for our tug vessels supporting the Corpus Christi LNG Terminal, which are classified as finance leases.

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):

		September 30,		December 31,
	Consolidated Balance Sheets Location	2021		2020
Right-of-use assets—Operating	Operating lease assets	$	2,064	$	759
Right-of-use assets—Financing	Property, plant and equipment, net of accumulated depreciation	51		53
Total right-of-use assets		$	2,115	$	812
Current operating lease liabilities	Current operating lease liabilities	$	458	$	161
Current finance lease liabilities	Other current liabilities	2		2
Non-current operating lease liabilities	Operating lease liabilities	1,590		597
Non-current finance lease liabilities	Finance lease liabilities	57		57
Total lease liabilities		$	2,107	$	817

The following table shows the classification and location of our lease costs on our Consolidated Statements of Operations (in millions):

	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Operating lease cost (a)	Operating costs and expenses (1)	$	145	$	77	$	441	$	316
Finance lease cost:
Amortization of right-of-use assets	Depreciation and amortization expense	—		—		2		2
Interest on lease liabilities	Interest expense, net of capitalized interest	2		2		7		7
Total lease cost		$	147	$	79	$	450	$	325
(a) Included in operating lease cost:
Short-term lease costs		$	22	$	9	$	103	$	60
Variable lease costs		7		3		20		12

(1)Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

22

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Future annual minimum lease payments for operating and finance leases as of September 30, 2021 are as follows (in millions): 

Years Ending December 31,	Operating Leases (1)		Finance Leases
2021	$	139	$	3
2022	515		10
2023	479		10
2024	433		10
2025	243		10
Thereafter	510		127
Total lease payments	2,319		170
Less: Interest	(271)		(111)
Present value of lease liabilities	$	2,048	$	59

(1)Does not include $758 million of legally binding minimum lease payments primarily for vessel charters which were executed as of September 30, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to seven years.

The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases:

	September 30, 2021		December 31, 2020
	Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	5.9	16.9	8.2	17.7
Weighted-average discount rate (1)	3.6%	16.2%	5.4%	16.2%

(1)The finance leases commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

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

	Nine Months Ended September 30,
	2021		2020
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows used in operating leases	$	331	$	226
Operating cash flows used in finance leases	7		8
Right-of-use assets obtained in exchange for operating lease liabilities	1,575		412

LNG Vessel Subcharters

From time to time, we sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. As of both September 30, 2021 and December 31, 2020, we had no future minimum sublease payments to be received from LNG vessel subcharters. The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Fixed income	$	17	$	9	$	28	$	61
Variable income	15		1		21		24
Total sublease income	$	32	$	10	$	49	$	85

23

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 11—REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
LNG revenues (1)	$	4,169	$	1,344	$	10,505	$	6,088
Regasification revenues	68		67		202		202
Other revenues	22		10		66		48
Total revenues from customers	4,259		1,421		10,773		6,338
Net derivative gain (loss) (2)	(1,091)		29		(1,515)		148
Other (3)	32		10		49		85
Total revenues	$	3,200	$	1,460	$	9,307	$	6,571

(1)LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2021 and 2020 excluded zero and $458 million, respectively, and LNG revenues during the nine months ended September 30, 2021 and 2020 excluded $38 million and zero, respectively, that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

(2)See Note 6—Derivative Instruments for additional information about our derivatives.

(3)Includes revenues from LNG vessel subcharters. See Note 10—Leases for additional information about our subleases.

Contract Assets and Liabilities

The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Consolidated Balance Sheets (in millions):

	September 30,		December 31,
	2021		2020
Contract assets, net of current expected credit losses	$	123	$	80

Contract assets represent our right to consideration for transferring goods or services to the customer under the terms of a sales contract when the associated consideration is not yet due. Changes in contract assets during the nine months ended September 30, 2021 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due.

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Consolidated Balance Sheets (in millions):

	Nine Months Ended September 30, 2021
Deferred revenue, beginning of period	$	138
Cash received but not yet recognized in revenue	196
Revenue recognized from prior period deferral	(138)
Deferred revenue, end of period	$	196

24

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of September 30, 2021 and December 31, 2020:

	September 30, 2021			December 31, 2020
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues	$	100.6	10	$	102.3	10
Regasification revenues	1.9		4	2.1		5
Total revenues	$	102.5		$	104.4

(1)The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

We have elected the following exemptions which omit certain potential future sources of revenue from the table above:

(1)We omit from the table above all performance obligations that are part of a contract that has an original expected duration of one year or less.

(2)The table above excludes substantially all variable consideration under our SPAs and TUAs. We omit from the table above all variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation when that performance obligation qualifies as a series. The amount of revenue from variable fees that is not included in the transaction price will vary based on the future prices of Henry Hub throughout the contract terms, to the extent customers elect to take delivery of their LNG, and adjustments to the consumer price index. Certain of our contracts contain additional variable consideration based on the outcome of contingent events and the movement of various indexes. We have not included such variable consideration in the transaction price to the extent the consideration is considered constrained due to the uncertainty of ultimate pricing and receipt. Approximately 61% and 37% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2021 and 2020, respectively, and approximately 56% and 35% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2021 and 2020, respectively, were related to variable consideration received from customers. During each of the three and nine months ended September 30, 2021, approximately 5% of our regasification revenues were related to variable consideration received from customers and during each of the three and nine months ended September 30, 2020, approximately 6% of our regasification revenues were related to variable consideration received from customers.

We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching FID on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

NOTE 12—RELATED PARTY TRANSACTIONS

Natural Gas Supply Agreements

SPL and CCL are party to natural gas supply agreements with related parties in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the Liquefaction Projects. These related parties are partially owned by The Blackstone Group Inc., who also partially owns Cheniere Partners’ limited partner interests.

SPL Natural Gas Supply Agreement

The term of the SPL agreement is for five years, which can commence no earlier than November 1, 2021 and no later than November 1, 2022, following the achievement of contractually-defined conditions precedent. As of September 30, 2021

25

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

and December 31, 2020, the notional amount for this agreement was 99 TBtu and 91 TBtu, respectively. As of both September 30, 2021 and December 31, 2020, the agreement had a fair value of zero.

CCL Natural Gas Supply Agreement

The term of the CCL agreement extends through March 2022. Under this agreement, CCL recorded $19 million and $13 million in accrued liabilities, as of September 30, 2021 and December 31, 2020, respectively.

The Liquefaction Supply Derivatives related to this agreement are recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount):

	September 30,		December 31,
	2021		2020
Current derivative assets	$	7	$	3
Derivative assets	10		1
Notional amount (in TBtu)	119		60

We recorded the following amounts on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 related to this agreement (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Cost of sales (a)	$	53	$	29	$	124	$	77
(a) Included in costs of sales:
Liquefaction Supply Derivative gain	$	6	$	(5)	$	13	$	(3)

Natural Gas Transportation and Storage Agreements

SPL is party to various natural gas transportation and storage agreements and CTPL is party to an operational balancing agreement with a related party in the ordinary course of business for the operation of the SPL Project, with initial primary terms of up to 10 years with extension rights. This related party is partially owned by Brookfield Asset Management, Inc., who indirectly acquired a portion of Cheniere Partners’ limited partner interests in September 2020. We recorded operating and maintenance expense of $12 million and $34 million and cost of sales of zero and $1 million during the three and nine months ended September 30, 2021, respectively, and accrued liabilities of $5 million and $4 million as of September 30, 2021 and December 31, 2020, respectively, with this related party.

CCL is party to natural gas transportation agreements with Midship Pipeline Company, LLC (“Midship Pipeline”) in the ordinary course of business for the operation of the CCL Project, for a period of 10 years which began in May 2020. We account for our investment in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline, as an equity method investment. We recorded operating and maintenance expense of $2 million during both the three months ended September 30, 2021 and 2020 and $7 million and $4 million during the nine months ended September 30, 2021 and 2020, respectively. Additionally, we recorded accrued liabilities of $1 million as of both September 30, 2021 and December 31, 2020 with this related party.

Operation and Maintenance Service Agreements

Cheniere LNG O&M Services, LLC (“O&M Services”), our wholly owned subsidiary, provides the development, construction, operation and maintenance services to Midship Pipeline pursuant to agreements in which O&M Services receives an agreed upon fee and reimbursement of costs incurred. O&M Services recorded $2 million in each of the three months ended September 30, 2021 and 2020 and $5 million and $8 million in the nine months ended September 30, 2021 and 2020, respectively, of other revenues and $1 million and $2 million of accounts receivable as of September 30, 2021 and December 31, 2020, respectively, for services provided to Midship Pipeline under these agreements.

26

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 13—INCOME TAXES

We recorded an income tax benefit of $1,860 million and $1,864 million during the three and nine months ended September 30, 2021, respectively, and an income tax benefit of $75 million and income tax provision of $119 million during the three and nine months ended September 30, 2020, respectively.

The effective tax rates for the three and nine months ended September 30, 2021 were 67.0% and 79.7%, respectively. Our effective tax rate is based on income (loss) before income taxes and non-controlling interest and is significantly impacted by non-controlling interest that is not taxable to Cheniere. Our effective tax rate experienced volatility during the three and nine months ended September 30, 2021 due to variability in our earnings and the proportion of such earnings attributable to non-controlling interest. The variability in earnings in the three and nine months ended September 30, 2021 were mainly the result of approximately $3.5 billion and $4.2 billion, respectively, of pre-tax derivative losses, primarily on our commodity derivatives as a result of unfavorable shifts in international forward commodity curves.

The effective tax rates for the three and nine months ended September 30, 2020 were 12.9% and 19.3%, respectively, which were lower than the 21% federal statutory tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere, and in the nine months ended September 30, 2020, it was partially offset by a $38 million discrete tax expense related to an internal restructuring.

NOTE 14—SHARE-BASED COMPENSATION

We have granted restricted stock shares, restricted stock units, performance stock units and phantom units to employees and non-employee directors under the 2011 Incentive Plan, as amended (the “2011 Plan”) and the 2020 Incentive Plan (the “2020 Plan”). For the nine months ended September 30, 2021, we granted 1.6 million restricted stock units and 0.3 million performance stock units at target performance under the 2020 Plan to certain employees. Additionally, 0.2 million incremental shares of our common stock were issued based on performance results from previously-granted performance stock unit awards.

Restricted stock units are stock awards that vest over a service period of three years and entitle the holder to receive shares of our common stock upon vesting, subject to restrictions on transfer and to a risk of forfeiture if the recipient terminates employment with us prior to the lapse of the restrictions. Performance stock units provide for cliff vesting after a period of three years with payouts based on metrics dependent upon market and performance achieved over the defined performance period compared to pre-established performance targets. The settlement amounts of the awards are based on market and performance metrics which include cumulative distributable cash flow per share, and in certain circumstances, absolute total shareholder return (“ATSR”) of our common stock. Where applicable, the compensation for performance stock units is based on fair value assigned to the market metric of ATSR using a Monte Carlo model upon grant, which remains constant through the vesting period, and a performance metric, which will vary due to changing estimates regarding the expected achievement of the performance metric of cumulative distributable cash flow per share. The number of shares that may be earned at the end of the vesting period ranges from 0% up to 300% of the target award amount. Both restricted stock units and performance stock units will be settled in Cheniere common stock (on a one-for-one basis) and are classified as equity awards, however, a portion of the performance stock units granted in 2021 will partially settle in cash, subject to individual limits. The portion of performance stock units expected to settle in Cheniere common stock (on a one-for-one basis) are classified as equity awards and the portion of performance stock units expected to settle in cash are classified as liability awards.

Total share-based compensation consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Share-based compensation costs, pre-tax:
Equity awards	$	28	$	26	$	92	$	86
Liability awards	1		1		3		2
Total share-based compensation	29		27		95		88
Capitalized share-based compensation	(1)		—		(4)		(4)
Total share-based compensation expense	$	28	$	27	$	91	$	84
Tax benefit associated with share-based compensation expense	$	3	$	2	$	30	$	21

27

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 15—NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

Basic net income (loss) per share attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS reflects potential dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued. The dilutive effect of unvested stock is calculated using the treasury-stock method and the dilutive effect of convertible securities is calculated using the if-converted method.

The following table reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net income (loss) attributable to common stockholders	$	(1,084)	$	(463)	$	(1,020)	$	109
Weighted average common shares outstanding:
Basic	253.6		252.2		253.3		252.5
Dilutive unvested stock	—		—		—		0.7
Diluted	253.6		252.2		253.3		253.2
Net income (loss) per share attributable to common stockholders—basic and diluted	$	(4.27)	$	(1.84)	$	(4.03)	$	0.43

Potentially dilutive securities that were not included in the diluted net income (loss) per share computations because their effects would have been anti-dilutive were as follows (in millions):

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021	2020	2021	2020
Unvested stock (1)	1.8	3.1	1.6	2.4
2045 Cheniere Convertible Senior Notes	4.5	4.5	4.5	4.5
Total potentially dilutive common shares	6.3	7.6	6.1	6.9

(1)Includes the impact of unvested shares containing performance conditions to the extent that the underlying performance conditions are satisfied based on actual results as of the respective dates.

NOTE 16—STOCKHOLDERS’ EQUITY

Share Repurchase Programs

On June 3, 2019, we announced that our Board of Directors (the “Board”) authorized a three-year, $1.0 billion share repurchase program. On September 7, 2021, the Board authorized an increase in the share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. The following table presents information with respect to repurchases of common stock during the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Aggregate common stock repurchased	0.1		—		0.1		2.9
Weighted average price paid per share	$	83.97	$	—	$	83.97	$	53.88
Total amount paid	$	6	$	—	$	6	$	155

As of September 30, 2021, we had up to $589 million of the share repurchase program available, which increased to $1.0 billion as of October 1, 2021.

28

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Dividends

On September 7, 2021, we declared a quarterly dividend of $0.33 per share that is payable on November 17, 2021 to shareholders of record as of November 3, 2021. As of September 30, 2021, we had $85 million accrued related to this obligation, which is included in accrued liabilities and other non-current liabilities in our Consolidated Balance Sheets.

NOTE 17—CUSTOMER CONCENTRATION

The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with accounts receivable, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total accounts receivable, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively:

	Percentage of Total Revenues from External Customers				Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers
	Three Months Ended September 30,		Nine Months Ended September 30,		September 30,	December 31,
	2021	2020	2021	2020	2021	2020
Customer A	12%	*	14%	13%	*	14%
Customer B	15%	11%	13%	10%	*	12%
Customer C	11%	15%	11%	11%	*	*
Customer D	11%	13%	*	10%	*	*
Customer E	*	*	*	*	17%	*
Customer F	*	*	*	*	12%	*

* Less than 10%

NOTE 18—SUPPLEMENTAL CASH FLOW INFORMATION

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

	Nine Months Ended September 30,
	2021		2020
Cash paid during the period for interest on debt, net of amounts capitalized	$	902	$	977
Cash paid for income taxes, net of refunds	2		2
Non-cash investing and financing activities:
Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	234		262
Accrued and declared dividends on common stock	85		—

29

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

Information Regarding Forward-Looking Statements

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical or present facts or conditions, included herein or incorporated herein by reference are “forward-looking statements.” Included among “forward-looking statements” are, among other things: 

•statements that we expect to commence or complete construction of our proposed LNG terminals, liquefaction facilities, pipeline facilities or other projects, or any expansions or portions thereof, by certain dates, or at all;

•statements regarding future levels of domestic and international natural gas production, supply or consumption or future levels of LNG imports into or exports from North America and other countries worldwide or purchases of natural gas, regardless of the source of such information, or the transportation or other infrastructure or demand for and prices related to natural gas, LNG or other hydrocarbon products;

•statements regarding any financing transactions or arrangements, or our ability to enter into such transactions;

•statements relating to Cheniere’s capital deployment, including intent, ability, extent, and timing of capital expenditures, debt repayment, dividends, and share repurchases;

•statements relating to the construction of our Trains and pipelines, including statements concerning the engagement of any EPC contractor or other contractor and the anticipated terms and provisions of any agreement with any EPC or other contractor, and anticipated costs related thereto;

•statements regarding any SPA or other agreement to be entered into or performed substantially in the future, including any revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification, natural gas liquefaction or storage capacities that are, or may become, subject to contracts;

•statements regarding counterparties to our commercial contracts, construction contracts and other contracts;

•statements regarding our planned development and construction of additional Trains or pipelines, including the financing of such Trains or pipelines;

•statements that our Trains, when completed, will have certain characteristics, including amounts of liquefaction capacities;

•statements regarding our business strategy, our strengths, our business and operation plans or any other plans, forecasts, projections, or objectives, including anticipated revenues, capital expenditures, maintenance and operating costs and cash flows, any or all of which are subject to change;

•statements regarding legislative, governmental, regulatory, administrative or other public body actions, approvals, requirements, permits, applications, filings, investigations, proceedings or decisions;

•statements regarding our anticipated LNG and natural gas marketing activities;

•statements regarding the outbreak of COVID-19 and its impact on our business and operating results, including any customers not taking delivery of LNG cargoes, the ongoing credit worthiness of our contractual counterparties, any disruptions in our operations or construction of our Trains and the health and safety of our employees, and on our customers, the global economy and the demand for LNG; and

•any other statements that relate to non-historical or future information.

All of these types of statements, other than statements of historical or present facts or conditions, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “achieve,” “anticipate,” “believe,” “contemplate,” “continue,” “estimate,” “expect,” “intend,” “plan,” “potential,” “predict,” “project,” “pursue,” “target,” the negative of such terms or other comparable terminology. The forward-looking statements contained in this quarterly report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market

30

conditions and other factors. Although we believe that such estimates are reasonable, they are inherently uncertain and involve a number of risks and uncertainties beyond our control. In addition, assumptions may prove to be inaccurate. We caution that the forward-looking statements contained in this quarterly report are not guarantees of future performance and that such statements may not be realized or the forward-looking statements or events may not occur. Actual results may differ materially from those anticipated or implied in forward-looking statements as a result of a variety of factors described in this quarterly report and in the other reports and other information that we file with the SEC, including those discussed under “Risk Factors” in our annual report on Form 10-K for the fiscal year ended December 31, 2020. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. These forward-looking statements speak only as of the date made, and other than as required by law, we undertake no obligation to update or revise any forward-looking statement or provide reasons why actual results may differ, whether as a result of new information, future events or otherwise.

Introduction

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

•Overview of Business 

•Overview of Significant Events 

•Results of Operations 

•Liquidity and Capital Resources

•Off-Balance Sheet Arrangements  

•Summary of Critical Accounting Estimates 

•Recent Accounting Standards

Overview of Business

Cheniere, a Delaware corporation, is a Houston-based energy infrastructure company primarily engaged in LNG-related businesses. We provide clean, secure and affordable LNG to integrated energy companies, utilities and energy trading companies around the world. We aspire to conduct our business in a safe and responsible manner, delivering a reliable, competitive and integrated source of LNG to our customers.

We own and operate the Sabine Pass LNG terminal in Louisiana, one of the largest LNG production facilities in the world, through our ownership interest in and management agreements with Cheniere Partners, which is a publicly traded limited partnership that we created in 2007. As of September 30, 2021, we owned 100% of the general partner interest and 48.6% of the limited partner interest in Cheniere Partners. We also own and operate the Corpus Christi LNG terminal in Texas, which is wholly owned by us.

Cheniere Partners owns the Sabine Pass LNG terminal located in Cameron Parish, Louisiana, which has natural gas liquefaction facilities consisting of five operational natural gas liquefaction Trains and one additional Train that is undergoing commissioning and expected to be substantially completed in the first quarter of 2022, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG terminal also has operational regasification facilities that include five LNG storage tanks with aggregate capacity of approximately 17 Bcfe, two existing marine berths and one under construction that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4 Bcf/d. Cheniere Partners also owns a 94-mile pipeline through its subsidiary, CTPL, that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines.

We also own the Corpus Christi LNG terminal near Corpus Christi, Texas, and currently operate three Trains for a total production capacity of approximately 15 mtpa of LNG. Additionally, we operate a 23-mile natural gas supply pipeline that interconnects the Corpus Christi LNG terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Trains, the “CCL Project”) through our subsidiaries CCL and CCP, respectively, as part of the

31

CCH Group. The CCL Project also contains three LNG storage tanks with aggregate capacity of approximately 10 Bcfe and two marine berths that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) through our subsidiary CCL Stage III for up to seven midscale Trains with an expected total production capacity of approximately 10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and operate the expansion project. CCL Stage III has entered into various IPM gas supply agreements.

We have contracted our production capacity under SPAs, in which the customers are generally required to pay a fixed fee with respect to the contracted volumes irrespective of their election to cancel or suspend deliveries of LNG cargoes, and under IPM gas supply agreements, in which the gas producer sells gas on a global LNG index price, less a fixed liquefaction fee, shipping and other costs. We have contracted approximately 90% of the total production capacity from the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”), including those executed to support Corpus Christi Stage 3. Substantially all of our contracted capacity is from contracts with terms exceeding 10 years. Excluding contracts with terms less than 10 years, our SPAs and IPM gas supply agreements had approximately 17.5 years of weighted average remaining life as of September 30, 2021.

We remain focused on operational excellence and customer satisfaction. Increasing demand for LNG has allowed us to expand our liquefaction infrastructure in a financially disciplined manner. We have increased available liquefaction capacity at our Liquefaction Projects as a result of debottlenecking and other optimization projects. We hold significant land positions at both the Sabine Pass LNG terminal and the Corpus Christi LNG terminal which provide opportunity for further liquefaction capacity expansion. The development of these sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we can make a final investment decision (“FID”).

Additionally, we are committed to the responsible and proactive management of our most important environmental, social and governance (“ESG”) impacts, risks and opportunities. We published our 2020 Corporate Responsibility (“CR”) report, which details our strategy and progress on ESG issues, as well as our efforts on integrating climate considerations into our business strategy and taking a leadership position on increased environmental transparency, including conducting a climate scenario analysis and our plan to provide LNG customers with Cargo Emission Tags. In August 2021, we also announced a peer-reviewed LNG life cycle assessment study which allows for improved greenhouse gas emissions assessment, which was published in the American Chemical Society Sustainable Chemistry & Engineering Journal. Our CR report is available at cheniere.com/IMPACT. Information on our website, including the CR report, is not incorporated by reference into this Quarterly Report on Form 10-Q.

Overview of Significant Events

Our significant events since January 1, 2021 and through the filing date of this Form 10-Q include the following:

Strategic

•In September 2021, our Board of Directors approved a long-term capital allocation plan which includes (i) the repurchase, repayment or retirement of approximately $1.0 billion of existing indebtedness of the Company each year through 2024 with the intent of achieving consolidated investment grade credit metrics, (ii) initiation of a quarterly dividend for third quarter 2021 at $0.33 per share, payable November 17, 2021 to shareholders of record as of November 3, 2021 and (iii) the authorization of an increase in the share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for a three-year term effective October 1, 2021.

•In July 2021, CCL Stage III entered into an IPM gas supply agreement with Tourmaline Oil Marketing Corp. to purchase 140,000 MMBtu per day of natural gas at a price based on the Platts Japan Korea Marker (“JKM”), for a term of approximately 15 years beginning in early 2023.

32

•In July 2021, the board of directors of the Company (the “Board”) appointed Mses. Patricia K. Collawn and Lorraine Mitchelmore to serve as members of the Board. Ms. Collawn was appointed to the Audit Committee and the Compensation Committee of the Board, and Ms. Mitchelmore was appointed to the Audit Committee and the Governance and Nominating Committee of the Board.

•Our subsidiaries entered into SPAs with multiple counterparties for portfolio volumes aggregating approximately 34 million tonnes of LNG to be delivered between 2021 and 2035, inclusive of long-term SPAs entered into with ENN LNG (Singapore) Pte Ltd. and a subsidiary of Glencore plc.

Operational

•As of October 31, 2021, over 1,800 cumulative LNG cargoes totaling over 135 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Projects.

•In September 2021, feed gas was introduced to Train 6 of the SPL Project.

•On March 26, 2021, substantial completion of Train 3 of the CCL Project was achieved.

Financial

•We completed the following financing transactions:

◦In October 2021, we amended and restated our $1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”) to, among other things, (1) extend the maturity through October 2026, (2) reduce the interest rate and commitment fees, which can be further reduced based on our credit ratings and may be positively or negatively adjusted up to five basis points on the interest rate and up to one basis point on the commitment fees based on the achievement of defined ESG milestones and (3) make certain other changes to the terms and conditions of the existing revolving credit facility.

◦In September 2021, Cheniere Partners issued an aggregate principal amount of $1.2 billion of 3.25% Senior Notes due 2032 (the “2032 CQP Senior Notes”). Net proceeds of the 2032 CQP Senior Notes were used to redeem a portion of the outstanding $1.1 billion aggregate principal amount of the 5.625% Senior Notes due 2026 (the “2026 CQP Senior Notes”) in September 2021 pursuant to a tender offer. In October 2021, the remaining net proceeds of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 6.25% Senior Secured Notes due 2022 (the “2022 SPL Senior Notes”).

◦In August 2021, CCH issued an aggregate principal amount of $750 million of fully amortizing 2.742% Senior Secured Notes due 2039 (the “2.742% CCH Senior Secured Notes”). The net proceeds of the 2.742% CCH Senior Secured Notes were used to prepay a portion of the principal amount outstanding under CCH’s amended and restated term loan credit facility (the “CCH Credit Facility”).

◦During 2021, SPL entered into a series of note purchase agreements for the sale of approximately $482 million aggregate principal amount of Senior Secured Notes due 2037, on a private placement basis (the “2037 SPL Private Placement Senior Secured Notes”). The 2037 SPL Private Placement Senior Secured Notes are expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, and the net proceeds will be used to redeem a portion of the 2022 SPL Senior Notes and pay related fees, costs and expenses. The 2037 SPL Private Placement Senior Secured Notes will be fully amortizing, with a weighted average life of over 10 years and a weighted average interest rate of 3.07%.

◦In March 2021, Cheniere Partners issued an aggregate principal amount of approximately $1.5 billion of 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”). The net proceeds of the 2031 CQP Senior Notes, along with cash on hand, were used to redeem the 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) and to pay fees and expenses in connection with the redemption.

•In July 2021, share repurchase activities recommenced pursuant to the June 2019 repurchase plan, with 77,100 shares repurchased during the third quarter.

•In line with our capital allocation plan, we have repaid $750 million of debt with available cash during the nine months ended September 30, 2021 as follows: (1) fully repaid $148 million of total outstanding indebtedness under Cheniere’s term loan facility (the “Cheniere Term Loan Facility”) and $476 million of Cheniere’s 4.875% convertible notes due May 2021 (“2021 Cheniere Convertible Notes”) with $500 million of available cash and the remainder from

33

borrowings under the Cheniere Revolving Credit Facility, (2) $134 million repayment of the Cheniere Revolving Credit Facility with available cash and (3) $116 million repayment of the CCH Credit Facility with available cash.

•In April 2021, S&P Global Ratings changed the outlook of Cheniere and Cheniere Partners’ ratings to positive from negative.

•In February 2021, Fitch Ratings (“Fitch”) changed the outlook of SPL’s senior secured notes rating to positive from stable and the outlook of Cheniere Partners’ long-term issuer default rating and senior unsecured notes rating to positive from stable.

•In January 2021, the term commenced on Cheniere Marketing International LLP’s 25 year SPA with CPC Corporation, Taiwan.

Results of Operations

The following charts summarize the total revenues and total LNG volumes loaded from our Liquefaction Projects (including both operational and commissioning volumes) during the nine months ended September 30, 2021 and 2020:

The following table summarizes the volumes of operational and commissioning LNG cargoes that were loaded from the Liquefaction Projects, which were recognized on our Consolidated Financial Statements during the three and nine months ended September 30, 2021:

	Three Months Ended September 30, 2021		Nine Months Ended September 30, 2021
(in TBtu)	Operational	Commissioning	Operational	Commissioning
Volumes loaded during the current period	500	—	1,447	28
Volumes loaded during the prior period but recognized during the current period	23	—	26	3
Less: volumes loaded during the current period and in transit at the end of the period	(34)	—	(34)	—
Total volumes recognized in the current period	489	—	1,439	31

34

Net income (loss) attributable to common stockholders

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions, except per share data)	2021		2020		Change		2021		2020		Change
Net income (loss) attributable to common stockholders	$	(1,084)	$	(463)	$	(621)	$	(1,020)	$	109	$	(1,129)
Net income (loss) per share attributable to common stockholders—basic and diluted	(4.27)		(1.84)		(2.43)		(4.03)		0.43		(4.46)

Net income attributable to common stockholders decreased by $621 million and $1.1 billion during the three and nine months ended September 30, 2021, respectively, from the comparable periods in 2020, primarily due to the increase in derivative losses from changes in fair value and settlements of $3.4 billion and $4.5 billion (pre-tax and excluding the impact of non-controlling interest) between the three and nine months periods, respectively, as further described below. This impact was partially offset by increased volume and revenue per MMBtu of LNG delivered of $1.3 billion and $2.2 billion (pre-tax and excluding the impact of non-controlling interest) during the three and nine months ended September 30, 2021, respectively, from the comparable periods in 2020, as well as the volatility in our effective tax rate during the three and nine months ended September 30, 2021 due to variability in our earnings and the proportion of such earnings attributable to non-controlling interest.

Substantially all after-tax derivative losses relate to the use of commodity derivative instruments, principally those indexed to international LNG prices. While operationally we utilize commodity derivatives to mitigate price volatility for commodities procured or sold over a period of time, as a result of significant appreciation in forward international LNG commodity curves during the three and nine months ended September 30, 2021, we recognized $3.2 billion and $4.0 billion, respectively, of non-cash unfavorable changes in fair value attributed to positions indexed to such prices (pre-tax and excluding the impact of non-controlling interest), including our IPM gas supply agreements and certain physical and financial derivatives entered into economically hedge exposure to commodity markets in which we have contractual agreements to purchase or sell physical LNG.

Derivative instruments, which in addition to managing exposure to commodity-related marketing and price risks are utilized to manage exposure to changing interest rates and foreign exchange volatility, are reported at fair value on our Consolidated Financial Statements. In some cases, the underlying transactions being economically hedged are accounted for under the accrual method of accounting, whereby revenues and expenses are recognized only upon delivery, receipt or realization of the underlying transaction. Because the recognition of derivative instruments at fair value has the effect of recognizing gains or losses relating to future period exposure, and given the significant volumes, long-term duration and volatility in price basis for certain of our derivative contracts, use of derivative instruments may result in continued volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant factors, notwithstanding the operational intent to mitigate risk exposure over time.

Revenues

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2021		2020		Change		2021		2020		Change
LNG revenues	$	3,078	$	1,373	$	1,705	$	8,990	$	6,236	$	2,754
Regasification revenues	68		67		1		202		202		—
Other revenues	54		20		34		115		133		(18)
Total revenues	$	3,200	$	1,460	$	1,740	$	9,307	$	6,571	$	2,736

Total revenues increased during the three and nine months ended September 30, 2021 from the comparable periods in 2020, primarily as a result of increased revenues per MMBtu and higher volume of LNG delivered between the periods due to the non-recurrence of notification by our customers to not take delivery of scheduled LNG during the three and nine months ended September 30, 2021. Revenues per MMBtu of LNG was higher due to improved market prices recognized by our integrated marketing function and as a result of variable fees that are received in addition to fixed fees when the customers take delivery of the cargo as opposed to exercising their contractual right to not take delivery. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG

35

revenues during the three months ended September 30, 2020 and nine months ended September 30, 2021 excluded $458 million and $38 million, respectively, that would have otherwise been recognized during the quarter if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021.

Prior to substantial completion of a Train, amounts received from the sale of commissioning cargoes from that Train are offset against LNG terminal construction-in-process, because these amounts are earned or loaded during the testing phase for the construction of that Train. During the nine months ended September 30, 2021, we realized offsets to LNG terminal costs of $227 million, corresponding to 31 TBtu, respectively, that were related to the sale of commissioning cargoes from Train 3 of the CCL Project. We did not realize any offsets to LNG terminal costs during the three months ended September 30, 2021 and three and nine months ended September 30, 2020.

Also included in LNG revenues are sales of certain unutilized natural gas procured for the liquefaction process and other revenues, which was $94 million and $243 million during the three months ended September 30, 2021 and 2020, respectively, and $241 million and $397 million during the nine months ended September 30, 2021 and 2020, respectively. Additionally, LNG revenues include gains and losses from derivative instruments, which include the realized value associated with a portion of derivative instruments that settle through physical delivery. We recognized revenues (offsets to revenues) of $(1,092) million and $29 million during the three months ended September 30, 2021 and 2020, respectively, and $(1,515) million and $148 million during the nine months ended September 30, 2021 and 2020, respectively, related to the gains and losses from derivative instruments due to shifts in forward commodity curves.

We expect our LNG revenues to increase in the future upon Train 6 of the SPL Project becoming operational, which is expected in the first quarter of 2022.

The following table presents the components of LNG revenues and the corresponding LNG volumes delivered:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
LNG revenues (in millions):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	$	2,887	$	780	$	7,688	$	3,931
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	1,075		65		2,277		540
LNG procured from third parties	115		85		300		288
LNG revenues associated with cargoes not delivered per customer notification (2)	—		171		—		932
Net derivative gains (losses)	(1,092)		29		(1,515)		148
Other revenues	93		243		240		397
Total LNG revenues	$	3,078	$	1,373	$	8,990	$	6,236
Volumes delivered as LNG revenues (in TBtu):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	386		145		1,170		764
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	103		23		269		168
LNG procured from third parties	10		31		38		79
Total volumes delivered as LNG revenues	499		199		1,477		1,011

(1)Long-term agreements include agreements with an initial tenure of 12 months or more.

(2)LNG revenues include revenues with no corresponding volumes due to revenues attributable to LNG cargoes for which customers notified us that they would not take delivery.

36

Operating costs and expenses

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2021		2020		Change		2021		2020		Change
Cost of sales	$	4,868	$	768	$	4,100	$	8,408	$	2,295	$	6,113
Operating and maintenance expense	350		317		33		1,057		988		69
Development expense	2		—		2		5		5		—
Selling, general and administrative expense	70		70		—		224		224		—
Depreciation and amortization expense	259		233		26		753		699		54
Impairment expense and loss on disposal of assets	1		—		1		—		5		(5)
Total operating costs and expenses	$	5,550	$	1,388	$	4,162	$	10,447	$	4,216	$	6,231

Our total operating costs and expenses increased during the three and nine months ended September 30, 2021 from the comparable periods in 2020, primarily as a result of increased cost of sales.

Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Projects, to the extent those costs are not utilized for the commissioning process. Cost of sales increased during the three and nine months ended September 30, 2021 from the comparable 2020 periods, primarily due to increased pricing of natural gas feedstock as a result of higher US natural gas prices and increased volume of LNG delivered, as well as unfavorable changes in our commodity derivatives to secure natural gas feedstock for the Liquefaction Projects driven by unfavorable shifts in international forward commodity curves. Cost of sales also includes costs associated with the sale of certain unutilized natural gas procured for the liquefaction process and a portion of derivative instruments that settle through physical delivery, port and canal fees, variable transportation and storage costs, net of margins from the sale of natural gas procured for the liquefaction process and other costs to convert natural gas into LNG.

We expect our operating costs and expenses to generally increase in the future upon Train 6 of the SPL Project achieving substantial completion in the first quarter of 2022, although we expect certain costs will not proportionally increase with the number of operational Trains as cost efficiencies will be realized.

Other expense

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2021		2020		Change		2021		2020		Change
Interest expense, net of capitalized interest	$	364	$	355	$	9	$	1,088	$	1,174	$	(86)
Loss on modification or extinguishment of debt	36		171		(135)		95		215		(120)
Interest rate derivative loss, net	2		—		2		3		233		(230)
Other expense, net	24		129		(105)		14		115		(101)
Total other expense	$	426	$	655	$	(229)	$	1,200	$	1,737	$	(537)

Interest expense, net of capitalized interest, increased during the three months ended September 30, 2021 from the comparable 2020 period primarily due to the completion of construction of the final Train of the CCL Project in March 2021, which eliminated the portion of total interest costs that was eligible for capitalization. Interest expense, net of capitalized interest, decreased during the nine months ended September 30, 2021 from the comparable 2020 period as a result of lower interest costs as a result of refinancing higher cost debt and repayment of debt in accordance with our capital allocation plan, partially offset by the portion of total interest costs that was eligible for capitalization. During the three months ended September 30, 2021 and 2020, we incurred $398 million and $416 million of total interest cost, respectively, of which we capitalized $34 million and $61 million, respectively, which was primarily related to interest costs incurred for the construction of the Liquefaction Projects. During the nine months ended September 30, 2021 and 2020, we incurred $1,216 million and $1,356 million of total interest cost, respectively, of which we capitalized $128 million and $182 million, respectively, which was primarily related to interest costs incurred for the construction of the Liquefaction Projects.

37

Loss on modification or extinguishment of debt decreased during the three and nine months ended September 30, 2021 from the respective comparable periods in 2020 due to a lower amount of senior notes and convertible notes repaid or redeemed between the periods, as well as a lower amount of borrowings prepaid under our credit facilities, as further described in Liquidity and Capital Resources—Sources and Uses of Cash—Proceeds from Issuances of Debt, Repayments of Debt, Debt Issuance and Other Financing Costs and Debt Modification or Extinguishment Costs.

Interest rate derivative loss, net decreased during the nine months ended September 30, 2021 compared to the comparable 2020 period, primarily due to a favorable shift in the long-term forward LIBOR curve between the periods and the settlement of certain outstanding derivatives in August 2020 that were in an unfavorable position.

Other expense, net decreased during the three and nine months ended September 30, 2021 compared to the three and nine months ended September 30, 2020 primarily due to lower other-than-temporary impairment losses related to our investment in Midship Holdings that were recognized between the periods.

Income tax provision (benefit)

	Three Months Ended September 30,								Nine Months Ended September 30,
(in millions)	2021			2020			Change		2021			2020			Change
Income (loss) before income taxes and non-controlling interest	$	(2,776)		$	(583)		$	(2,193)	$	(2,340)		$	618		$	(2,958)
Income tax provision (benefit)	(1,860)			(75)			(1,785)		(1,864)			119			(1,983)
Effective tax rate	67.0		%	12.9		%			79.7		%	19.3		%

The effective tax rates for the three and nine months ended September 30, 2021 were 67.0% and 79.7%, respectively. Our effective tax rate is based on income (loss) before income taxes and non-controlling interest and is significantly impacted by non-controlling interest that is not taxable to Cheniere. Our effective tax rate experienced volatility during the three and nine months ended September 30, 2021 due to variability in our earnings and the proportion of such earnings attributable to non-controlling interest. The variability in earnings in the three and nine months ended September 30, 2021 were mainly the result of approximately $3.5 billion and $4.2 billion, respectively, of pre-tax derivative losses, primarily on our commodity derivatives as a result of unfavorable shifts in international forward commodity curves.

The effective tax rates for the three and nine months ended September 30, 2020 were 12.9% and 19.3%, respectively, which were lower than the 21% federal statutory tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere, and in the nine months ended September 30, 2020, it was partially offset by a $38 million discrete tax expense related to an internal restructuring.

Net income (loss) attributable to non-controlling interest

	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2021		2020		Change		2021		2020		Change
Net income (loss) attributable to non-controlling interest	$	168	$	(45)	$	213	$	544	$	390	$	154

Net income attributable to non-controlling interest increased during the three and nine months ended September 30, 2021 from the three and nine months ended September 30, 2020 primarily due to an increase in consolidated net income recognized by Cheniere Partners, which increased from a net loss of $67 million in the three months ended September 30, 2020 to net income of $381 million in the three months ended September 30, 2021 and increased from net income of $774 million in the nine months ended September 30, 2020 to $1,123 million in the nine months ended September 30, 2021.

38

Liquidity and Capital Resources

Although results are consolidated for financial reporting, SPL, Cheniere Partners, CCH Group and Cheniere operate with independent capital structures. Our capital requirements include capital and investment expenditures, repayment of long-term debt and repurchase of our shares. We expect the cash needs for at least the next twelve months will be met for each of these independent capital structures as follows:

•SPL through operating cash flows, project debt and borrowings and equity contributions from Cheniere Partners;

•Cheniere Partners through operating cash flows from SPLNG, SPL and CTPL, debt or equity offerings and borrowings;

•CCH Group through operating cash flows from CCL and CCP, project debt and borrowings and equity contributions from Cheniere; and

•Cheniere through existing unrestricted cash, debt and equity offerings by us or our subsidiaries, operating cash flows, borrowings, services fees from our subsidiaries and distributions from our investment in Cheniere Partners.

The following table provides a summary of our liquidity position at September 30, 2021 and December 31, 2020 (in millions):

	September 30,		December 31,
	2021		2020
Cash and cash equivalents (1)	$	2,203	$	1,628
Restricted cash designated for the following purposes:
SPL Project	133		97
CCL Project	59		70
Other	227		282
Available commitments under the following credit facilities:
$1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”)	804		787
CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”)	750		750
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)	840		767
Cheniere Revolving Credit Facility	1,250		1,126
Cheniere Term Loan Facility	—		372

(1)Amounts presented include balances held by our consolidated variable interest entity, Cheniere Partners, as discussed in Note 7—Non-controlling Interest and Variable Interest Entity of our Notes to Consolidated Financial Statements. As of both September 30, 2021 and December 31, 2020, assets of Cheniere Partners, which are included in our Consolidated Balance Sheets, included $1.7 billion of cash and cash equivalents.

39

Sabine Pass LNG Terminal

Liquefaction Facilities

The SPL Project is one of the largest LNG production facilities in the world. Through Cheniere Partners, we are currently operating five Trains and two marine berths at the SPL Project, undergoing commissioning of one additional Train that is expected to be substantially completed in the first quarter of 2022 and constructing a third marine berth. We have achieved substantial completion of the first five Trains of the SPL Project and commenced commercial operating activities for each Train at various times starting in May 2016. The following table summarizes the project completion and construction status of Train 6 of the SPL Project as of September 30, 2021:

	SPL Train 6
Overall project completion percentage	97.1%
Completion percentage of:
Engineering	100.0%
Procurement	100.0%
Subcontract work	95.8%
Construction	92.9%
Date of expected substantial completion	1Q 2022

We received approval from FERC to site, construct and operate up to a combined total equivalent of approximately 1,661.94 Bcf/yr (approximately 33 mtpa) of natural gas from the SPL Project. The DOE has has issued multiple orders authorizing the export of domestically produced LNG by vessel from the Sabine Pass LNG terminal through December 31, 2050 to FTA countries and non-FTA countries for 1,509.3 Bcf/yr (approximately 30 mtpa) of natural gas, and an additional 152.64 Bcf/yr (approximately 3 mtpa) of natural gas to FTA countries only, with the authorization for the additional volume to non-FTA countries pending.

In December 2020, the DOE announced a new policy in which it would no longer issue short-term export authorizations separately from long-term authorizations. Accordingly, the DOE amended each of SPL’s long-term authorizations to include short-term export authority, and vacated the short-term orders.

Customers

SPL has entered into fixed price long-term SPAs with third-parties, generally with terms of 20 years (plus extension rights) and with a weighted average remaining contract length of approximately 16 years (plus extension rights) for Trains 1 through 6 of the SPL Project. Under these SPAs, the customers will purchase LNG from SPL for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG generally equal to approximately 115% of Henry Hub. The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under SPL’s SPAs. We refer to the fee component that is applicable only in connection with LNG cargo deliveries as the variable fee component of the price under SPL’s SPAs. The variable fees under SPL’s SPAs were generally sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation and liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery of a specified Train.

In aggregate, the annual fixed fee portion to be paid by the third-party SPA customers is approximately $2.9 billion for Trains 1 through 5. After giving effect to an SPA that Cheniere has committed to provide to SPL and upon the date of first commercial delivery of Train 6, the annual fixed fee portion to be paid by the third-party SPA customers is expected to increase to at least $3.3 billion.

In addition, Cheniere Marketing has an agreement with SPL to purchase, at Cheniere Marketing’s option, any LNG produced by SPL in excess of that required for other customers. See Marketing section for additional information regarding agreements entered into by Cheniere Marketing.

40

Natural Gas Transportation, Storage and Supply

To ensure SPL is able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, it has entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL and third-party pipeline companies. SPL has entered into firm storage services agreements with third parties to assist in managing variability in natural gas needs for the SPL Project. SPL has also entered into enabling agreements and long-term natural gas supply contracts with third parties in order to secure natural gas feedstock for the SPL Project. As of September 30, 2021, SPL had secured up to approximately 5,033 TBtu of natural gas feedstock through long-term and short-term natural gas supply contracts with remaining terms that range up to 10 years, a portion of which is subject to conditions precedent.

Construction

SPL entered into lump sum turnkey contracts with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for the engineering, procurement and construction of Trains 1 through 6 of the SPL Project, under which Bechtel charges a lump sum for all work performed and generally bears project cost, schedule and performance risks unless certain specified events occur, in which case Bechtel may cause SPL to enter into a change order, or SPL agrees with Bechtel to a change order.

The total contract price of the EPC contract for Train 6 of the SPL Project is approximately $2.5 billion, including estimated costs for the third marine berth that is currently under construction. As of September 30, 2021, we have incurred $2.2 billion under this contract.

Regasification Facilities

The Sabine Pass LNG terminal has operational regasification capacity of approximately 4 Bcf/d and aggregate LNG storage capacity of approximately 17 Bcfe. Approximately 2 Bcf/d of the regasification capacity at the Sabine Pass LNG terminal has been reserved under two long-term third-party TUAs, under which SPLNG’s customers are required to pay fixed monthly fees, whether or not they use the LNG terminal.  Each of TotalEnergies Gas & Power North America, Inc. (“Total”) and Chevron U.S.A. Inc. (“Chevron”) has reserved approximately 1 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually, prior to inflation adjustments, for 20 years that commenced in 2009. Total S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions, and Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.

The remaining approximately 2 Bcf/d of capacity has been reserved under a TUA by SPL. SPL is obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million annually, prior to inflation adjustments, continuing until at least May 2036. SPL entered into a partial TUA assignment agreement with Total, whereby upon substantial completion of Train 5 of the SPL Project, SPL gained access to substantially all of Total’s capacity and other services provided under Total’s TUA with SPLNG. This agreement provides SPL with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to provide increased flexibility in managing LNG cargo loading and unloading activity, permit SPL to more flexibly manage its LNG storage capacity and accommodate the development of Train 6. Notwithstanding any arrangements between Total and SPL, payments required to be made by Total to SPLNG will continue to be made by Total to SPLNG in accordance with its TUA. During each of the three months ended September 30, 2021 and 2020, SPL recorded $32 million as operating and maintenance expense under this partial TUA assignment agreement. During each of the nine months ended September 30, 2021 and 2020, SPL recorded $97 million, as operating and maintenance expense under this partial TUA assignment agreement.

Under each of these TUAs, SPLNG is entitled to retain 2% of the LNG delivered to the Sabine Pass LNG terminal.

Capital Resources

We currently expect that SPL’s capital resources requirements with respect to the SPL Project will be financed through cash flows under the SPAs, project debt and borrowings and equity contributions from Cheniere Partners. We believe that with the net proceeds of borrowings, available commitments under the 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities, cash flows from operations and equity contributions from Cheniere Partners, SPL will have adequate financial resources available to meet its currently anticipated capital, operating and debt service requirements with respect to Trains 1 through 6 of the SPL Project. Additionally, SPLNG generates cash flows from the TUAs, as discussed above.

41

The following table provides a summary of our capital resources from borrowings and available commitments for the Sabine Pass LNG terminal, excluding equity contributions to our subsidiaries and cash flows from operations (as described in Sources and Uses of Cash), at September 30, 2021 and December 31, 2020 (in millions):

	September 30,		December 31,
	2021		2020
Senior notes (1)	$	18,278	$	17,750
Letters of credit issued (2)	396		413
Available commitments under credit facilities (2)	1,554		1,537
Total capital resources from borrowings and available commitments (3)	$	20,228	$	19,700

(1)Includes SPL’s 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 (collectively, the “SPL Senior Notes”), as well as Cheniere Partners’ 3.250% to 5.625% senior notes due between October 2025 and January 2032 (collectively, the “CQP Senior Notes”).

(2)Consists of 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities.

(3)Does not include equity contributions that may be available from Cheniere’s borrowings and available cash and cash equivalents.

SPL Senior Notes

The SPL Senior Notes are governed by a common indenture (the “SPL Indenture”) and the terms of the 5.00% Senior Secured Notes due 2037 (the “2037 SPL Senior Notes”) are governed by a separate indenture (the “2037 SPL Senior Notes Indenture”). Both the SPL Indenture and the 2037 SPL Senior Notes Indenture contain terms and events of default and certain covenants that, among other things, limit SPL’s ability and the ability of SPL’s restricted subsidiaries to incur additional indebtedness or issue preferred stock, make certain investments or pay dividends or distributions on capital stock or subordinated indebtedness or purchase, redeem or retire capital stock, sell or transfer assets, including capital stock of SPL’s restricted subsidiaries, restrict dividends or other payments by restricted subsidiaries, incur liens, enter into transactions with affiliates, dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of SPL’s assets and enter into certain LNG sales contracts. Subject to permitted liens, the SPL Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in SPL and substantially all of SPL’s assets. SPL may not make any distributions until, among other requirements, deposits are made into debt service reserve accounts as required and a debt service coverage ratio test of 1.25:1.00 is satisfied.

At any time prior to six months before the respective dates of maturity for each series of the SPL Senior Notes (except for the 2022 SPL Senior Notes, 5.625% Senior Secured Notes due 2023 (the “2023 SPL Senior Notes”), 5.75% Senior Secured Notes due 2024 (the “2024 SPL Senior Notes”) and 5.625% Senior Notes due 2025 (the “2025 SPL Senior Notes”), in which case the time period is three months before the respective dates of maturity), SPL may redeem all or part of such series of the SPL Senior Notes at a redemption price equal to the ‘make-whole’ price (except for the 2037 SPL Senior Notes, in which case the redemption price is equal to the “optional redemption” price) set forth in the respective indentures governing the SPL Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. SPL may also, at any time within six months of the respective maturity dates for each series of the SPL Senior Notes (except for the 2022 SPL Senior Notes, 2023 SPL Senior Notes, 2024 SPL Senior Notes and 2025 SPL Senior Notes, in which case the time period is within three months of the respective dates of maturity), redeem all or part of such series of the SPL Senior Notes at a redemption price equal to 100% of the principal amount of such series of the SPL Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

SPL may incur additional indebtedness in the future, including by issuing additional notes, and such indebtedness could be at higher interest rates and have different maturity dates and more restrictive covenants than the current outstanding indebtedness of SPL, including the SPL Senior Notes and the 2020 SPL Working Capital Facility. Semi-annual principal payments for the 2037 SPL Senior Notes are due on March 15 and September 15 of each year beginning September 15, 2025 and are fully amortizing according to a fixed sculpted amortization schedule.

During 2021, SPL entered into a series of note purchase agreements for the sale of approximately $482 million aggregate principal amount of the 2037 SPL Private Placement Senior Secured Notes on a private placement basis. The 2037 SPL Private Placement Senior Secured Notes are expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, and the net proceeds will be used to strategically refinance a portion of the 2022 SPL Senior Notes and pay related

42

fees, costs and expenses. The 2037 SPL Private Placement Senior Secured Notes will be fully amortizing, with a weighted average life of over 10 years and a weighted average interest rate of 3.07%.

2020 SPL Working Capital Facility

In March 2020, SPL entered into the 2020 SPL Working Capital Facility with aggregate commitments of $1.2 billion, which replaced the $1.2 billion Amended and Restated SPL Working Capital Facility (the “2015 SPL Working Capital Facility”). The 2020 SPL Working Capital Facility is intended to be used for loans to SPL, swing line loans to SPL and the issuance of letters of credit on behalf of SPL, primarily for (1) the refinancing of the 2015 SPL Working Capital Facility, (2) fees and expenses related to the 2020 SPL Working Capital Facility, (3) SPL and its future subsidiaries’ gas purchase obligations and (4) SPL and certain of its future subsidiaries’ general corporate purposes. SPL may, from time to time, request increases in the commitments under the 2020 SPL Working Capital Facility of up to $800 million. As of September 30, 2021 and December 31, 2020, SPL had $804 million and $787 million of available commitments and $396 million and $413 million aggregate amount of issued letters of credit, respectively. As of both September 30, 2021 and December 31, 2020, SPL had no outstanding borrowings under the 2020 SPL Working Capital Facility.

The 2020 SPL Working Capital Facility matures on March 19, 2025, but may be extended with consent of the lenders. The 2020 SPL Working Capital Facility provides for mandatory prepayments under customary circumstances.

The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, satisfaction of a 12-month forward-looking and backward-looking 1.25:1.00 debt service reserve ratio test. The obligations of SPL under the 2020 SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as a pledge of all of the membership interests in SPL and certain future subsidiaries of SPL on a pari passu basis by a first priority lien with the SPL Senior Notes.

Cheniere Partners

CQP Senior Notes

The CQP Senior Notes are jointly and severally guaranteed by each of Cheniere Partners’ subsidiaries other than SPL and, subject to certain conditions governing its guarantee, Sabine Pass LP (each a “Guarantor” and collectively, the “CQP Guarantors”). The CQP Senior Notes are governed by the same base indenture (the “CQP Base Indenture”). The 4.500% Senior Notes due 2029 (the “2029 CQP Senior Notes”) are further governed by the Third Supplemental Indenture, the 2031 CQP Senior Notes are further governed by the Fifth Supplemental Indenture and the 2032 CQP Senior Notes are further governed by the Sixth Supplemental Indenture. The indentures governing the CQP Senior Notes contain terms and events of default and certain covenants that, among other things, limit the ability of Cheniere Partners and the CQP Guarantors to incur liens and sell assets, enter into transactions with affiliates, enter into sale-leaseback transactions and consolidate, merge or sell, lease or otherwise dispose of all or substantially all of the applicable entity’s properties or assets.

At any time prior to October 1, 2024 for the 2029 CQP Senior Notes, March 1, 2026 for the 2031 CQP Senior Notes and January 31, 2027 for the 2032 CQP Senior Notes, Cheniere Partners may redeem all or a part of the applicable CQP Senior Notes at a redemption price equal to 100% of the aggregate principal amount of the CQP Senior Notes redeemed, plus the “applicable premium” set forth in the respective indentures governing the CQP Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. In addition, at any time prior to October 1, 2024 for the 2029 CQP Senior Notes, March 1, 2024 for the 2031 CQP Senior Notes and January 31, 2025 for the 2032 CQP Senior Notes, Cheniere Partners may redeem up to 35%, and in the case of the 2032 CQP Senior Notes, up to 40%, of the aggregate principal amount of the CQP Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 104.5% of the aggregate principal amount of the 2029 CQP Senior Notes, 104.000% of the aggregate principal amount of the 2031 CQP Senior Notes and 103.250% of the aggregate principal amount of the 2032 CQP Senior Notes redeemed, plus accrued and unpaid interest, if any, to the date of redemption. Cheniere Partners also may at any time on or after October 1, 2024 through the maturity date of October 1, 2029 for the 2029 CQP Senior Notes, March 1, 2026 through the maturity date of March 1, 2031 for the 2031 CQP Senior Notes and January 31, 2027 through maturity date of January 31, 2032 for the 2032 CQP Senior Notes, redeem the CQP Senior Notes, in whole or in part, at the redemption prices set forth in the respective indentures governing the CQP Senior Notes.

43

The CQP Senior Notes are Cheniere Partners’ senior obligations, ranking equally in right of payment with Cheniere Partners’ other existing and future unsubordinated debt and senior to any of its future subordinated debt. In the event that the aggregate amount of Cheniere Partners’ secured indebtedness and the secured indebtedness of the CQP Guarantors (other than the CQP Senior Notes or any other series of notes issued under the CQP Base Indenture) outstanding at any one time exceeds the greater of (1) $1.5 billion and (2) 10% of net tangible assets, the CQP Senior Notes will be secured to the same extent as such obligations under the 2019 CQP Credit Facilities. The obligations under the 2019 CQP Credit Facilities are secured on a first-priority basis (subject to permitted encumbrances) with liens on substantially all the existing and future tangible and intangible assets and rights of Cheniere Partners and the CQP Guarantors and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities). The liens securing the CQP Senior Notes, if applicable, will be shared equally and ratably (subject to permitted liens) with the holders of other senior secured obligations, which include the 2019 CQP Credit Facilities obligations and any future additional senior secured debt obligations.

2019 CQP Credit Facilities

Cheniere Partners has a $750 million revolving credit facility under the 2019 CQP Credit Facilities. Borrowings under the 2019 CQP Credit Facilities are being used to fund the development and construction of Train 6 of the SPL Project and for general corporate purposes, subject to a sublimit, and the 2019 CQP Credit Facilities are also available for the issuance of letters of credit. As of both September 30, 2021 and December 31, 2020, Cheniere Partners had $750 million of available commitments and no letters of credit issued or loans outstanding under the 2019 CQP Credit Facilities.

The 2019 CQP Credit Facilities mature on May 29, 2024. Any outstanding balance may be repaid, in whole or in part, at any time without premium or penalty, except for interest rate breakage costs. The 2019 CQP Credit Facilities contain conditions precedent for extensions of credit, as well as customary affirmative and negative covenants, and limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions are satisfied.

The 2019 CQP Credit Facilities are unconditionally guaranteed and secured by a first priority lien (subject to permitted encumbrances) on substantially all of Cheniere Partners’ and the CQP Guarantors’ existing and future tangible and intangible assets and rights and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities).

Corpus Christi LNG Terminal

Liquefaction Facilities

We are currently operating three Trains and two marine berths at the CCL Project. We completed construction of Trains 1, 2 and 3 of the CCL Project and commenced commercial operating activities in February 2019, August 2019 and March 2021, respectively. We received approval from FERC to site, construct and operate up to a combined total equivalent of approximately 875.16 Bcf/yr (approximately 17 mtpa) of natural gas from the CCL Project.

Separate from the CCH Group, we are also developing Corpus Christi Stage 3 through our subsidiary CCL Stage III, adjacent to the CCL Project. We received approval from FERC in November 2019 to site, construct and operate seven midscale Trains with an expected total production capacity of up to approximately 11.45 mtpa of LNG.

The following orders have been issued by the DOE authorizing the export of domestically produced LNG by vessel from the Corpus Christi LNG terminal:

•CCL Project—FTA countries and non-FTA countries through December 31, 2050, up to a combined total equivalent of approximately 767 Bcf/yr (approximately 15 mtpa) of natural gas, and an additional 108.16 Bcf/yr (approximately 2 mtpa) to FTA countries only, with the authorization for the additional volume to non-FTA countries pending.

•Corpus Christi Stage 3—FTA countries and non-FTA countries through December 31, 2050 in an amount equivalent to approximately 582.14 Bcf/yr (approximately 11 mtpa) of natural gas.

44

In December 2020, the DOE announced a new policy in which it would no longer issue short-term export authorizations separately from long-term authorizations. Accordingly, the DOE amended each of CCL’s long-term authorizations to include short-term export authority, and vacated the short-term orders.

Customers

CCL has entered into fixed price long-term SPAs with third-parties, generally with terms of 20 years (plus extension rights) and with a weighted average remaining contract length of approximately 18 years (plus extension rights) for Trains 1 through 3 of the CCL Project. Under these SPAs, the customers will purchase LNG from CCL on a free on board (“FOB”) basis for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG equal to approximately 115% of Henry Hub. The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under our SPAs. We refer to the fee component that is applicable only in connection with LNG cargo deliveries as the variable fee component of the price under our SPAs. The variable fee under CCL’s SPAs entered into in connection with the development of the CCL Project was sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation and liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery for the applicable Train, as specified in each SPA.

In aggregate, the minimum annual fixed fee portion to be paid by the third-party SPA customers is approximately $1.8 billion for Trains 1 through 3.

In addition, Cheniere Marketing has agreements with CCL to purchase: (1) approximately 15 TBtu per annum of LNG with a term through 2043, (2) any LNG produced by CCL in excess of that required for other customers at Cheniere Marketing’s option and (3) approximately 44 TBtu of LNG with a maximum term up to 2026 associated with the IPM gas supply agreement between CCL and EOG Resources, Inc. See Marketing section for additional information regarding agreements entered into by Cheniere Marketing.

Natural Gas Transportation, Storage and Supply

To ensure CCL is able to transport adequate natural gas feedstock to the Corpus Christi LNG terminal, it has entered into transportation precedent agreements to secure firm pipeline transportation capacity with CCP and certain third-party pipeline companies. CCL has entered into a firm storage services agreement with a third party to assist in managing variability in natural gas needs for the CCL Project. CCL has also entered into enabling agreements and long-term natural gas supply contracts with third parties, and will continue to enter into such agreements, in order to secure natural gas feedstock for the CCL Project. As of September 30, 2021, CCL had secured up to approximately 2,798 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to 10 years, a portion of which is subject to the achievement of certain project milestones and other conditions precedent.

CCL Stage III has also entered into long-term natural gas supply contracts with third parties, and anticipates continuing to enter into such agreements, in order to secure natural gas feedstock for Corpus Christi Stage 3. As of September 30, 2021, CCL Stage III had secured up to approximately 3,128 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to approximately 15 years, which is subject to the achievement of certain project milestones and other conditions precedent.

A portion of the natural gas feedstock transactions for CCL and CCL Stage III are IPM transactions, in which the natural gas producers are paid based on a global gas market price less a fixed liquefaction fee and certain costs incurred by us.

45

Construction

CCL entered into separate lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of Trains 1 through 3 of the CCL Project under which Bechtel charged a lump sum for all work performed and generally bore project cost, schedule and performance risks unless certain specified events occurred, in which case Bechtel may have caused CCL to enter into a change order, or CCL agreed with Bechtel to a change order.

Final Investment Decision for Corpus Christi Stage 3

FID for Corpus Christi Stage 3 will be subject to, among other things, entering into an EPC contract, obtaining additional commercial support for the project and securing the necessary financing arrangements.

Pipeline Facilities

In November 2019, the FERC authorized CCP to construct and operate the pipeline for Corpus Christi Stage 3. The pipeline will be designed to transport 1.5 Bcf/d of natural gas feedstock required by Corpus Christi Stage 3 from the existing regional natural gas pipeline grid.

Capital Resources

The following table provides a summary of the capital resources of the CCH Group from borrowings and available commitments for the CCL Project, excluding equity contributions from Cheniere, at September 30, 2021 and December 31, 2020 (in millions):

	September 30,		December 31,
	2021		2020
Senior notes (1)	$	8,471	$	7,721
Credit facilities outstanding balance (2)	1,761		2,767
Letters of credit issued (2)	360		293
Available commitments under credit facilities (2)	840		767
Total capital resources from borrowings and available commitments (3)	$	11,432	$	11,548

(1)Includes CCH’s 2.742% to 7.000% senior secured notes due between June 2024 and December 2039 (collectively, the “CCH Senior Notes”).

(2)Includes the CCH Credit Facility and the CCH Working Capital Facility.

(3)Does not include equity contributions that may be available from Cheniere’s borrowings and available cash and cash equivalents.

CCH Senior Notes

The CCH Senior Notes are jointly and severally guaranteed by CCH’s subsidiaries, CCL, CCP and Corpus Christi Pipeline GP, LLC (each a “CCH Guarantor” and collectively, the “CCH Guarantors”). The indentures governing the CCH Senior Notes contain customary terms and events of default and certain covenants that, among other things, limit CCH’s ability and the ability of CCH’s restricted subsidiaries to: incur additional indebtedness or issue preferred stock; make certain investments or pay dividends or distributions on membership interests or subordinated indebtedness or purchase, redeem or retire membership interests; sell or transfer assets, including membership or partnership interests of CCH’s restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries to CCH or any of CCH’s restricted subsidiaries; incur liens; enter into transactions with affiliates; dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of the properties or assets of CCH and its restricted subsidiaries taken as a whole; or permit any CCH Guarantor to dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of its properties and assets. The covenants included in the respective indentures that govern the CCH Senior Notes are subject to a number of important limitations and exceptions.

The CCH Senior Notes are CCH’s senior secured obligations, ranking senior in right of payment to any and all of CCH’s future indebtedness that is subordinated to the CCH Senior Notes and equal in right of payment with CCH’s other existing and future indebtedness that is senior and secured by the same collateral securing the CCH Senior Notes. The CCH Senior Notes are secured by a first-priority security interest in substantially all of CCH’s and the CCH Guarantors’ assets.

46

At any time prior to six months before the respective dates of maturity for each of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes at a redemption price equal to the “make-whole” price set forth in the appropriate indenture, plus accrued and unpaid interest, if any, to the date of redemption. At any time within six months of the respective dates of maturity for each of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the CCH Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

CCH Credit Facility

CCH has total commitments under the CCH Credit Facility of $6.1 billion. The obligations of CCH under the CCH Credit Facility are secured by a first priority lien on substantially all of the assets of CCH and its subsidiaries and by a pledge by Cheniere CCH Holdco I, LLC of its limited liability company interests in CCH. As of both September 30, 2021 and December 31, 2020, CCH had no available commitments and $1.8 billion and $2.6 billion, respectively, of loans outstanding under the CCH Credit Facility.

The CCH Credit Facility matures on June 30, 2024, with principal payments due quarterly commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following the completion of the CCL Project as defined in the common terms agreement and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train of the CCL Project to become operational is entitled to terminate its SPA for failure to achieve the date of first commercial delivery for that agreement. Scheduled repayments will be based upon a 19-year tailored amortization, commencing the first full quarter after the completion of Trains 1 through 3 and designed to achieve a minimum projected fixed debt service coverage ratio of 1.50:1.

Under the CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt. CCH is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, the completion of the construction of Trains 1 through 3 of the CCL Project, funding of a debt service reserve account equal to six months of debt service and achieving a historical debt service coverage ratio and fixed projected debt service coverage ratio of at least 1.25:1.00.

CCH Working Capital Facility

CCH has total commitments under the CCH Working Capital Facility of $1.2 billion. The CCH Working Capital Facility is intended to be used for loans to CCH (“CCH Working Capital Loans”) and the issuance of letters of credit on behalf of CCH for certain working capital requirements related to developing and operating the CCL Project and for related business purposes. Loans under the CCH Working Capital Facility are guaranteed by the CCH Guarantors. CCH may, from time to time, request increases in the commitments under the CCH Working Capital Facility of up to the maximum allowed for working capital under the Common Terms Agreement that was entered into concurrently with the CCH Credit Facility. As of September 30, 2021 and December 31, 2020, CCH had $840 million and $767 million of available commitments, zero and $140 million of loans outstanding and $360 million and $293 million aggregate amount of issued letters of credit under the CCH Working Capital Facility as of September 30, 2021 and December 31, 2020, respectively.

The CCH Working Capital Facility matures on June 29, 2023, and CCH may prepay the CCH Working Capital Loans and loans made in connection with a draw upon any letter of credit (“CCH LC Loans”) at any time without premium or penalty upon three business days’ notice and may re-borrow at any time. CCH LC Loans have a term of up to one year. CCH is required to reduce the aggregate outstanding principal amount of all CCH Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The CCH Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of CCH under the CCH Working Capital Facility are secured by substantially all of the assets of CCH and the CCH Guarantors as well as all of the membership interests in CCH and each of the CCH Guarantors on a pari passu basis with the CCH Senior Notes and the CCH Credit Facility.

47

Cheniere

Senior Notes

We have an aggregate principal amount of $2.0 billion of the 4.625% Senior Secured Notes due 2028 (the “2028 Cheniere Senior Notes”), the proceeds of which were used to prepay a portion of the outstanding indebtedness under the Cheniere Term Loan Facility and to pay related fees and expenses. The associated indentures (“Cheniere Indenture”) contain customary terms and events of default and certain covenants that, among other things, limit our ability to create liens or other encumbrances, enter into sale-leaseback transactions and merge or consolidate with other entities or sell all or substantially all of our assets. The Cheniere Indenture covenants are subject to a number of important limitations and exceptions.

At any time prior to October 15, 2023, we may redeem all or a part of the 2028 Cheniere Senior Notes at a redemption price equal to 100% of the aggregate principal amount thereof, plus the “applicable premium” and accrued and unpaid interest, if any, to but not including the date of redemption. We also may, at any time prior to October 15, 2023, redeem up to 40% of the aggregate principal amount of the 2028 Cheniere Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 104.625% of the aggregate principal amount of the notes being redeemed, plus accrued and unpaid interest, if any, to but not including, the date of redemption. At any time on or after October 15, 2023 through the maturity date of October 15, 2028, we may redeem all or part of the 2028 Cheniere Senior Notes at the redemption prices described in the Cheniere Indenture.

The 2028 Cheniere Senior Notes are our general senior obligations and rank senior in right of payment to all of our future obligations that are, by their terms, expressly subordinated in right of payment to the 2028 Cheniere Senior Notes and equally in right of payment with all of our other existing and future unsubordinated indebtedness. The 2028 Cheniere Senior Notes became unsecured in June 2021 concurrent with the repayment of all outstanding obligations under the Cheniere Term Loan Facility and may, in certain instances become secured in the future in connection with the incurrence of additional secured indebtedness by us. When required, the 2028 Cheniere Senior Notes will be secured on a first-priority basis by a lien on substantially all of our assets and equity interests in our direct subsidiaries (other than certain excluded subsidiaries), which liens rank pari passu with the liens securing the Cheniere Revolving Credit Facility. As of September 30, 2021, the 2028 Cheniere Senior Notes are not guaranteed by any of our subsidiaries. In the future, the 2028 Cheniere Senior Notes will be guaranteed by our subsidiaries who guarantee our other material indebtedness.

Convertible Notes

We have $625 million aggregate principal amount of 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”). We have the right, at our option, at any time after March 15, 2020, to redeem all or any part of the 2045 Cheniere Convertible Senior Notes at a redemption price equal to the accreted amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date. Prior to December 15, 2044, the 2045 Cheniere Convertible Senior Notes are convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes, which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).

We have the option to satisfy the conversion obligation for the 2045 Cheniere Convertible Senior Notes with cash, common stock or a combination thereof.

Cheniere Revolving Credit Facility

We have total commitments under the Cheniere Revolving Credit Facility of $1.25 billion. The Cheniere Revolving Credit Facility is intended to fund, through loans and letters of credit, equity capital contributions to Cheniere CCH Holdco II, LLC (“CCH HoldCo II”) and its subsidiaries for the development of the CCL Project and, provided that certain conditions are met, for general corporate purposes. As of September 30, 2021 and December 31, 2020, we had $1.3 billion and $1.1 billion of available commitments and zero and $124 million aggregate amount of issued letters of credit under the Cheniere Revolving Credit Facility, respectively. We had no loans outstanding under the Cheniere Revolving Credit Facility as of both September 30, 2021 and December 31, 2020.

48

The Cheniere Revolving Credit Facility matures on December 13, 2022 and contains representations, warranties and affirmative and negative covenants customary for companies like us with lenders of the type participating in the Cheniere Revolving Credit Facility that limit our ability to make restricted payments, including distributions, unless certain conditions are satisfied, as well as limitations on indebtedness, guarantees, hedging, liens, investments and affiliate transactions. Under the Cheniere Revolving Credit Facility, we are required to ensure that the sum of our unrestricted cash and the amount of undrawn commitments under the Cheniere Revolving Credit Facility is at least equal to the lesser of (1) 20% of the commitments under the Cheniere Revolving Credit Facility and (2) $200 million (the “Liquidity Covenant”). However, at any time that the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit under the Cheniere Revolving Credit Facility is greater than 30% of aggregate commitments under the Cheniere Revolving Credit Facility, the Liquidity Covenant will not apply and we will instead be governed by a quarterly non-consolidated leverage ratio covenant not to exceed 5.75:1.00 (the “Springing Leverage Covenant”).

The Cheniere Revolving Credit Facility is secured by a first priority security interest (subject to permitted liens and other customary exceptions) in substantially all of our assets, including our interests in our direct subsidiaries (excluding CCH HoldCo II and certain other subsidiaries).

Cash Receipts from Subsidiaries

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. As of September 30, 2021, we owned a 48.6% limited partner interest in Cheniere Partners in the form of 239.9 million common units. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. We are eligible to receive quarterly equity distributions from Cheniere Partners related to our ownership interests and our incentive distribution rights.

We also receive fees for providing management services to some of our subsidiaries. We received $88 million and $83 million in total service fees from these subsidiaries during the nine months ended September 30, 2021 and 2020, respectively.

Capital Allocation Plan

In September 2021, our Board of Directors approved a long-term capital allocation plan which includes (i) repurchase, repayment or retirement of approximately $1.0 billion of existing indebtedness of the Company each year through 2024, (ii) initiation of a quarterly dividend for third quarter 2021 at $0.33 per share, payable November 17, 2021 to shareholders of record as of November, 3, 2021 and (iii) the authorized reset of the share repurchase program, as further explained below.

Share Repurchase Program

On June 3, 2019, we announced that our Board authorized a 3-year, $1.0 billion share repurchase program. On September 7, 2021, the Board authorized an increase in the share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. During the three and nine months ended September 30, 2021, we repurchased an aggregate of 0.1 shares of our common stock for $6 million, for a weighted average price per share of $83.97. During the nine months ended September 30, 2020, we repurchased an aggregate of 2.9 million shares of our common stock for $155 million, for a weighted average price per share of $53.88. As of September 30, 2021, we had up to $589 million of the share repurchase program available, which increased to $1.0 billion as of October 1, 2021. Under the share repurchase program, repurchases can be made from time to time using a variety of methods, which may include open market purchases, privately negotiated transactions or otherwise, all in accordance with the rules of the SEC and other applicable legal requirements. The timing and amount of any shares of our common stock that are repurchased under the share repurchase program will be determined by our management based on market conditions and other factors.  The share repurchase program does not obligate us to acquire any particular amount of common stock, and may be modified, suspended or discontinued at any time or from time to time at our discretion.

Marketing

We market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. We have, and continue to develop, a portfolio of long-, medium- and short-term SPAs to transport and unload commercial LNG cargoes to locations worldwide. These volumes are expected to be primarily sourced by LNG produced by the Liquefaction Projects but supplemented by volumes procured from other locations worldwide, as needed. As of September 30, 2021, we have sold or have options to sell approximately 5,085 TBtu of LNG to be delivered to customers

49

between 2021 and 2045, including volume from an SPA Cheniere Marketing has committed to provide to SPL.  The cargoes have been sold either on a FOB basis (delivered to the customer at the Sabine Pass LNG terminal or the Corpus Christi LNG terminal, as applicable) or a delivered at terminal (“DAT”) basis (delivered to the customer at their specified LNG receiving terminal). We have chartered LNG vessels to be utilized for cargoes sold on a DAT basis.

Cheniere Marketing has uncommitted trade finance facilities with available credit of $124 million as of September 30, 2021, primarily to be used for the purchase and sale of LNG for ultimate resale in the course of its operations. The finance facilities are intended to be used for advances, guarantees or the issuance of letters of credit or standby letters of credit on behalf of Cheniere Marketing. As of September 30, 2021 and December 31, 2020, Cheniere Marketing had $101 million and $34 million, respectively, in standby letters of credit and guarantees outstanding under the finance facilities. As of both September 30, 2021 and December 31, 2020, there were zero loans outstanding under the finance facilities. Cheniere Marketing pays interest or fees on utilized commitments.

Cheniere Marketing also has an uncommitted letter of credit facility with available credit of $35 million as of September 30, 2021, for the issuance of letters of credit in the course of its operations. As of September 30, 2021, Cheniere Marketing had no letters of credit issued under the facility. Cheniere Marketing pays fees on utilized commitments.

Corporate and Other Activities

We are required to maintain corporate and general and administrative functions to serve our business activities described above.  The development of our sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make an FID.

We have made an equity investment in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“the Midship Pipeline”). Midship Pipeline operates an approximately 200-mile natural gas pipeline project (the “Midship Project”) with current capacity of up to 1.1 million Dekatherms per day that connects new gas production in the Anadarko Basin to Gulf Coast markets, including markets serving the Liquefaction Projects. The Midship Project was placed in service in April 2020.

Restrictive Debt Covenants

As of September 30, 2021, each of our issuers was in compliance with all covenants related to their respective debt agreements.

LIBOR

The use of LIBOR is expected to be phased out by June 2023. It is currently unclear whether LIBOR will be utilized beyond that date or whether it will be replaced by a particular rate. We intend to continue working with our lenders and counterparties to pursue any amendments to our debt and derivative agreements that are currently subject to LIBOR following LIBOR cessation and will continue to monitor, assess and plan for the phase out of LIBOR.

50

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash, cash equivalents and restricted cash for the nine months ended September 30, 2021 and 2020 (in millions). The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, which are referred to elsewhere in this report. Additional discussion of these items follows the table. 

	Nine Months Ended September 30,
	2021		2020
Sources of cash, cash equivalents and restricted cash:
Net cash provided by operating activities	$	2,057	$	765
Proceeds from sale of fixed assets	68		—
Proceeds from issuances of debt	4,104		7,683
Other	8		—
	$	6,237	$	8,448
Uses of cash, cash equivalents and restricted cash:
Property, plant and equipment	$	(761)	$	(1,437)
Investment in equity method investment	—		(100)
Repayments of debt	(4,276)		(6,324)
Debt issuance and other financing costs	(38)		(124)
Debt modification or extinguishment costs	(67)		(170)
Distributions to non-controlling interest	(483)		(468)
Payments related to tax withholdings for share-based compensation	(47)		(43)
Repurchase of common stock	(6)		(155)
Other	(14)		(8)
	(5,692)		(8,829)
Net increase (decrease) in cash, cash equivalents and restricted cash	$	545	$	(381)

Operating Cash Flows

Our operating cash net inflows during the nine months ended September 30, 2021 and 2020 were $2,057 million and $765 million, respectively. The $1,292 million increase in operating cash inflows in 2021 compared to 2020 was primarily related to increased cash receipts from the sale of LNG cargoes due to higher revenue per MMBtu and higher volume of LNG delivered, as well as from higher than normal contributions from LNG and natural gas portfolio optimization activities due to significant volatility in LNG and natural gas markets during the nine months ended September 30, 2021. Partially offsetting these operating cash inflows were higher operating cash outflows due to higher natural gas feedstock costs and payment of paid-in-kind interest on our convertible notes.

Proceeds from Sale of Fixed Assets

During the nine months ended September 30, 2021, we received proceeds from the sale of fixed assets of $68 million from divestment of non-core land holdings.

Proceeds from Issuances of Debt, Repayments of Debt, Debt Issuance and Other Financing Costs and Debt Modification or Extinguishment Costs

During the nine months ended September 30, 2021, we issued $3,450 million aggregate principal amount of senior notes and borrowed an aggregate amount of $654 million under our credit facilities. The proceeds from these issuances and borrowings, together with cash on hand, were used to redeem $2,172 million aggregate principal amount of senior notes, repay $476 million of the 2021 Cheniere Convertible Notes and prepay $1,808 million aggregate outstanding borrowings under our credit facilities. We incurred $38 million of debt issuance costs related to these issuances, and incurred $67 million of debt modification or extinguishment costs related to these redemptions and repayments, primarily for the payment of early redemption fees and write off of unamortized issuance costs.

During the nine months ended September 30, 2020, we issued $4,769 million aggregate principal amount of senior notes and borrowed an aggregate amount of $2,919 million under our credit facilities. The proceeds from these issuances and borrowings, together with cash on hand, were used to redeem $2.0 billion aggregate principal amount of 2021 SPL Senior Notes, redeem or repurchase $1,513 million of our convertible notes and prepay $2,811 million aggregate outstanding

51

borrowings under our credit facilities. We incurred $124 million of debt issuance costs related to these issuances and the closing of the 2020 SPL Working Capital Facility, and incurred $170 million of debt modification or extinguishment costs related to these redemptions and repayments, primarily for the payment of early redemption fees and write off of unamortized issuance costs.

Property, Plant and Equipment

Cash outflows for property, plant and equipment were primarily for the construction costs for the Liquefaction Projects. These costs are capitalized as construction-in-process until achievement of substantial completion. Additionally, we purchased land adjacent to the CCL Project for potential future expansion purposes.

Distributions to Non-controlling Interest

We own a 48.6% limited partner interest in Cheniere Partners, with the remaining non-controlling interest held by The Blackstone Group Inc., Brookfield Asset Management Inc. and the public, to whom Cheniere Partners paid distributions during the three and nine months ended September 30, 2021 and 2020.

Repurchase of Common Stock

During the nine months ended September 30, 2021 and 2020, we paid $6 million and $155 million, respectively, to repurchase approximately 0.1 million shares and 2.9 million shares, respectively of our common stock under our share repurchase program.

Off-Balance Sheet Arrangements

As of September 30, 2021, we had no transactions that met the definition of off-balance sheet arrangements that may have a current or future material effect on our consolidated financial position or operating results.

Summary of Critical Accounting Estimates

The preparation of Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

Recent Accounting Standards

For a summary of recently issued accounting standards, see Note 1—Nature of Operations and Basis of Presentation of our Notes to Consolidated Financial Statements.

ITEM 3.    QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Marketing and Trading Commodity Price Risk

We have entered into commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the SPL Project, the CCL Project and potential future development of Corpus Christi Stage 3 (“Liquefaction Supply Derivatives”). We have also entered into physical and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives and the LNG Trading Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location and a 10% change in the commodity price for LNG, respectively, as follows (in millions):

	September 30, 2021				December 31, 2020
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Liquefaction Supply Derivatives	$	(2,629)	$	763	$	240	$	204
LNG Trading Derivatives	(1,113)		168		(134)		44

See Note 6—Derivative Instruments for additional details about our derivative instruments.

52

Interest Rate Risk

We are exposed to interest rate risk primarily when we incur debt related to project financing. Interest rate risk is managed in part by replacing outstanding floating-rate debt with fixed-rate debt with varying maturities. CCH has entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the CCH Credit Facility (“CCH Interest Rate Derivatives”). In order to test the sensitivity of the fair value of the CCH Interest Rate Derivatives to changes in interest rates, management modeled a 10% change in the forward one-month LIBOR curve across the remaining terms of the CCH Interest Rate Derivatives as follows (in millions):

	September 30, 2021				December 31, 2020
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
CCH Interest Rate Derivatives	$	(67)	$	—	$	(140)	$	1

See Note 6—Derivative Instruments for additional details about our derivative instruments.

Foreign Currency Exchange Risk

We have entered into foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with operations in countries outside of the United States (“FX Derivatives”). In order to test the sensitivity of the fair value of the FX Derivatives to changes in FX rates, management modeled a 10% change in FX rate between the U.S. dollar and the applicable foreign currencies as follows (in millions):

	September 30, 2021				December 31, 2020
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
FX Derivatives	$	9	$	1	$	(22)	$	2

See Note 6—Derivative Instruments for additional details about our derivative instruments.

ITEM 4.    CONTROLS AND PROCEDURES

We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures are effective.

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. 

53

PART II.    OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. Other than discussed below, there have been no material changes to the legal proceedings disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

In February 2018, the Pipeline and Hazardous Materials Safety Administration (“PHMSA”) issued a Corrective Action Order (the “CAO”) to SPL in connection with a minor LNG leak from one tank and minor vapor release from a second tank at the Sabine Pass LNG terminal. These two tanks have been taken out of operational service while we conduct analysis, repair and remediation. On April 20, 2018, SPL and PHMSA executed a Consent Agreement and Order (the “Consent Order”) that replaces and supersedes the CAO. On July 9, 2019, PHMSA and FERC issued a joint letter setting out operating conditions required to be met prior to SPL returning the tanks to service. In July 2021, PHMSA issued a Notice of Probable Violation (“NOPV”) and Proposed Civil Penalty to SPL alleging violations of federal pipeline safety regulations relating to the 2018 SPL tank incident and proposing civil penalties totaling $2,214,900. On September 16, 2021, PHMSA issued an Amended NOPV that reduced the proposed penalty to $1,458,200. On October 12, 2021, SPL responded to the Amended NOPV, electing not to contest the alleged violations in the Amended NOPV and electing to pay the proposed reduced penalty. SPL continues to coordinate with PHMSA and FERC to address the matters relating to the February 2018 leak, including repair approach and related analysis. We do not expect that the Consent Order and related analysis, repair and remediation or resolution of the NOPV will have a material adverse impact on our financial results or operations.

ITEM 1A.    RISK FACTORS

There have been no material changes from the risk factors disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

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

Purchase of Equity Securities by the Issuer and Affiliated Purchasers

The following table summarizes stock repurchases for the three months ended September 30, 2021:

Period	Total Number of Shares Purchased (1)	Average Price Paid Per Share (2)	Total Number of Shares Purchased as a Part of Publicly Announced Plans	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (3)
July 1 - 31, 2021	93,008	$85.31	44,100	$592,272,032
August 1 - 31, 2021	32,019	$84.62	30,500	$589,692,332
September 1 - 30, 2021	2,500	$85.43	2,500	$589,478,717
Total	127,527	$85.14	77,100

(1)Includes issued shares surrendered to us by participants in our share-based compensation plans for payment of applicable tax withholdings on the vesting of share-based compensation awards. Associated shares surrendered by participants are repurchased pursuant to terms of the plan and award agreements and not as part of the publicly announced share repurchase plan.

(2)The price paid per share was based on the average trading price of our common stock on the dates on which we repurchased the shares.

(3)On June 3, 2019, we announced that our Board authorized a 3-year, $1.0 billion share repurchase program. On September 7, 2021, the Board authorized an increase in the share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. For additional information, see Share Repurchase Program in Liquidity and Capital Resources.

54

ITEM 6.    EXHIBITS

Exhibit No.	Description
4.1	Fifth Supplemental Indenture, dated as of August 24, 2021, among CCH, as issuer, CCL, CCP and Corpus Christi Pipeline GP, LLC, as guarantors, and The Bank of New York Mellon, as trustee (incorporated by reference to Exhibit 4.1 to CCH’s Current Report on Form 8-K (SEC File No. 333-215435), filed on August 24, 2021)
4.2	Sixth Supplemental Indenture, dated as of September 27, 2021, among Cheniere Partners, the guarantors party thereto and The Bank of New York Mellon, as Trustee under the Indenture (incorporated by reference to Exhibit 4.1 to Cheniere Partners’ Current Report on Form 8-K (SEC File No. 001-33366), filed on September 27, 2021)
10.1*	Change orders to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 4 Liquefaction Facility, dated November 7, 2018, by and between SPL and Bechtel Oil Gas and Chemicals, Inc.: (i) the Change Order CO-00049 COVID-19 Impacts 2Q2021, dated July 6, 2021, (ii) CO-00050 Third Berth Bunkering Ship Modifications — Pre-Investment for Foundations, dated July 6, 2021, (iii) CO-00051 Thermal Oxidizer Controls Change, dated September 8, 2021, (iv) CO-00052 Third Berth Spare Beacon and Additional Cable Tray, dated September 8, 2021 and (v) CO-0053 Train 6 Gearbox Assembly Replacement for Unit 1411, dated September 24, 2021
10.2*	First Amendment to Third Amended and Restated Common Terms Agreement, dated as of July 26, 2021, among SPL, as borrower, the Secured Debt Holder Group Representatives party thereto, the Secured Hedge Representatives party thereto, the Secured Gas Hedge Representatives party thereto and Société Générale, as the Common Security Trustee and the Intercreditor Agent
10.3	Second Employment Agreement Amendment between the Company and Jack A. Fusco, dated August 11, 2021 (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on August 13, 2021)
10.4	Registration Rights Agreement, dated as of August 24, 2021, among CCH and CCL, CCP and Corpus Christi Pipeline GP, LLC, as guarantors, and Morgan Stanley & Co. LLC, for itself and as representative of the purchasers (incorporated by reference to Exhibit 10.1 to CCH’s Current Report on Form 8-K (SEC File No. 333-215435), filed on August 24, 2021)
10.5	Registration Rights Agreement, dated as of September 27, 2021, among Cheniere Partners, the guarantors party thereto and RBC Capital Markets, LLC (incorporated by reference to Exhibit 10.1 to Cheniere Partners’ Current Report on Form 8-K (SEC File No. 001-33366), filed on September 27, 2021)
31.1*	Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
31.2*	Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**	Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**	Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*	XBRL Instance Document
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document
104*	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

*	Filed herewith.
**	Furnished herewith.

55

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. 

		CHENIERE ENERGY, INC.
Date:	November 3, 2021	By:	/s/ Zach Davis
			Zach Davis
			Senior Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)
Date:	November 3, 2021	By:	/s/ Leonard E. Travis
			Leonard E. Travis
			Senior Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

56

EX-10.1

Exhibit 10.1

CHANGE ORDER

COVID-19 Impacts 2Q2021

PROJECT NAME: Sabine Pass LNG Stage 4 Liquefaction Facility OWNER: Sabine Pass Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: November 7, 2018 CHANGE ORDER NUMBER: CO-00049 DATE OF CHANGE ORDER: July 6, 2021

The Agreement between the Parties listed above is changed as follows:

1.Pursuant to Article 6.2 of the Agreement (Change Orders Requested by Contractor), Parties agree this Change Order includes Contractor’s costs for the second quarter of 2021 (“Q2”) (actuals through April 2021 and forecasted costs through June 2021), in response to the novel coronavirus (COVID-19) outbreak event.

This Change Order is based on the following assumptions and qualifications for Q2:

i.Contractor’s Houston home office personnel have worked and shall continue working effectively remotely or in the Houston home office.

ii.Contractor has been able to keep the Jobsite open throughout the event and shall continue doing so, to the extent reasonably possible, to advance the Work at the current rate of progress (or better if possible), with no planned shutdown in Q2.

iii.Contractor shall continue to put forth diligent mitigation efforts to minimize impacts caused by the event to the extent reasonably practical, including but not limited to: increased craft professional hours for additional cleaning, disinfecting, etc.; increased bussing services to support social distancing; additional cleaning stations, waste management services, etc.; quarantine requirements for supplier technical support (international and others); continued COVID-19 testing costs and hours (excluding quarantine time); increased professional staff for contact tracing efforts; and additional safety PPE, communication materials (e.g., posters, signs, etc.).

iv.No major COVID-19 infection outbreak on the Jobsite resulting in: (i) Site shutdown of all or critical scopes of the Work; or (ii) absenteeism at or above the twenty percent (20%) level for a sustained duration of more than four (4) Weeks. Should either of these triggers occur, the Parties shall jointly collaborate on mitigation actions and plans for shutdown accordingly.

v.Existing government (local, state and/or federal) guidelines, executive orders, actions or directives as of 9 March 2021 shall remain unchanged through the end of Q2. New government orders shall be subject to separate notices and Change Orders, if applicable.

vi.Owner’s operations and other professional staff personnel shall continue to support the Contractor’s activities for the Project in support of the Work.

vii.Subcontractors and Suppliers shall continue to provide uninterrupted support for construction activities either at Site or remotely if possible.

viii.Any changes in the above assumptions and qualifications and additional costs beyond Q2 are excluded from this Change Order; and may be part of a separate Change Order in accordance with Article 6.2 of the Agreement.

2.Contractor has not experienced schedule impacts on the critical path of the CPM Schedule through 15 May 2021; and should all the qualifications and assumptions above remain as stated, Contractor does not anticipate any schedule impacts to the Project on the critical path of the CPM Schedule through Q2. In the event of the occurrence of any impacts to the critical path of the CPM Schedule, Contractor shall notify Owner in accordance with Article 6.5 of the Agreement.

3.The detailed cost breakdown of this Change Order is provided in Exhibit A of this Change Order.

4.Schedule C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit B of this Change Order.

Adjustment to Contract Price Applicable to Subproject 6(a)

1.	The original Contract Price Applicable to Subproject 6(a) was	$	2,016,892,573
2.	Net change for Contract Price Applicable to Subproject 6(a) by previously authorized Change Orders (#01-08, 10-13, 15, 17-18, 21-22, 24, 28-29, 31-32, 34-35, 38, 41-42, 45-48)	$	15,549,729
3.	The Contract Price Applicable to Subproject 6(a) prior to this Change Order was	$	2,032,442,302
4.	The Contract Price Applicable to Subproject 6(a) will be increased by this Change Order in the amount of	$	2,256,901
5.	The Provisional Sum Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
6.	The Contract Price Applicable to Subproject 6(a) including this Change Order will be	$	2,034,699,203

Adjustment to Contract Price Applicable to Subproject 6(b)

7.	The original Contract Price Applicable to Subproject 6(b) (in CO-00009) was	$	457,696,000
8.	Net change for Contract Price Applicable to Subproject 6(b) by previously authorized Change Orders (#14, 16, 19-20, 23, 25-27, 30-31, 33, 36-37, 39-40, 43-44)	$	(4,939,146)
9.	The Contract Price Applicable to Subproject 6(b) prior to this Change Order was	$	452,756,854
10.	The Contract Price Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
11.	The Provisional Sum Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
12.	The Contract Price Applicable to Subproject 6(b) including this Change Order will be	$	452,756,854

Adjustment to Contract Price

13.	The original Contract Price for Subproject 6(a) and Subproject 6(b) was (add lines 1 and 7)	$	2,474,588,573
14.	The Contract Price prior to this Change Order was (add lines 3 and 9)	$	2,485,199,156
15.	The Contract Price will be increased by this Change Order in the amount of (add lines 4, 5, 10 and 11)	$	2,256,901
16.	The new Contract Price including this Change Order will be (add lines 14 and 15)	$	2,487,456,057

Adjustment to dates in Project Schedule for Subproject 6(a)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(a):N/A

Adjustment to Payment Schedule for Subproject 6(a): Yes; see Exhibit B of this Change Order.

Adjustment to Minimum Acceptance Criteria for Subproject 6(a):N/A

Adjustment to Performance Guarantees for Subproject 6(a):N/A

Adjustment to Design Basis for Subproject 6(a):N/A

Other adjustments to liability or obligations of Contractor or Owner under the Agreement for Subproject 6(a): N/A

Adjustment to dates in Project Schedule for Subproject 6(b)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(b): N/A

Adjustment to Payment Schedule for Subproject 6(b): N/A

Adjustment to Design Basis for Subproject 6(b):N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials: /s/ KM Contractor /s/ DC Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: _____ Contractor _____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order.Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect.This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ David Craft	/s/ Kane McIntosh
Owner	Contractor
David Craft	Kane McIntosh
Name	Name
SVP E&C	Senior Project Manager
Title	Title
July 12, 2021	July 6, 2021
Date of Signing	Date of Signing

CHANGE ORDER

Third Berth Bunkering Ship Modifications - Pre-Investment for Foundations

PROJECT NAME: Sabine Pass LNG Stage 4 Liquefaction Facility OWNER: Sabine Pass Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: November 7, 2018 CHANGE ORDER NUMBER: CO-00050 DATE OF CHANGE ORDER: July 6, 2021

The Agreement between the Parties listed above is changed as follows:

1.In accordance with Section 6.1 of the Agreement (Change Orders Requested by Owner), and pursuant to Owner’s request via Letter No. SPL4-BE-C20-055, dated 12 November 2020, and Contractor’s Third Berth Bunkering Study Class 3 Estimate provided via Letter No. 26012-100-T21-GAM-00026, dated 2 April 2021, the Parties agree this Change Order includes Contractor’s engineering, procurement and construction costs to proceed with Pre-Investment of Foundations for an additional Gangway Tower, new Hydraulic Power Unit (“HPU”) and Bunker Arm Vapor Line pedestals as further described in Section 5.0 of Contractor’s Third Berth Bunkering Study Report No. 26012-100-G65-GEX-00001, Rev 00A, dated 31 March 2021.

2.The detailed cost breakdown for this Change Order is detailed in Exhibit A of this Change Order.

3.Schedule C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit B of this Change Order.

Adjustment to Contract Price Applicable to Subproject 6(a)

1.	The original Contract Price Applicable to Subproject 6(a) was	$	2,016,892,573
2.	Net change for Contract Price Applicable to Subproject 6(a) by previously authorized Change Orders (#01-08, 10-13, 15, 17-18, 21-22, 24, 28-29, 31-32, 34-35, 38, 41-42, 45-49)	$	17,806,630
3.	The Contract Price Applicable to Subproject 6(a) prior to this Change Order was	$	2,034,699,203
4.	The Contract Price Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
5.	The Provisional Sum Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
6.	The Contract Price Applicable to Subproject 6(a) including this Change Order will be	$	2,034,699,203

Adjustment to Contract Price Applicable to Subproject 6(b)

7.	The original Contract Price Applicable to Subproject 6(b) (in CO-00009) was	$	457,696,000
8.	Net change for Contract Price Applicable to Subproject 6(b) by previously authorized Change Orders (#14, 16, 19-20, 23, & 25-27, 30-31, 33, 36-37, 39-40, 43-44)	$	(4,939,146)
9.	The Contract Price Applicable to Subproject 6(b) prior to this Change Order was	$	452,756,854
10.	The Contract Price Applicable to Subproject 6(b) will be increased by this Change Order	$	371,193
11.	The Provisional Sum Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
12.	The Contract Price Applicable to Subproject 6(b) including this Change Order will be	$	453,128,047

Adjustment to Contract Price

13.	The original Contract Price for Subproject 6(a) and Subproject 6(b) was (add lines 1 and 7)	$	2,474,588,573
14.	The Contract Price prior to this Change Order was (add lines 3 and 9)	$	2,487,456,057
15.	The Contract Price will be increased by this Change Order in the amount of (add lines 4, 5, 10 and 11)	$	371,193
16.	The new Contract Price including this Change Order will be (add lines 14 and 15)	$	2,487,827,250

Adjustment to dates in Project Schedule for Subproject 6(a)

The following dates are modified : N/A

Adjustment to other Changed Criteria for Subproject 6(a): N/A

Adjustment to Payment Schedule for Subproject 6(a): N/A

Adjustment to Minimum Acceptance Criteria for Subproject 6(a):N/A

Adjustment to Performance Guarantees for Subproject 6(a):N/A

Adjustment to Design Basis for Subproject 6(a):N/A

Other adjustments to liability or obligations of Contractor or Owner under the Agreement for Subproject 6(a): N/A

Adjustment to dates in Project Schedule for Subproject 6(b)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(b): N/A

Adjustment to Payment Schedule for Subproject 6(b): Yes; see Exhibit B of this Change Order.

Adjustment to Design Basis for Subproject 6(b):N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials: /s/ KM Contractor /s/ DC Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order.Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect.This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ David Craft	/s/ Kane McIntosh
Owner	Contractor
David Craft	Kane McIntosh
Name	Name
SVP E&C	Senior Project Manager
Title	Title
July 12, 2021	July 6, 2021
Date of Signing	Date of Signing

CHANGE ORDER

Thermal Oxidizer Controls Change

PROJECT NAME: Sabine Pass LNG Stage 4 Liquefaction Facility OWNER: Sabine Pass Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: November 7, 2018 CHANGE ORDER NUMBER: CO-00051 DATE OF CHANGE ORDER: September 8, 2021

The Agreement between the Parties listed above is changed as follows:

1.In accordance with Section 6.1 of the Agreement (Change Orders Requested by Owner), the Parties agree this Change Order includes Contractor's engineering costs to implement two (2) design changes to the Thermal Oxidizer System controls scheme for Train 6 (MOC #M2020778-001 & MOC #M2021544-001).

2.The detailed cost breakdown for this Change Order is detailed in Exhibit A of this Change Order.

3.Schedule C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit B of this Change Order.

Adjustment to Contract Price Applicable to Subproject 6(a)

1.	The original Contract Price Applicable to Subproject 6(a) was	$	2,016,892,573
2.	Net change for Contract Price Applicable to Subproject 6(a) by previously authorized Change Orders (#01-08, 10-13, 15, 17-18, 21-22, 24, 28-29, 31-32, 34-35, 38, 41-42, 45-49)	$	17,806,630
3.	The Contract Price Applicable to Subproject 6(a) prior to this Change Order was	$	2,034,699,203
4.	The Contract Price Applicable to Subproject 6(a) will be increased by this Change Order in the amount of	$	40,306
5.	The Provisional Sum Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
6.	The Contract Price Applicable to Subproject 6(a) including this Change Order will be	$	2,034,739,509

Adjustment to Contract Price Applicable to Subproject 6(b)

7.	The original Contract Price Applicable to Subproject 6(b) (in CO-00009) was	$	457,696,000
8.	Net change for Contract Price Applicable to Subproject 6(b) by previously authorized Change Orders (#14, 16, 19-20, 23, 25-27, 30-31, 33, 36-37, 39-40, 43-44, 50)	$	(4,567,953)
9.	The Contract Price Applicable to Subproject 6(b) prior to this Change Order was	$	453,128,047
10.	The Contract Price Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
11.	The Provisional Sum Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
12.	The Contract Price Applicable to Subproject 6(b) including this Change Order will be	$	453,128,047

Adjustment to Contract Price

13.	The original Contract Price for Subproject 6(a) and Subproject 6(b) was (add lines 1 and 7)	$	2,474,588,573
14.	The Contract Price prior to this Change Order was (add lines 3 and 9)....................................................	$	2,487,827,250
15.	The Contract Price will be increased by this Change Order in the amount of (add lines 4, 5, 10 and 11)	$	40,306
16.	The new Contract Price including this Change Order will be (add lines 14 and 15)................................	$	2,487,867,556

Adjustment to dates in Project Schedule for Subproject 6(a)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(a):N/A

Adjustment to Payment Schedule for Subproject 6(a): Yes; see Exhibit B

Adjustment to Minimum Acceptance Criteria for Subproject 6(a): N/A

Adjustment to Performance Guarantees for Subproject 6(a):N/A

Adjustment to Design Basis for Subproject 6(a):N/A

Other adjustments to liability or obligations of Contractor or Owner under the Agreement for Subproject 6(a): N/A

Adjustment to dates in Project Schedule for Subproject 6(b)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(b): N/A

Adjustment to Payment Schedule for Subproject 6(b): N/A

Adjustment to Design Basis for Subproject 6(b):N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials: /s/ KM Contractor /s/ DC Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ David Craft	/s/ Kane McIntosh
Owner	Contractor
David Craft	Kane McIntosh
Name	Name
SVP E&C	Senior Project Manager
Title	Title
September 16, 2021	September 8, 2021
Date of Signing	Date of Signing

CHANGE ORDER

Third Berth Spare Beacon and Additional Cable Tray

PROJECT NAME: Sabine Pass LNG Stage 4 Liquefaction Facility OWNER: Sabine Pass Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: November 7, 2018 CHANGE ORDER NUMBER: CO-00052 DATE OF CHANGE ORDER: September 8, 2021

The Agreement between the Parties listed above is changed as follows:

1.In accordance with Section 6.1 of the Agreement (Change Orders Requested by Owner), the Parties agree this Change Order includes Contractor’s procurement and construction costs to procure, supply and pre-assemble a spare beacon structure for the Third Berth Project.

2.In accordance with Section 6.1 of the Agreement (Change Orders Requested by Owner), the Parties agree this Change Order includes Contractor’s engineering, procurement, and construction costs to install a new six (6) inch wide cable tray on the existing pipe rack to support installation of the new 5kV cable for the Third Berth Project.

3. The detailed cost breakdown for this Change Order is detailed in Exhibits A.1 and A.2 of this Change Order.

4. Schedule C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit B of this Change Order.

Adjustment to Contract Price Applicable to Subproject 6(a)

1.	The original Contract Price Applicable to Subproject 6(a) was	$	2,016,892,573
2.	Net change for Contract Price Applicable to Subproject 6(a) by previously authorized Change Orders (#01-08, 10-13, 15, 17-18, 21-22, 24, 28-29, 31-32, 34-35, 38, 41-42, 45-49, 51)	$	17,846,936
3.	The Contract Price Applicable to Subproject 6(a) prior to this Change Order was	$	2,034,739,509
4.	The Contract Price Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
5.	The Provisional Sum Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
6.	The Contract Price Applicable to Subproject 6(a) including this Change Order will be	$	2,034,739,509

Adjustment to Contract Price Applicable to Subproject 6(b)

7.	The original Contract Price Applicable to Subproject 6(b) (in CO-00009) was	$	457,696,000
8.	Net change for Contract Price Applicable to Subproject 6(b) by previously authorized Change Orders (#14, 16, 19-20, 23, 25-27, 30-31, 33, 36-37, 39-40, 43-44, 50)	$	(4,567,953)
9.	The Contract Price Applicable to Subproject 6(b) prior to this Change Order was	$	453,128,047
10.	The Contract Price Applicable to Subproject 6(b) will be increased by this Change Order	$	589,417
11.	The Provisional Sum Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
12.	The Contract Price Applicable to Subproject 6(b) including this Change Order will be	$	453,717,464

Adjustment to Contract Price

13.	The original Contract Price for Subproject 6(a) and Subproject 6(b) was (add lines 1 and 7)	$	2,474,588,573
14.	The Contract Price prior to this Change Order was (add lines 3 and 9)....................................................	$	2,487,867,556
15.	The Contract Price will be increased by this Change Order in the amount of (add lines 4, 5, 10 and 11)	$	589,417
16.	The new Contract Price including this Change Order will be (add lines 14 and 15)................................	$	2,488,456,973

Adjustment to dates in Project Schedule for Subproject 6(a)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(a):N/A

Adjustment to Payment Schedule for Subproject 6(a): N/A

Adjustment to Minimum Acceptance Criteria for Subproject 6(a): N/A

Adjustment to Performance Guarantees for Subproject 6(a):N/A

Adjustment to Design Basis for Subproject 6(a):N/A

Other adjustments to liability or obligations of Contractor or Owner under the Agreement for Subproject 6(a): N/A

Adjustment to dates in Project Schedule for Subproject 6(b)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(b): N/A

Adjustment to Payment Schedule for Subproject 6(b): Yes; see Exhibit B of this Change Order.

Adjustment to Design Basis for Subproject 6(b):N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials: /s/ KM Contractor /s/ DC Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ David Craft	/s/ Kane McIntosh
Owner	Contractor
David Craft	Kane McIntosh
Name	Name
SVP E&C	Project Manager
Title	Title
September 16, 2021	September 8, 2021
Date of Signing	Date of Signing

CHANGE ORDER

Train 6 Gearbox Assembly Replacement for Unit 1411

PROJECT NAME: Sabine Pass LNG Stage 4 Liquefaction Facility OWNER: Sabine Pass Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: November 7, 2018 CHANGE ORDER NUMBER: CO-00053 DATE OF CHANGE ORDER: September 24, 2021

The Agreement between the Parties listed above is changed as follows:

1.Contractor acknowledges that one(1) gearbox assembly (identified as "PROPANE COMPRESSOR ASSEMBLY GEARBOX; 46C-1411-GB02 GEARBOX; PN: NF2419E; S/N: YH00156; GE NUOVO PIGNONE/LUFKIN") procured by Contractor for Subproject 6(a), which is part of compressor number 46C-1411 ("Compressor"), requires repair before it can be incorporated into Subproject 6(a) ("Original Gearbox Assembly").

2.Contractor states that the repair of the Original Gearbox Assembly and subsequent installation of the repaired Original Gearbox Assembly into Subproject 6(a) may delay the achievement of Substantial Completion. To mitigate this delay, Contractor has requested Owner provide the following capital spare parts from the Stage 4 Liquefaction Facility: (a) one (1) low speed shaft and gear set, (b) one (1) high speed pinion, and (c) four (4) tilting pad bearings and other various operating spare parts to be installed in the Compressor (subclauses (a), (b), (c) and the operating spare parts together, the "Replacement Parts").

3.Owner has no obligation to provide the Replacement Parts to Contractor. Notwithstanding the foregoing, Owner agrees to make the Replacement Parts available to Contractor for the purpose of Contractor installing such Replacement Parts into Subproject 6(a) (in lieu of installing the Original Gearbox Assembly) based on the conditions stated in this Change Order.

4.Contractor shall, for all Replacement Parts provided by Owner procure for Owner equivalent replacement or refurbished (as needed) parts in condition equivalent to condition of the Replacement Parts and meeting all requirements under the Agreement (including Article 12) ("New Parts") and shall deliver the New Parts to a storage location designated by Owner. Contractor shall use commercially reasonable efforts to make such delivery on or before [28JAN2022] (the "Delivery Date". Contractor shall also provide to Owner a schedule for the procurement and delivery of the New Parts, which schedule shall account for the delivery of all New Parts to Owner on or before the Delivery Date. Once approved in writing by Owner (such approval not to be unreasonably withheld), Contractor shall procure and deliver the New Parts in accordance with such approved schedule. Notwithstanding the foregoing, any written request by Owner Representative to maintain or improve upon such schedule shall be implemented by Contractor unless otherwise agreed in writing between David Craft of Owner and Kane McIntosh of Contractor.

5.Contractor shall bear all costs and expenses in relation to repair, restoration, delivery, transportation, installation, uninstallation, removal, return and storage of, or any other services for, the Original Gearbox Assembly, the Replacement Parts, the New Parts and Contractor's performance of its obligations under this Change Order.

6.In the event Owner sustains a failure of any gearbox comparable to the Original Gearbox Assembly or any spare parts comparable to any Replacement Part currently in operation in the Stage 1 Liquefaction Facility, the Stage 2 Liquefaction Facility or the Stage 3 Liquefaction Facility (each individually, "such other Liquefaction Facility") prior to Owner receiving the New Parts, Contractor shall return and, if applicable, uninstall, the such Replacement Part to Owner for use in such other Liquefaction Facility, and Contractor shall not be entitled to any Change Order under the Agreement in connection with the return and, if applicable, the uninstallation, of the Replacement Parts, including no adjustment to the Guaranteed Substantial Completion Date.

7.THE PARTIES AGREE THAT (I) OWNER PROVIDES AND CONTRACTOR SHALL ACCEPT ALL REPLACEMENT PARTS "AS- IS" WITH ANY AND ALL DEFECTS (IF ANY), INCLUDING LATENT DEFECTS; (II) ANY USE OF ANY REPLACEMENT PARTS BY CONTRACTOR, INCLUDING CONTRACTOR'S INCORPORATION OF ANY REPLACEMENT PARTS INTO SUBPROJECT 6(a), SHALL BE AT CONTRACTOR'S SOLE RISK AND SHALL NOT RELIEVE CONTRACTOR OF ANY OF ITS OBLIGATIONS UNDER THE AGREEMENT (INCLUDING ACHIEVING THE GUARANTEED SUBSTANTIAL COMPLETION DATE, THE MAC AND PERFORMANCE GUARANTEE IN ACCORDANCE WITH THE AGREEMENT); AND (III) OWNER HEREBY DISCLAIMS ANY AND ALL WARRANTIES RELATING TO ALL REPLACEMENT PARTS, INCLUDING THE IMPLIED WARRANTY OF MERCHANTABILITY AND IMPLIED WARRANTY OF FITNESS FOR A

PARTICULAR PURPOSE. After installation of any Replacement Parts into the Stage 4 Liquefaction Facility, Article 12 of the Agreement (including the warranty obligations) shall apply to the Replacement Parts as if the Replacement Parts were provided by Contractor under the Agreement.

Adjustment to Contract Price Applicable to Subproject 6(a)

1.	The original Contract Price Applicable to Subproject 6(a) was	$	2,016,892,573
2.	Net change for Contract Price Applicable to Subproject 6(a) by previously authorized Change Orders (#01-08, 10-13, 15, 17-18, 21-22, 24, 28-29, 31-32, 34-35, 38, 41-42, 45-49, 51)	$	17,846,936
3.	The Contract Price Applicable to Subproject 6(a) prior to this Change Order was	$	2,034,739,509
4.	The Contract Price Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
5.	The Provisional Sum Applicable to Subproject 6(a) will be unchanged by this Change Order in the amount of	$	—
6.	The Contract Price Applicable to Subproject 6(a) including this Change Order will be	$	2,034,739,509

Adjustment to Contract Price Applicable to Subproject 6(b)

7.	The original Contract Price Applicable to Subproject 6(b) (in CO-00009) was	$	457,696,000
8.	Net change for Contract Price Applicable to Subproject 6(b) by previously authorized Change Orders (#14, 16, 19-20, 23, 25-27, 30-31, 33, 36-37, 39-40, 43-44, 50, 52)	$	(3,978,536)
9.	The Contract Price Applicable to Subproject 6(b) prior to this Change Order was	$	453,717,464
10.	The Contract Price Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
11.	The Provisional Sum Applicable to Subproject 6(b) will be unchanged by this Change Order	$	—
12.	The Contract Price Applicable to Subproject 6(b) including this Change Order will be	$	453,717,464

Adjustment to Contract Price

13.	The original Contract Price for Subproject 6(a) and Subproject 6(b) was (add lines 1 and 7)	$	2,474,588,573
14.	The Contract Price prior to this Change Order was (add lines 3 and 9)....................................................	$	2,488,456,973
15.	The Contract Price will be unchanged by this Change Order in the amount of (add lines 4, 5, 10 and 11)	$	—
16.	The new Contract Price including this Change Order will be (add lines 14 and 15)................................	$	2,488,456,973

Adjustment to dates in Project Schedule for Subproject 6(a)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(a):N/A

Adjustment to Payment Schedule for Subproject 6(a): N/A

Adjustment to Minimum Acceptance Criteria for Subproject 6(a): N/A

Adjustment to Performance Guarantees for Subproject 6(a):N/A

Adjustment to Design Basis for Subproject 6(a):N/A

Other adjustments to liability or obligations of Contractor or Owner under the Agreement for Subproject 6(a): N/A

Adjustment to dates in Project Schedule for Subproject 6(b)

The following dates are modified: N/A

Adjustment to other Changed Criteria for Subproject 6(b): N/A

Adjustment to Payment Schedule for Subproject 6(b): N/A

Adjustment to Design Basis for Subproject 6(b):N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

Other adjustments to liability or obligation of Contractor or Owner under the Agreement; N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials: /s/ KM Contractor /s/ DC Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ David Craft	/s/ Kane McIntosh
Owner	Contractor
David Craft	Kane McIntosh
Name	Name
SVP E&C	Project Manager
Title	Title
September 29, 2021	September 27, 2021
Date of Signing	Date of Signing

EX-10.2

Exhibit 10.2

FIRST AMENDMENT TO THIRD AMENDED AND RESTATED COMMON TERMS AGREEMENT

This First Amendment to Third Amended and Restated Common Terms Agreement (this “Amendment”), dated as of July 26, 2021 amends the Third Amended and Restated Common Terms Agreement, dated as of March 19, 2020 (as it may be further amended, restated, supplemented or otherwise modified from time to time prior to this Amendment, the “Common Terms Agreement”), by and among Sabine Pass Liquefaction, LLC, a Delaware limited liability company (the “Borrower”), the Subsidiaries of the Borrower from time to time party thereto, Société Générale, as the Common Security Trustee (in such capacity, the “Common Security Trustee”) and as the Intercreditor Agent (in such capacity, the “Intercreditor Agent”), the Secured Debt Holder Group Representatives, the Secured Hedge Representatives and the Secured Gas Hedge Representatives party thereto from time to time. All capitalized terms used herein and not otherwise defined shall have the meanings ascribed to such terms in the Common Terms Agreement.

WHEREAS, the Borrower has requested that the Common Security Trustee, the Intercreditor Agent, the Secured Debt Holder Group Representative for the Working Capital Debt, and the Lenders (collectively, the “Lenders” and each individually, a “Lender”) constituting the Required Lenders under the Working Capital Facility Agreement agree to amend the Common Terms Agreement as set forth in Section 1 herein; and

WHEREAS, the Secured Debt Holder Group Representative for the Working Capital Debt, the Common Security Trustee, the Intercreditor Agent and the Required Lenders are willing to amend the Common Terms Agreement as set forth in Section 1 herein.

NOW, THEREFORE, in consideration of the foregoing premises and the agreements, provisions and covenants herein contained, and for other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the parties hereto agree as follows:

Section 1.Amendment to the Common Terms Agreement. Pursuant to Section 5.1 of the Common Terms Agreement and Section 4.1(i) of the Intercreditor Agreement, each of the Borrower, the Common Security Trustee, the Intercreditor Agent and the Secured Debt Holder Group Representative for the Working Capital Debt hereby consents to the following amendment:

1.1    The definition of “Permitted Hedging Agreement” in Schedule 1 of the Common Terms Agreement is hereby amended to delete the stricken text (indicated textually in the same manner as the following example: stricken text) and to add the double-underlined text (indicated textually in the same manner as the following example: double-underlined text) as set forth below:

“Permitted Hedging Agreement” means any:

(a)    Interest Rate Protection Agreements;

(b)    the following gas hedging contracts:

(i)    Futures Contracts, Fixed-Float Futures Swaps, NYMEX Natural Gas Futures Contracts and Swing Swaps for gas hedging purposes for up to a maximum of 78 TBtu of gas utilizing intra-month and up to three prompt month contracts;

(ii)    Index Swaps for gas hedging purposes for up to a maximum of 74.4 TBtu per month of gas utilizing up to three twenty four prompt month contracts; and

(iii)    Basis Swaps for gas hedging purposes for up to a maximum of (a) 74.4 TBtu per month for Basis Swaps with a tenor up to 24 months and (b) 30.0 TBtu for Basis Swaps with a tenor greater than 24 months but less than 36 months. For the avoidance of doubt, Basis Swaps with a tenor of more than 36 months are prohibited. Further, the aggregate notional volume of financial natural gas positions in Basis Swaps may not exceed that of physical natural gas positions on an MMBtu basis.

1.2    The Common Terms Agreement as amended by this Section 1 is referred to

herein as the “Amended Common Terms Agreement”.

Section 2.    Effectiveness. This Amendment shall become effective as of the date

hereof upon the satisfaction of the following condition precedent: this Amendment shall have been executed by the Common Security Trustee and the Common Security Trustee shall have received counterparts of this Amendment executed by each of (a) the Borrower, (b) the Intercreditor Agent, (c) the Secured Debt Holder Group Representative for the Working Capital Debt (who constitutes the Majority Aggregate Secured Credit Facilities Debt Participants (as defined in the Intercreditor Agreement)) and (d) the Lenders constituting the Required Lenders under the Working Capital Facility Agreement.

Section 3.    Representations and Warranties. The Borrower hereby represents and warrants to the Lenders that:

3.1    no Default or Event of Default has occurred and is continuing as of the date

hereof or will result from the consummation of the transactions contemplated by the Amendment; and

3.2    each of the representations and warranties of the Borrower in the Financing

Documents is true and correct in all material respects except for (A) those representations and warranties that are qualified by materiality, which shall be true and correct in all respects, on and as of the date hereof (or, if stated to have been made solely as of an earlier date, as of such earlier date) and (B) the representations and warranties that, pursuant to Article III of the Working Capital Facility Agreement, are not deemed repeated.

Section 4.    Financing Document. This Amendment constitutes a Financing Document as such term is defined in, and for purposes of, the Amended Common Terms Agreement.

2

Section 5.    Governing Law. THIS AMENDMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK, UNITED STATES OF AMERICA, WITHOUT ANY REFERENCE TO THE CONFLICT OF LAW PRINCIPLES THEREOF (OTHER THAN SECTION 5-1401 OF THE NEW YORK GENERAL OBLIGATIONS LAW).

Section 6.    Headings. All headings in this Amendment are included only for convenience and ease of reference and shall not be considered in the construction and interpretation of any provision hereof.

Section 7.    Binding Nature and Benefit. This Amendment shall be binding upon and inure to the benefit of each party hereto and their respective successors and permitted assigns.

Section 8.    Counterparts; Electronic Execution. This Amendment may be executed in multiple counterparts, each of which shall be deemed an original for all purposes, but all of which together shall constitute one and the same instrument. Delivery of an executed counterpart of a signature page of this Amendment by facsimile or portable document format (“pdf”) shall be effective as delivery of a manually executed counterpart of this Amendment. The words “execution,” “execute”, “signed,” “signature,” and words of like import in or related to any document to be signed in connection with this Amendment and the transactions contemplated hereby shall be deemed to include electronic signatures, the electronic matching of assignment terms and contract formations on electronic platforms approved by the Common Security Trustee, or the keeping of records in electronic form, each of which shall be of the same legal effect, validity or enforceability as a manually executed signature or the use of a paper-based recordkeeping system, as the case may be, to the extent and as provided for in any applicable law, including the Federal Electronic Signatures in Global and National Commerce Act, the New York State Electronic Signatures and Records Act, or any other similar state laws based on the Uniform Electronic Transactions Act.

Section 9.    No Modifications; No Other Matters. Except as expressly provided for herein, the terms and conditions of the Common Terms Agreement shall continue unchanged and shall remain in full force and effect. Each amendment granted herein shall apply solely to the matters set forth herein and such amendment shall not be deemed or construed as an amendment of any other matters, nor shall such amendment apply to any other matters.

Section 10.    Direction to Secured Debt Holder Group Representative, Intercreditor Agent and Common Security Trustee.

(a)    by their signature below, each of the undersigned Lenders instructs the Secured Debt Holder Group Representative for the Working Capital Debt to (i) execute this Amendment and (ii) direct the Intercreditor Agent to execute this Amendment;

(b)    based on the instructions above, the Secured Debt Holder Group Representative for the Working Capital Debt, constituting the Majority Aggregate Secured Credit Facilities Debt Participants (as defined in the Intercreditor

3

Agreement), hereby directs the Intercreditor Agent to (i) execute this Amendment and (ii) direct the Common Security Trustee to execute this Amendment; and

(c) by its signature below, the Intercreditor Agent, in such capacity, hereby directs the Common Security Trustee to execute this Amendment.

[Remainder of the page left intentionally blank.]

4

IN WITNESS WHEREOF,the parties have caused this Amendment to be duly executed by their officers thereunto duly authorized as of the day and year first above written.

SABINE PASS LIQUEFACTION, LLC,
as the Borrower
By:	/s/ Lisa C. Cohen
	Name:	Lisa C. Cohen
	Title:	Treasurer

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

SOCIÉTÉ GÉNÉRALE,

as Common Security Trustee and Secured

Debt Holder Group Representative for the

Commercial Banks Facility

By:	/s/ Karla Navas
	Name:	Karla Navas
	Title:	Vice President

SOCIÉTÉ GÉNÉRALE,

as the Intercreditor Agent

By:	/s/ Karla Navas
	Name:	Karla Navas
	Title:	Vice President

SOCIÉTÉ GÉNÉRALE,

as a Lender

By:	/s/ Karla Navas
	Name:	Karla Navas
	Title:	Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

THE BANK OF NOVA SCOTIA,

as the Secured Debt Holder Group Representative for the Working Capital Debt

By:	/s/ Joe Lattanzi
	Name:	Joe Lattanzi
	Title:	Managing Director

THE BANK OF NOVA SCOTIA, HOUSTON BRANCH

as an Issuing Bank, the Swing Line Lender and a Lender

By:	/s/ Joe Lattanzi
	Name:	Joe Lattanzi
	Title:	Managing Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

ABN AMRO CAPITAL USA LLC,

as a Lender

By:	/s/ Darrell Holley
	Name:	Darrell Holley
	Title:	Managing Director

By:	/s/ Matt Worstell
	Name:	Matt Wortsell
	Title:	Executive Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

BANCO BILBAO VIZCAYA

ARGENTARIA, S.A. NEW YORK

BRANCH,

as a Lender

By:	/s/ Cara Younger
	Name:	Cara Younger
	Title:	Executive Director

By:	/s/ Miriam Trautmann
	Name:	Miriam Trautmann
	Title:	Senior Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

BANK OF CHINA, NEW YORK

BRANCH

as a Lender

By:	/s/ Raymond Qiao
	Name:	Raymond Qiao
	Title:	Executive Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

CITIBANK, N.A.,

as a Lender

By:	/s/ Catherine Shepherd
	Name:	Catherine Shepherd
	Title:	Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

HSBC BANK USA, NATIONAL ASSOCIATION,

as a Lender and an Issuing Bank

By:	/s/ Balaji Rajgopal
	Name:	Balaji Rajgopal
	Title:	Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

INDUSTRIAL AND COMMERCIAL BANK

OF CHINA LIMITED, NEW YORK BRANCH,

as a Lender

By:	/s/ Michael Merrow
	Name:	Michael Merrow
	Title:	Vice President

By:	/s/ Michael Fabisiak
	Name:	Michael Fabisiak
	Title:	Head of Project Finance

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

ING CAPITAL LLC,

as a Lender and an Issuing Bank

By:	/s/ Subha Pasumarti
	Name:	Subha Pasumarti
	Title:	Managing Director

By:	/s/ Gabriel D’Huart
	Name:	Gabriel D’Huart
	Title:	Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

INTESA SANPAOLO S.P.A., NEW YORK BRANCH,

as a Lender

By:	/s/ Fuensanta Diaz Cobacho
	Name:	Fuensanta Diaz Cobacho
	Title:	Managing Director

By:	/s/ Nicholas A. Matacchieri
	Name:	Nicholas A. Matacchieri
	Title:	Managing Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

MIZUHO BANK, LTD.,

as Lender

By:	/s/ Edward Sacks
	Name:	Edward Sacks
	Title:	Executive Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

MUFG BANK, LTD.,

as a Lender

By:	/s/ Saad Iqbal
	Name:	Saad Iqbal
	Title:	Managing Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

NATIONAL AUSTRALIA BANK LIMITED,

as a Lender

By:	/s/ Eli Davis
	Name:	Eli Davis
	Title:	Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

NATIXIS, NEW YORK BRANCH,

as Lender and Issuing Bank

By:	/s/ Anthony Perna
	Name:	Anthony Perna
	Title:	Director

By:	/s/ Jonathan Cohen
	Name:	Jonathan Cohen
	Title:	Executive

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

BANCO DE SABADELL, S.A., MIAMI BRANCH,

as a Lender

By:	/s/ Ignacio Alcaraz
	Name:	Ignacio Alcaraz
	Title:	Head of Structured Finance Americas

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

BANCO SANTANDER, S.A., NEW YORK BRANCH,

as a Lender

By:	/s/ Daniel S. Kostman
	Name:	Daniel S. Kostman
	Title:	Executive Director

By:	/s/ Robert Cestari
	Name:	Robert Cestari
	Title:	Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

STANDARD CHARTERED BANK,

as a Lender

By:	/s/ Mr. Sridhar Nagarajan
	Name:	Mr. Sridhar Nagarajan
	Title:	Regional Head, Project and Export Finance, Europe and Americas

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

SUMITOMO MITSUI BANKING CORPORATION,

as a Lender

By:	/s/ Juan Kreutz
	Name:	Juan Kreutz
	Title:	Managing Director

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

Acknowledged and agreed as of the first date set forth above.

WELLS FARGO BANK, NATIONAL ASSOCIATION,

as a Lender and an Issuing Bank

By:	/s/ Borden Tennant
	Name:	Borden Tennant
	Title:	Vice President

SIGNATURE PAGE TO FIRST AMENDMENT TO THIRD A&R COMMON TERMS AGREEMENT (SPL)

EX-31.1

Exhibit 31.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Jack A. Fusco, certify that:

1.    I have reviewed this quarterly report on Form 10-Q of Cheniere Energy, Inc.;

2.     Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.     Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.    The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)    Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)     Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)     Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

d)     Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.     The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)     All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)     Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 3, 2021 

/s/ Jack A. Fusco

Jack A. Fusco
Chief Executive Officer of

Cheniere Energy, Inc.

EX-31.2

Exhibit 31.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

PURSUANT TO RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Zach Davis, certify that:

1.    I have reviewed this quarterly report on Form 10-Q of Cheniere Energy, Inc.;

2.     Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.     Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.     The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a)     Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)     Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)     Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

d)     Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.     The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a)     All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b)     Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 3, 2021

/s/ Zach Davis

Zach Davis
Chief Financial Officer of

Cheniere Energy, Inc.

EX-32.1

Exhibit 32.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended September 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jack A. Fusco, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1)    The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)    The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: November 3, 2021 

/s/ Jack A. Fusco

Jack A. Fusco
Chief Executive Officer of

Cheniere Energy, Inc.

EX-32.2

Exhibit 32.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the quarter ended September 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Zach Davis, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1)    The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)    The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: November 3, 2021 

/s/ Zach Davis

Zach Davis
Chief Financial Officer of

Cheniere Energy, Inc.

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2021	Oct. 29, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
Document Transition Report	false
Entity File Number	001-16383
Entity Registrant Name	CHENIERE ENERGY, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	95-4352386
Entity Address, Address Line One	700 Milam Street
Entity Address, Address Line Two	Suite 1900
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	375-5000
Title of 12(b) Security	Common Stock, $ 0.003 par value
Trading Symbol	LNG
Security Exchange Name	NYSEAMER
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		253,588,453
Entity Central Index Key	0000003570
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3

XML

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenues
Revenues		$ 3,200	$ 1,460	$ 9,307	$ 6,571
Revenues from contracts with customers		4,259	1,421	10,773	6,338
Operating costs and expenses
Cost of sales (excluding items shown separately below)		4,868	768	8,408	2,295
Operating and maintenance expense		350	317	1,057	988
Development expense		2	0	5	5
Selling, general and administrative expense		70	70	224	224
Depreciation and amortization expense		259	233	753	699
Impairment expense and loss on disposal of assets		1	0	0	5
Total operating costs and expenses		5,550	1,388	10,447	4,216
Income (loss) from operations		(2,350)	72	(1,140)	2,355
Other expense
Interest expense, net of capitalized interest		(364)	(355)	(1,088)	(1,174)
Loss on modification or extinguishment of debt		(36)	(171)	(95)	(215)
Interest rate derivative loss, net		3,500		4,200
Other expense, net		(24)	(129)	(14)	(115)
Total other expense		(426)	(655)	(1,200)	(1,737)
Income (loss) before income taxes and non-controlling interest		(2,776)	(583)	(2,340)	618
Less: income tax provision (benefit)		(1,860)	(75)	(1,864)	119
Net income (loss)		(916)	(508)	(476)	499
Less: net income (loss) attributable to non-controlling interest		168	(45)	544	390
Net income (loss) attributable to common stockholders		$ (1,084)	$ (463)	$ (1,020)	$ 109
Net income (loss) per share attributable to common stockholders—basic and diluted		$ (4.27)	$ (1.84)	$ (4.03)	$ 0.43
Weighted average number of common shares outstanding—basic		253.6	252.2	253.3	252.5
Weighted average number of common shares outstanding—diluted		253.6	252.2	253.3	253.2
Interest Rate Derivatives [Member]
Other expense
Interest rate derivative loss, net		$ (2)	$ 0	$ (3)	$ (233)
LNG [Member]
Revenues
Revenues		3,078	1,373	8,990	6,236
Revenues from contracts with customers	[1]	4,169	1,344	10,505	6,088
Regasification [Member]
Revenues
Revenues from contracts with customers		68	67	202	202
Other [Member]
Revenues
Revenues		54	20	115	133
Revenues from contracts with customers		$ 22	$ 10	$ 66	$ 48

[1] LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2021 and 2020 excluded zero and $458 million, respectively, and LNG revenues during the nine months ended September 30, 2021 and 2020 excluded $38 million and zero, respectively, that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

XML

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2021		Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 2,203	[1]	$ 1,628
Restricted cash	419	[1]	449
Accounts and other receivables, net of current expected credit losses	983		647
Inventory	471		292
Current derivative assets	266		32
Margin deposits	336		25
Other current assets	185		96
Total current assets	4,863		3,169
Property, plant and equipment, net of accumulated depreciation	30,318		30,421
Operating lease assets	2,064		759
Derivative assets	71		376
Goodwill	77		77
Deferred tax assets	2,361		489
Other non-current assets, net	425		406
Total assets	40,179	[1]	35,697
Current liabilities
Accounts payable	73		35
Accrued liabilities	1,787		1,175
Current debt, net of discount and debt issuance costs	1,047		372
Deferred revenue	187		138
Current operating lease liabilities	458		161
Current derivative liabilities	1,979		313
Other current liabilities	129		2
Total current liabilities	5,660		2,196
Long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Operating lease liabilities	1,590		597
Finance lease liabilities	57		57
Derivative liabilities	2,158		151
Other non-current liabilities	20		7
Stockholders’ equity
Preferred stock, $0.0001 par value, 5.0 million shares authorized, none issued	0		0
Common stock, $0.003 par value, 480.0 million shares authorized; 275.1 million shares and 273.1 million shares issued at September 30, 2021 and December 31, 2020, respectively	1		1
Treasury stock: 21.6 million shares and 20.8 million shares at September 30, 2021 and December 31, 2020, respectively, at cost	(924)		(872)
Additional paid-in-capital	4,364		4,273
Accumulated deficit	(4,698)		(3,593)
Total stockholders' deficit	(1,257)		(191)
Non-controlling interest	2,470		2,409
Total equity	1,213		2,218
Total liabilities and stockholders’ equity	$ 40,179	[1]	$ 35,697

[1] Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

XML

Consolidated Balance Sheets Parentheticals - USD ($) $ in Millions	Sep. 30, 2021		Dec. 31, 2020
Assets	$ 40,179	[1]	$ 35,697
Cash and cash equivalents	2,203	[1]	1,628
Restricted cash	$ 419	[1]	$ 449
Preferred Stock, Par Value	$ 0.0001		$ 0.0001
Preferred Stock, Shares Authorized	5,000,000		5,000,000
Preferred Stock, Shares Issued	0		0
Common Stock, Par Value Per Share	$ 0.003		$ 0.003
Common stock, Shares Authorized	480,000,000		480,000,000
Common Stock, Shares, Issued	275,100,000		273,100,000
Treasury Stock, Shares	21,600,000		20,800,000
Cheniere Partners [Member]
Assets	$ 19,601		$ 18,817
Liabilities	19,275		18,535
Cash and cash equivalents	1,713		1,210
Restricted cash	$ 133		$ 97

[1] Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

XML

Consolidated Statements of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Accumulated Deficit	Non-controlling Interest
Common Stock, Shares, Outstanding, Beginning of Period at Dec. 31, 2019	253,600,000
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2019	17,100,000
Stockholders' Equity, Beginning of Period at Dec. 31, 2019	$ 2,435	$ 1	$ (674)	$ 4,167	$ (3,508)	$ 2,449
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		2,100,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	29	$ 0	$ 0	29	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		(700,000)
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			700,000
Issued shares withheld from employees related to share-based compensation, at cost	(39)	$ 0	$ (39)	0	0	0
Shares repurchased, at cost, shares		(2,900,000)	2,900,000
Shares repurchased, at cost	(155)	$ 0	$ (155)	0	0	0
Net income attributable to non-controlling interest	228	0	0	0	0	228
Distributions to non-controlling interest	(154)	0	0	0	0	(154)
Net income (loss)	$ 375	0	0	0	375	0
Common Stock, Shares, Outstanding, End of Period at Mar. 31, 2020	252,100,000
Treasury Stock, Shares, End of Period at Mar. 31, 2020	20,700,000
Stockholders' Equity, End of Period at Mar. 31, 2020	$ 2,719	1	(868)	4,196	(3,133)	2,523
Common Stock, Shares, Outstanding, Beginning of Period at Dec. 31, 2019	253,600,000
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2019	17,100,000
Stockholders' Equity, Beginning of Period at Dec. 31, 2019	$ 2,435	1	(674)	4,167	(3,508)	2,449
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased, at cost, shares	2,900,000
Net income attributable to non-controlling interest	$ 390
Net income (loss)	$ 109
Common Stock, Shares, Outstanding, End of Period at Sep. 30, 2020	252,200,000
Treasury Stock, Shares, End of Period at Sep. 30, 2020	20,800,000
Stockholders' Equity, End of Period at Sep. 30, 2020	$ 2,347	1	(872)	4,246	(3,399)	2,371
Common Stock, Shares, Outstanding, Beginning of Period at Mar. 31, 2020	252,100,000
Treasury Stock, Shares, Beginning of Period at Mar. 31, 2020	20,700,000
Stockholders' Equity, Beginning of Period at Mar. 31, 2020	$ 2,719	$ 1	$ (868)	4,196	(3,133)	2,523
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		100,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	31	$ 0	$ 0	31	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		0
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			0
Issued shares withheld from employees related to share-based compensation, at cost	(2)	$ 0	$ (2)	0	0	0
Net income attributable to non-controlling interest	207	0	0	0	0	207
Distributions to non-controlling interest	(156)	0	0	0	0	(156)
Net income (loss)	$ 197	0	0	0	197	0
Common Stock, Shares, Outstanding, End of Period at Jun. 30, 2020	252,200,000
Treasury Stock, Shares, End of Period at Jun. 30, 2020	20,700,000
Stockholders' Equity, End of Period at Jun. 30, 2020	$ 2,996	$ 1	$ (870)	4,227	(2,936)	2,574
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		100,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	26	$ 0	$ 0	26	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		(100,000)
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			100,000
Issued shares withheld from employees related to share-based compensation, at cost	$ (2)	$ 0	$ (2)	0	0	0
Shares repurchased, at cost, shares	0
Net income attributable to non-controlling interest	$ (45)	0	0	0	0	(45)
Reacquisition of equity component of convertible notes, net of tax	(7)	0	0	(7)	0	0
Distributions to non-controlling interest	(158)	0	0	0	0	(158)
Net income (loss)	$ (463)	0	0	0	(463)	0
Common Stock, Shares, Outstanding, End of Period at Sep. 30, 2020	252,200,000
Treasury Stock, Shares, End of Period at Sep. 30, 2020	20,800,000
Stockholders' Equity, End of Period at Sep. 30, 2020	$ 2,347	1	(872)	4,246	(3,399)	2,371
Common Stock, Shares, Outstanding, Beginning of Period at Dec. 31, 2020	252,300,000
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2020	20,800,000
Stockholders' Equity, Beginning of Period at Dec. 31, 2020	$ 2,218	$ 1	$ (872)	4,273	(3,593)	2,409
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		1,800,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	33	$ 0	$ 0	33	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		(600,000)
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			600,000
Issued shares withheld from employees related to share-based compensation, at cost	(42)	$ 0	$ (42)	0	0	0
Net income attributable to non-controlling interest	178	0	0	0	0	178
Distributions to non-controlling interest	(160)	0	0	0	0	(160)
Net income (loss)	$ 393	0	0	0	393	0
Common Stock, Shares, Outstanding, End of Period at Mar. 31, 2021	253,500,000
Treasury Stock, Shares, End of Period at Mar. 31, 2021	21,400,000
Stockholders' Equity, End of Period at Mar. 31, 2021	$ 2,620	1	(914)	4,306	(3,200)	2,427
Common Stock, Shares, Outstanding, Beginning of Period at Dec. 31, 2020	252,300,000
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2020	20,800,000
Stockholders' Equity, Beginning of Period at Dec. 31, 2020	$ 2,218	1	(872)	4,273	(3,593)	2,409
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased, at cost, shares	100,000
Net income attributable to non-controlling interest	$ 544
Net income (loss)	$ (1,020)
Common Stock, Shares, Outstanding, End of Period at Sep. 30, 2021	253,500,000
Treasury Stock, Shares, End of Period at Sep. 30, 2021	21,600,000
Stockholders' Equity, End of Period at Sep. 30, 2021	$ 1,213	1	(924)	4,364	(4,698)	2,470
Common Stock, Shares, Outstanding, Beginning of Period at Mar. 31, 2021	253,500,000
Treasury Stock, Shares, Beginning of Period at Mar. 31, 2021	21,400,000
Stockholders' Equity, Beginning of Period at Mar. 31, 2021	$ 2,620	$ 1	$ (914)	4,306	(3,200)	2,427
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		100,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	31	$ 0	$ 0	31	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		0
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			0
Issued shares withheld from employees related to share-based compensation, at cost	(1)	$ 0	$ (1)	0	0	0
Net income attributable to non-controlling interest	198	0	0	0	0	198
Distributions to non-controlling interest	(162)	0	0	0	0	(162)
Net income (loss)	$ (329)	0	0	0	(329)	0
Common Stock, Shares, Outstanding, End of Period at Jun. 30, 2021	253,600,000
Treasury Stock, Shares, End of Period at Jun. 30, 2021	21,400,000
Stockholders' Equity, End of Period at Jun. 30, 2021	$ 2,357	$ 1	$ (915)	4,337	(3,529)	2,463
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		100,000	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	28	$ 0	$ 0	28	0	0
Issued shares withheld from employees related to share-based compensation, at cost, shares, common stock		(100,000)
Issued shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			100,000
Issued shares withheld from employees related to share-based compensation, at cost	$ (4)	$ 0	$ (3)	(1)	0	0
Shares repurchased, at cost, shares	100,000	(100,000)	100,000
Shares repurchased, at cost	$ (6)	$ 0	$ (6)	0	0	0
Net income attributable to non-controlling interest	168	0	0	0	0	168
Distributions to non-controlling interest	(161)	0	0	0	0	(161)
Dividends declared ($0.33 per common share)	(85)	0	0	0	(85)	0
Net income (loss)	$ (1,084)	0	0	0	(1,084)	0
Common Stock, Shares, Outstanding, End of Period at Sep. 30, 2021	253,500,000
Treasury Stock, Shares, End of Period at Sep. 30, 2021	21,600,000
Stockholders' Equity, End of Period at Sep. 30, 2021	$ 1,213	$ 1	$ (924)	$ 4,364	$ (4,698)	$ 2,470

XML

Consolidated Statements of Stockholders' Equity Parentheticals	3 Months Ended
	Sep. 30, 2021 $ / shares
Common Stock
Common Stock, Dividends, Per Share, Declared	$ 0.33

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Cash flows from operating activities
Net income (loss)	$ (476)	$ 499
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	753	699
Share-based compensation expense	91	84
Non-cash interest expense	16	43
Amortization of debt issuance costs, premium and discount	57	94
Reduction of right-of-use assets	269	222
Loss on modification or extinguishment of debt	95	215
Total losses (gains) on derivatives, net	4,230	(282)
Net cash provided by (used for) settlement of derivative instruments	(486)	61
Impairment expense and loss on disposal of assets	0	5
Impairment expense and loss on equity method investments	16	130
Deferred taxes	(1,872)	115
Repayment of paid-in-kind interest related to repurchase of convertible notes	(190)	(911)
Other	3	2
Changes in operating assets and liabilities:
Accounts and other receivables, net of current expected credit losses	(338)	101
Inventory	(174)	31
Margin deposits	(311)	(10)
Other current assets	(92)	(27)
Accounts payable and accrued liabilities	612	(93)
Deferred revenue	58	18
Operating lease liabilities	(285)	(205)
Finance lease liabilities	1	0
Other, net	80	(26)
Net cash provided by operating activities	2,057	765
Cash flows from investing activities
Property, plant and equipment	(761)	(1,437)
Proceeds from sale of fixed assets	68	0
Investment in equity method investment	0	(100)
Other	(14)	(8)
Net cash used in investing activities	(707)	(1,545)
Cash flows from financing activities
Proceeds from issuances of debt	4,104	7,683
Repayments of debt	(4,276)	(6,324)
Debt issuance and other financing costs	(38)	(124)
Debt modification or extinguishment costs	(67)	(170)
Distributions to non-controlling interest	(483)	(468)
Payments related to tax withholdings for share-based compensation	(47)	(43)
Repurchase of common stock	(6)	(155)
Other	8	0
Net cash provided by (used in) financing activities	(805)	399
Net increase (decrease) in cash, cash equivalents and restricted cash	545	(381)
Cash, cash equivalents and restricted cash—beginning of period	2,077	2,994
Cash, cash equivalents and restricted cash—end of period	$ 2,622	$ 2,613

XML

Consolidated Statements of Cash Flows - Balances per Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2021		Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Balances per Consolidated Balance Sheets:
Cash and cash equivalents	$ 2,203	[1]	$ 1,628
Restricted cash	419	[1]	449
Total cash, cash equivalents and restricted cash	$ 2,622		$ 2,077	$ 2,613	$ 2,994

[1] Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

XML

Nature of Operations and Basis of Presentation

9 Months Ended

Sep. 30, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Operations and Basis of Presentation

NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We operate two natural gas liquefaction and export facilities at Sabine Pass and Corpus Christi (respectively, the “Sabine Pass LNG Terminal” and “Corpus Christi LNG Terminal”).

Cheniere Partners owns the Sabine Pass LNG Terminal located in Cameron Parish, Louisiana, which has natural gas liquefaction facilities consisting of five operational natural gas liquefaction Trains and one additional Train that is undergoing commissioning and expected to be substantially completed in the first quarter of 2022, for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”). The Sabine Pass LNG Terminal also has operational regasification facilities that include five LNG storage tanks, vaporizers and two marine berths, with an additional marine berth that is under construction. Cheniere Partners also owns a 94-mile pipeline that interconnects the Sabine Pass LNG Terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) through its subsidiary, CTPL. As of September 30, 2021, we owned 100% of the general partner interest and 48.6% of the limited partner interest in Cheniere Partners.

The Corpus Christi LNG Terminal is located near Corpus Christi, Texas. We currently operate three Trains, for a total production capacity of approximately 15 mtpa of LNG. We also own a 23-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the Trains, the “CCL Project”) through our subsidiary CCP, as part of the CCH Group. The CCL Project also contains three LNG storage tanks and two marine berths.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG Terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) through our subsidiary CCL Stage III, for up to seven midscale Trains with an expected total production capacity of approximately 10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and operate the expansion project.

We remain focused on operational excellence and customer satisfaction. Increasing demand for LNG has allowed us to expand our liquefaction infrastructure in a financially disciplined manner. We have increased available liquefaction capacity at the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) as a result of debottlenecking and other optimization projects. We hold significant land positions at both the Sabine Pass LNG Terminal and the Corpus Christi LNG Terminal which provide opportunity for further liquefaction capacity expansion. The development of these sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a final investment decision (“FID”).

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

Results of operations for the three and nine months ended September 30, 2021 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2021.

Recent Accounting Standards

In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. This guidance simplifies the accounting for convertible instruments primarily by eliminating the existing cash conversion and beneficial conversion models within Subtopic 470-20, which will result in fewer embedded conversion options being accounted for separately from the debt host. The guidance also amends and simplifies the calculation of earnings per share relating to convertible instruments. This guidance is effective for annual periods beginning after December 15, 2021, including interim periods within that reporting period, with earlier adoption permitted for fiscal years beginning after December 15, 2020, including interim periods within that reporting period, using either a full or modified retrospective approach. We plan to adopt

this guidance on January 1, 2022 using the modified retrospective approach. Preliminarily, we anticipate the adoption of ASU 2020-06 will primarily result in the reclassification of the previously bifurcated equity component associated with the 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to debt as a result of the elimination of the cash conversion model. We currently estimate that the reclassification of the $194 million equity component will result in an approximate $190 million increase in the carrying value of our 2045 Cheniere Convertible Senior Notes, with the difference primarily impacting retained earnings as of January 1, 2022. We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures. See Note 9—Debt for further discussion on the 2045 Cheniere Convertible Senior Notes.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing contracts expected to arise from the market transition from LIBOR to alternative reference rates. We have various credit facilities and interest rate swaps indexed to LIBOR, as further described in Note 6—Derivative Instruments and Note 9—Debt. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time the optional expedients are no longer available.

XML

Restricted Cash

9 Months Ended

Sep. 30, 2021

Restricted Cash [Abstract]

Restricted Cash

RESTRICTED CASH

Restricted cash consists of funds that are contractually or legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. As of September 30, 2021 and December 31, 2020, restricted cash consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Restricted cash
SPL Project	$	133	$	97
CCL Project	59		70
Cash held by our subsidiaries that is restricted to Cheniere	227		282
Total restricted cash	$	419	$	449

Pursuant to the accounts agreements entered into with the collateral trustees for the benefit of SPL’s debt holders and CCH’s debt holders, SPL and CCH are required to deposit all cash received into reserve accounts controlled by the collateral trustees.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Projects and other restricted payments. The majority of the cash held by our subsidiaries that is restricted to Cheniere relates to advance funding for operation and construction needs of the Liquefaction Projects.

XML

Accounts and Other Receivables, Net of Current Expected Credit Losses

9 Months Ended

Sep. 30, 2021

Receivables [Abstract]

Accounts and Other Receivables, Net of Current Expected Credit Losses

ACCOUNTS AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES

As of September 30, 2021 and December 31, 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Trade receivables
SPL and CCL	$	584	$	482
Cheniere Marketing	272		113
Other accounts receivable	127		52
Total accounts and other receivables, net of current expected credit losses	$	983	$	647

XML

Inventory

9 Months Ended

Sep. 30, 2021

Inventory Disclosure [Abstract]

Inventory

INVENTORY

As of September 30, 2021 and December 31, 2020, inventory consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Materials	$	168	$	150
LNG in-transit	145		88
LNG	125		27
Natural gas	31		26
Other	2		1
Total inventory	$	471	$	292

XML

Property, Plant and Equipment, Net of Accumulated Depreciation

9 Months Ended

Sep. 30, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment, Net of Accumulated Depreciation

PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION

As of September 30, 2021 and December 31, 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
LNG terminal
LNG terminal and interconnecting pipeline facilities	$	30,617	$	27,475
LNG site and related costs	441		324
LNG terminal construction-in-process	2,817		5,378
Accumulated depreciation	(3,663)		(2,935)
Total LNG terminal, net of accumulated depreciation	30,212		30,242
Fixed assets and other
Computer and office equipment	27		25
Furniture and fixtures	20		19
Computer software	122		117
Leasehold improvements	45		45
Land	1		59
Other	21		25
Accumulated depreciation	(181)		(164)
Total fixed assets and other, net of accumulated depreciation	55		126
Assets under finance lease
Tug vessels	60		60
Accumulated depreciation	(9)		(7)
Total assets under finance lease, net of accumulated depreciation	51		53
Property, plant and equipment, net of accumulated depreciation	$	30,318	$	30,421

The following table shows depreciation expense and offsets to LNG terminal costs during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Depreciation expense	$	257	$	231	$	749	$	694
Offsets to LNG terminal costs (1)	—		—		227		—

(1)We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Projects during the testing phase for its construction.

XML

Derivative Instruments

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

DERIVATIVE INSTRUMENTS

We have entered into the following derivative instruments that are reported at fair value:

•interest rate swaps (“CCH Interest Rate Derivatives”) to hedge the exposure to volatility in a portion of the floating-rate interest payments on CCH’s amended and restated term loan credit facility (the “CCH Credit Facility”) and previously, to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”);

•commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the Liquefaction Projects and potential future development of Corpus Christi Stage 3 (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”);

•physical derivatives consisting of liquified natural gas contracts in which we have contractual net settlement (“Physical LNG Trading Derivatives”) and financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (collectively, “LNG Trading Derivatives”); and

•foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with cash flows denominated in currencies other than United States dollar (“FX Derivatives”), associated with both LNG Trading Derivatives and operations in countries outside of the United States.

We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow or fair value hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations to the extent not utilized for the commissioning process, in which case it is capitalized.

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 (in millions):

	Fair Value Measurements as of
	September 30, 2021								December 31, 2020
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
CCH Interest Rate Derivatives liability	$	—	$	(67)	$	—	$	(67)	$	—	$	(140)	$	—	$	(140)
Liquefaction Supply Derivatives asset (liability)	(21)		3		(2,611)		(2,629)		5		(6)		241		240
LNG Trading Derivatives asset (liability)	11		(444)		(680)		(1,113)		(3)		(131)		—		(134)
FX Derivatives asset (liability)	—		9		—		9		—		(22)		—		(22)

We value our Interest Rate Derivatives using an income-based approach utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our LNG Trading Derivatives and our Liquefaction Supply Derivatives using a market or option-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data. We value our FX Derivatives with a market approach using observable FX rates and other relevant data.

The fair value of our Physical Liquefaction Supply Derivatives and LNG Trading Derivatives are predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated events deriving fair value, including evaluating whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of September 30, 2021 and December 31, 2020, some of our Physical

Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow.

We include our Physical LNG Trading Derivatives and a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity, volatility and contract duration.

The Level 3 fair value measurements of our Physical LNG Trading Derivatives and the natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives and Physical LNG Trading Derivatives as of September 30, 2021:

	Net Fair Value Liability (in millions)	Valuation Approach	Significant Unobservable Input	Range of Significant Unobservable Inputs / Weighted Average (1)
Physical Liquefaction Supply Derivatives	$(2,611)	Market approach incorporating present value techniques	Henry Hub basis spread	$(1.333) - $0.895 / $(0.006)
		Option pricing model	International LNG pricing spread, relative to Henry Hub (2)	158% - 516% / 224%
Physical LNG Trading Derivatives	$(680)	Market approach incorporating present value techniques	International LNG pricing spread, relative to Henry Hub or TTF, as applicable (2)	$(11.275) - $23.458 / $17.777

(1)Unobservable inputs were weighted by the relative fair value of the instruments.

(2)Spread contemplates U.S. dollar-denominated pricing.

Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Physical LNG Trading Derivatives and our Physical Liquefaction Supply Derivatives.

The following table shows the changes in the fair value of our Level 3 Physical LNG Trading Derivatives and Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Balance, beginning of period	$	(389)	$	590	$	241	$	138
Realized and mark-to-market gains (losses):
Included in cost of sales	(2,982)		(27)		(2,898)		454
Purchases and settlements:
Purchases	5		1		(657)		2
Settlements	75		(31)		23		(61)
Balance, end of period	$	(3,291)	$	533	$	(3,291)	$	533
Change in unrealized gains (losses) relating to instruments still held at end of period	$	(2,982)	$	(27)	$	(2,898)	$	454

All counterparty derivative contracts provide for the unconditional right of set-off in the event of default. We have elected to report derivative assets and liabilities arising from our derivative contracts with the same counterparty on a net basis. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

Interest Rate Derivatives

CCH has entered into interest rate swaps to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility. CCH previously also had interest rate swaps to hedge against changes in interest rates that could impact the anticipated future issuance of debt. In August 2020, we settled the outstanding CCH Interest Rate Forward Start Derivatives.

As of September 30, 2021, we had the following Interest Rate Derivatives outstanding:

	Notional Amounts
	September 30, 2021	December 31, 2020	Latest Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
CCH Interest Rate Derivatives	$4.5 billion	$4.6 billion	May 31, 2022	2.30%	One-month LIBOR

The following table shows the effect and location of our Interest Rate Derivatives on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
CCH Interest Rate Derivatives	Interest rate derivative loss, net	$	(2)	$	—	$	(3)	$	(138)
CCH Interest Rate Forward Start Derivatives	Interest rate derivative loss, net	—		—		—		(95)

Commodity Derivatives

SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges, including those associated with our IPM transactions, to purchase natural gas for the commissioning and operation of the Liquefaction Projects and potential future development of Corpus Christi Stage 3, respectively, which are primarily indexed to the natural gas market and international LNG indices. The remaining terms of the index-based physical natural gas supply contracts range up to approximately 15 years, some of which commence upon the satisfaction of certain events or states of affairs. The terms of the Financial Liquefaction Supply Derivatives range up to approximately three years.

Commencing in first quarter of 2021, we have entered into physical LNG transactions that provide for contractual net settlement. Such transactions are accounted for as LNG Trading Derivatives, and are designed to economically hedge exposure to the commodity markets in which we sell LNG. We have entered into, and may from time to time enter into, financial LNG Trading Derivatives in the form of swaps, forwards, options or futures. The terms of LNG Trading Derivatives range up to approximately two years.

The following table shows the notional amounts of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”):

	September 30, 2021		December 31, 2020
	Liquefaction Supply Derivatives	LNG Trading Derivatives	Liquefaction Supply Derivatives	LNG Trading Derivatives
Notional amount, net (in TBtu) (1)	11,291	(14)	10,483	20

(1)Includes notional amounts for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

The following table shows the effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location (1)	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
LNG Trading Derivatives	LNG revenues	$	(1,098)	$	13	$	(1,539)	$	119
LNG Trading Derivatives	Cost of sales	55		(5)		136		(5)
Liquefaction Supply Derivatives (2)	LNG revenues	(4)		21		(3)		7
Liquefaction Supply Derivatives (2)	Cost of sales	(2,444)		(103)		(2,848)		372

(1)Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

(2)Does not include the realized value associated with derivative instruments that settle through physical delivery.

FX Derivatives

Cheniere Marketing has entered into FX Derivatives to protect against the volatility in future cash flows attributable to changes in international currency exchange rates. The FX Derivatives economically hedge the foreign currency exposure arising from cash flows expended for both physical and financial LNG transactions that are denominated in a currency other than the United States dollar. The terms of FX Derivatives range up to approximately one year.

The total notional amount of our FX Derivatives was $499 million and $786 million as of September 30, 2021 and December 31, 2020, respectively.

The following table shows the effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
FX Derivatives	LNG revenues	$	11	$	(5)	$	27	$	22

Fair Value and Location of Derivative Assets and Liabilities on the Consolidated Balance Sheets

The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions):

	September 30, 2021
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	88	$	163	$	15	$	266
Derivative assets	—		71		—		—		71
Total derivative assets	—		159		163		15		337
Current derivative liabilities	(67)		(630)		(1,276)		(6)		(1,979)
Derivative liabilities	—		(2,158)		—		—		(2,158)
Total derivative liabilities	(67)		(2,788)		(1,276)		(6)		(4,137)
Derivative asset (liability), net	$	(67)	$	(2,629)	$	(1,113)	$	9	$	(3,800)
	December 31, 2020
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	27	$	—	$	5	$	32
Derivative assets	—		376		—		—		376
Total derivative assets	—		403		—		5		408
Current derivative liabilities	(100)		(54)		(134)		(25)		(313)
Derivative liabilities	(40)		(109)		—		(2)		(151)
Total derivative liabilities	(140)		(163)		(134)		(27)		(464)
Derivative asset (liability), net	$	(140)	$	240	$	(134)	$	(22)	$	(56)

(1)Does not include collateral posted with counterparties by us of $47 million and $9 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes derivative assets for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

(2)Does not include collateral posted with counterparties by us of $287 million and $7 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively.

Consolidated Balance Sheets Presentation

Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions):

	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives		LNG Trading Derivatives		FX Derivatives
As of September 30, 2021
Gross assets	$	—	$	179	$	174	$	30
Offsetting amounts	—		(20)		(11)		(15)
Net assets	$	—	$	159	$	163	$	15
Gross liabilities	$	(67)	$	(2,816)	$	(1,427)	$	(34)
Offsetting amounts	—		28		151		28
Net liabilities	$	(67)	$	(2,788)	$	(1,276)	$	(6)
As of December 31, 2020
Gross assets	$	—	$	452	$	—	$	6
Offsetting amounts	—		(49)		—		(1)
Net assets	$	—	$	403	$	—	$	5
Gross liabilities	$	(140)	$	(184)	$	(163)	$	(62)
Offsetting amounts	—		21		29		35
Net liabilities	$	(140)	$	(163)	$	(134)	$	(27)

XML

Non-Controlling Interest and Variable Interest Entity

9 Months Ended

Sep. 30, 2021

Noncontrolling Interest and Variable Interest Entity [Abstract]

Non-Controlling Interest and Variable Interest Entity

NON-CONTROLLING INTEREST AND VARIABLE INTEREST ENTITY We own a 48.6% limited partner interest in Cheniere Partners in the form of 239.9 million common units, with the remaining non-controlling limited partner interest held by The Blackstone Group Inc., Brookfield Asset Management Inc. and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. Cheniere Partners is accounted for as a consolidated VIE. See Note 9—Non-Controlling Interest and Variable Interest Entity of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the fiscal year ended December 31, 2020 for further information.

The following table presents the summarized assets and liabilities (in millions) of Cheniere Partners, our consolidated VIE, which are included in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020. The assets in the table below may only be used to settle obligations of Cheniere Partners. In addition, there is no recourse to us for the consolidated VIE’s liabilities. The assets and liabilities in the table below include third-party assets and liabilities of Cheniere Partners only and exclude intercompany balances that eliminate in consolidation.

	September 30,		December 31,
	2021		2020
ASSETS
Current assets
Cash and cash equivalents	$	1,713	$	1,210
Restricted cash	133		97
Accounts and other receivables, net of current expected credit losses	358		318
Other current assets	283		182
Total current assets	2,487		1,807
Property, plant and equipment, net of accumulated depreciation	16,820		16,723
Other non-current assets, net	294		287
Total assets	$	19,601	$	18,817
LIABILITIES
Current liabilities
Accrued liabilities	$	846	$	658
Current debt, net of premium, discount and debt issuance costs	944		—
Other current liabilities	216		171
Total current liabilities	2,006		829
Long-term debt, net of premium, discount and debt issuance costs	17,171		17,580
Other non-current liabilities	98		126
Total liabilities	$	19,275	$	18,535

XML

Accrued Liabilities

9 Months Ended

Sep. 30, 2021

Accrued Liabilities, Current [Abstract]

Accrued Liabilities

ACCRUED LIABILITIES

As of September 30, 2021 and December 31, 2020, accrued liabilities consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Interest costs and related debt fees	$	360	$	245
Accrued natural gas purchases	900		576
LNG terminals and related pipeline costs	126		147
Compensation and benefits	88		123
Accrued LNG inventory	3		4
Accrued dividends	84		—
Other accrued liabilities	226		80
Total accrued liabilities	$	1,787	$	1,175

XML

Debt

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Debt

DEBT

As of September 30, 2021 and December 31, 2020, our debt consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Long-term debt:
SPL — 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 SPL Working Capital Facility”) (1)	$	13,128	$	13,650
Cheniere Partners — 3.250% to 5.625% senior notes due between October 2025 and January 2032 and credit facilities (“2019 CQP Credit Facilities”)	4,200		4,100
CCH — 2.742% to 7.000% senior secured notes due between June 2024 and December 2039 and CCH Credit Facility	10,128		10,217
Cheniere — 4.625% senior secured notes due October 2028 (the “2028 Cheniere Senior Notes”), convertible notes, revolving credit facility (“Cheniere Revolving Credit Facility”) and term loan facility (“Cheniere Term Loan Facility”)	2,625		3,145
Unamortized premium, discount and debt issuance costs, net of accumulated amortization	(600)		(641)
Total long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Current debt:
SPL — current portion of 6.25% senior secured notes due March 2022 (the “2022 SPL Senior Notes”) (1) (2)	522		—
Cheniere Partners — current portion of 5.625% senior notes due October 2026 (the “2026 CQP Senior Notes”) (3)	428		—
CCH — $1.2 billion CCH working capital facility (“CCH Working Capital Facility”) and current portion of CCH Credit Facility	104		271
Cheniere Marketing — trade finance facilities and letter of credit facility	—		—
Cheniere — current portion of the 4.875% convertible unsecured notes due May 2021 (“2021 Cheniere Convertible Notes”)	—		104
Unamortized discount and debt issuance costs, net of accumulated amortization	(7)		(3)
Total current debt, net of discount and debt issuance costs	1,047		372
Total debt, net of premium, discount and debt issuance costs	$	30,528	$	30,843

(1)A portion of the 2022 SPL Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 SPL Senior Notes and pay related fees, costs and expenses.

(2)In October 2021, $318 million of the 2022 SPL Senior Notes was redeemed with $100 million from the proceeds from Cheniere Partners’ issuance of the 3.250% senior notes due 2032 (the “2032 CQP Senior Notes”) and $218 million of cash on hand. See Issuances, Redemptions and Repayments section below for further discussion.

(3)In October 2021, Cheniere Partners redeemed the remaining outstanding aggregate principal amount of the 2026 CQP Senior Notes that were not purchased pursuant to the tender offer and consent solicitation in September 2021. See Issuances, Redemptions and Repayments section below for further discussion.

Issuances, Redemptions and Repayments

The following table shows the issuances, redemptions and repayments of long-term debt during the nine months ended September 30, 2021, excluding intra-quarter borrowings and repayments (in millions):

Issuances	Principal Amount Issued
Three Months Ended March 31, 2021
Cheniere Partners — 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”) (1)	$	1,500
Three Months Ended June 30, 2021
Cheniere — Cheniere Term Loan Facility (2)	220
Cheniere — Cheniere Revolving Credit Facility	134
Three Months Ended September 30, 2021
CCH — 2.742% Senior Notes due 2039 (the “2.742% CCH Senior Secured Notes”) (3)	750
Cheniere Partners — 2032 CQP Senior Notes (4)	1,200
Nine Months Ended September 30, 2021 total	$	3,804
Redemptions and Repayments	Principal Amount Redeemed/Repaid
Three Months Ended March 31, 2021
Cheniere Partners — 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) (1)	$	1,500
Cheniere — Cheniere Term Loan Facility (5)	148
Three Months Ended June 30, 2021
Cheniere — 2021 Cheniere Convertible Notes (2)	476
Cheniere — Cheniere Term Loan Facility (2)	220
Three Months Ended September 30, 2021
Cheniere — Cheniere Revolving Credit Facility	134
CCH — CCH Credit Facility (3)	866
Cheniere Partners — 2026 CQP Senior Notes (4)	672
Nine Months Ended September 30, 2021 total	$	4,016

(1)Net proceeds from the issuance of the 2031 CQP Senior Notes, together with cash on hand, were used to redeem all of Cheniere Partners’ outstanding 2025 CQP Senior Notes, resulting in $54 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs.

(2)The 2021 Cheniere Convertible Notes were repaid using a combination of borrowings under the Cheniere Term Loan Facility and cash on hand upon the maturity date at par value.

(3)Net proceeds of the 2.742% CCH Senior Secured Notes, together with cash on hand, were used to prepay a portion of the principal amount outstanding under the CCH Credit Facility, resulting in $9 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized issuance costs.

(4)Net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem a portion of the 2026 CQP Senior Notes in September 2021 pursuant to a tender offer and consent solicitation, resulting in $27 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs. In October 2021, the remaining net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 2022 SPL Senior Notes.

(5)The remaining commitments under the Cheniere Term Loan Facility were terminated in accordance with the credit agreement, resulting in $4 million of loss on extinguishment of debt relating to the write off of unamortized issuance costs.

Credit Facilities

Below is a summary of our credit facilities outstanding as of September 30, 2021 (in millions):

	2020 SPL Working Capital Facility (1)		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Original facility size	$	1,200	$	1,500	$	8,404	$	350	$	750
Incremental commitments	—		—		1,566		850		500
Less:
Outstanding balance	—		—		1,761		—		—
Commitments prepaid or terminated	—		750		8,209		—		—
Letters of credit issued	396		—		—		360		—
Available commitment	$	804	$	750	$	—	$	840	$	1,250
Priority ranking	Senior secured		Senior secured		Senior secured		Senior secured		Senior secured
Interest rate on available balance	LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750%		LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125%		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Weighted average interest rate of outstanding balance	n/a		n/a		1.83%		n/a		n/a
Maturity date	March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		December 13, 2022

(1)The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL pays a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.

Convertible Notes

Below is a summary of our convertible notes outstanding as of September 30, 2021 (in millions):

	2045 Cheniere Convertible Senior Notes
Aggregate original principal	$	625
Debt component, net of discount and debt issuance costs	$	320
Equity component	$	194
Interest payment method	Cash
Conversion by us (1)	(2)
Conversion by holders (1)	(3)
Conversion basis	Cash and/or stock
Conversion value in excess of principal	$	—
Maturity date	March 15, 2045
Contractual interest rate	4.25		%
Effective interest rate (4)	9.4		%
Remaining debt discount and debt issuance costs amortization period (5)	23.5 years

(1)Conversion is subject to various limitations and conditions, which have not been met as of the balance sheet date.

(2)Redeemable at any time at a redemption price payable in cash equal to the accreted amount of the $625 million aggregate principal amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date.

(3)Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes,

which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).

(4)Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

(5)We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity.

Restrictive Debt Covenants

The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit us, our subsidiaries’ and its restricted subsidiaries’ ability to make certain investments or pay dividends or distributions.

As of September 30, 2021, each of our issuers was in compliance with all covenants related to their respective debt agreements.

Interest Expense

Total interest expense, net of capitalized interest, including interest expense related to our convertible notes, consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Interest cost on convertible notes:
Interest per contractual rate	$	6	$	20	$	29	$	140
Amortization of debt discount	1		7		9		41
Amortization of debt issuance costs	—		1		—		8
Total interest cost related to convertible notes	7		28		38		189
Interest cost on debt and finance leases excluding convertible notes	391		388		1,178		1,167
Total interest cost	398		416		1,216		1,356
Capitalized interest	(34)		(61)		(128)		(182)
Total interest expense, net of capitalized interest	$	364	$	355	$	1,088	$	1,174

Fair Value Disclosures

The following table shows the carrying amount and estimated fair value of our debt (in millions):

	September 30, 2021				December 31, 2020
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior notes — Level 2 (1)	$	25,978	$	28,565	$	24,700	$	27,897
Senior notes — Level 3 (2)	2,771		3,317		2,771		3,423
Credit facilities — Level 3 (3)	1,761		1,761		2,915		2,915
2021 Cheniere Convertible Notes — Level 3 (2)	—		—		476		480
2045 Cheniere Convertible Senior Notes — Level 1 (4)	625		538		625		496

(1)The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.

(2)The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 

(3)The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty. (4)The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

XML

Leases

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Leases

LEASES

Our leased assets consist primarily of LNG vessel time charters (“vessel charters”) and additionally include tug vessels, office space and facilities and land sites. All of our leases are classified as operating leases except for our tug vessels supporting the Corpus Christi LNG Terminal, which are classified as finance leases.

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):

		September 30,		December 31,
	Consolidated Balance Sheets Location	2021		2020
Right-of-use assets—Operating	Operating lease assets	$	2,064	$	759
Right-of-use assets—Financing	Property, plant and equipment, net of accumulated depreciation	51		53
Total right-of-use assets		$	2,115	$	812
Current operating lease liabilities	Current operating lease liabilities	$	458	$	161
Current finance lease liabilities	Other current liabilities	2		2
Non-current operating lease liabilities	Operating lease liabilities	1,590		597
Non-current finance lease liabilities	Finance lease liabilities	57		57
Total lease liabilities		$	2,107	$	817

The following table shows the classification and location of our lease costs on our Consolidated Statements of Operations (in millions):

	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Operating lease cost (a)	Operating costs and expenses (1)	$	145	$	77	$	441	$	316
Finance lease cost:
Amortization of right-of-use assets	Depreciation and amortization expense	—		—		2		2
Interest on lease liabilities	Interest expense, net of capitalized interest	2		2		7		7
Total lease cost		$	147	$	79	$	450	$	325
(a) Included in operating lease cost:
Short-term lease costs		$	22	$	9	$	103	$	60
Variable lease costs		7		3		20		12

(1)Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

Future annual minimum lease payments for operating and finance leases as of September 30, 2021 are as follows (in millions): 

Years Ending December 31,	Operating Leases (1)		Finance Leases
2021	$	139	$	3
2022	515		10
2023	479		10
2024	433		10
2025	243		10
Thereafter	510		127
Total lease payments	2,319		170
Less: Interest	(271)		(111)
Present value of lease liabilities	$	2,048	$	59

(1)Does not include $758 million of legally binding minimum lease payments primarily for vessel charters which were executed as of September 30, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to seven years.

The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases:

	September 30, 2021		December 31, 2020
	Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	5.9	16.9	8.2	17.7
Weighted-average discount rate (1)	3.6%	16.2%	5.4%	16.2%

(1)The finance leases commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

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

	Nine Months Ended September 30,
	2021		2020
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows used in operating leases	$	331	$	226
Operating cash flows used in finance leases	7		8
Right-of-use assets obtained in exchange for operating lease liabilities	1,575		412

LNG Vessel Subcharters

From time to time, we sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. As of both September 30, 2021 and December 31, 2020, we had no future minimum sublease payments to be received from LNG vessel subcharters. The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Fixed income	$	17	$	9	$	28	$	61
Variable income	15		1		21		24
Total sublease income	$	32	$	10	$	49	$	85

XML

Revenues from Contracts with Customers

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Revenues from Contracts with Customers

REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
LNG revenues (1)	$	4,169	$	1,344	$	10,505	$	6,088
Regasification revenues	68		67		202		202
Other revenues	22		10		66		48
Total revenues from customers	4,259		1,421		10,773		6,338
Net derivative gain (loss) (2)	(1,091)		29		(1,515)		148
Other (3)	32		10		49		85
Total revenues	$	3,200	$	1,460	$	9,307	$	6,571

(1)LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2021 and 2020 excluded zero and $458 million, respectively, and LNG revenues during the nine months ended September 30, 2021 and 2020 excluded $38 million and zero, respectively, that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

(2)See Note 6—Derivative Instruments for additional information about our derivatives.

(3)Includes revenues from LNG vessel subcharters. See Note 10—Leases for additional information about our subleases.

Contract Assets and Liabilities

The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Consolidated Balance Sheets (in millions):

	September 30,		December 31,
	2021		2020
Contract assets, net of current expected credit losses	$	123	$	80

Contract assets represent our right to consideration for transferring goods or services to the customer under the terms of a sales contract when the associated consideration is not yet due. Changes in contract assets during the nine months ended September 30, 2021 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due.

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Consolidated Balance Sheets (in millions):

	Nine Months Ended September 30, 2021
Deferred revenue, beginning of period	$	138
Cash received but not yet recognized in revenue	196
Revenue recognized from prior period deferral	(138)
Deferred revenue, end of period	$	196

Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of September 30, 2021 and December 31, 2020:

	September 30, 2021			December 31, 2020
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues	$	100.6	10	$	102.3	10
Regasification revenues	1.9		4	2.1		5
Total revenues	$	102.5		$	104.4

(1)The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

We have elected the following exemptions which omit certain potential future sources of revenue from the table above:

(1)We omit from the table above all performance obligations that are part of a contract that has an original expected duration of one year or less.

(2)The table above excludes substantially all variable consideration under our SPAs and TUAs. We omit from the table above all variable consideration that is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation when that performance obligation qualifies as a series. The amount of revenue from variable fees that is not included in the transaction price will vary based on the future prices of Henry Hub throughout the contract terms, to the extent customers elect to take delivery of their LNG, and adjustments to the consumer price index. Certain of our contracts contain additional variable consideration based on the outcome of contingent events and the movement of various indexes. We have not included such variable consideration in the transaction price to the extent the consideration is considered constrained due to the uncertainty of ultimate pricing and receipt. Approximately 61% and 37% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2021 and 2020, respectively, and approximately 56% and 35% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2021 and 2020, respectively, were related to variable consideration received from customers. During each of the three and nine months ended September 30, 2021, approximately 5% of our regasification revenues were related to variable consideration received from customers and during each of the three and nine months ended September 30, 2020, approximately 6% of our regasification revenues were related to variable consideration received from customers.

We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching FID on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

XML

Related Party Transactions

9 Months Ended

Sep. 30, 2021

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

Natural Gas Supply Agreements

SPL and CCL are party to natural gas supply agreements with related parties in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the Liquefaction Projects. These related parties are partially owned by The Blackstone Group Inc., who also partially owns Cheniere Partners’ limited partner interests.

SPL Natural Gas Supply Agreement

The term of the SPL agreement is for five years, which can commence no earlier than November 1, 2021 and no later than November 1, 2022, following the achievement of contractually-defined conditions precedent. As of September 30, 2021

and December 31, 2020, the notional amount for this agreement was 99 TBtu and 91 TBtu, respectively. As of both September 30, 2021 and December 31, 2020, the agreement had a fair value of zero.

CCL Natural Gas Supply Agreement

The term of the CCL agreement extends through March 2022. Under this agreement, CCL recorded $19 million and $13 million in accrued liabilities, as of September 30, 2021 and December 31, 2020, respectively.

The Liquefaction Supply Derivatives related to this agreement are recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount):

	September 30,		December 31,
	2021		2020
Current derivative assets	$	7	$	3
Derivative assets	10		1
Notional amount (in TBtu)	119		60

We recorded the following amounts on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 related to this agreement (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Cost of sales (a)	$	53	$	29	$	124	$	77
(a) Included in costs of sales:
Liquefaction Supply Derivative gain	$	6	$	(5)	$	13	$	(3)

Natural Gas Transportation and Storage Agreements

SPL is party to various natural gas transportation and storage agreements and CTPL is party to an operational balancing agreement with a related party in the ordinary course of business for the operation of the SPL Project, with initial primary terms of up to 10 years with extension rights. This related party is partially owned by Brookfield Asset Management, Inc., who indirectly acquired a portion of Cheniere Partners’ limited partner interests in September 2020. We recorded operating and maintenance expense of $12 million and $34 million and cost of sales of zero and $1 million during the three and nine months ended September 30, 2021, respectively, and accrued liabilities of $5 million and $4 million as of September 30, 2021 and December 31, 2020, respectively, with this related party.

CCL is party to natural gas transportation agreements with Midship Pipeline Company, LLC (“Midship Pipeline”) in the ordinary course of business for the operation of the CCL Project, for a period of 10 years which began in May 2020. We account for our investment in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline, as an equity method investment. We recorded operating and maintenance expense of $2 million during both the three months ended September 30, 2021 and 2020 and $7 million and $4 million during the nine months ended September 30, 2021 and 2020, respectively. Additionally, we recorded accrued liabilities of $1 million as of both September 30, 2021 and December 31, 2020 with this related party.

Operation and Maintenance Service Agreements

Cheniere LNG O&M Services, LLC (“O&M Services”), our wholly owned subsidiary, provides the development, construction, operation and maintenance services to Midship Pipeline pursuant to agreements in which O&M Services receives an agreed upon fee and reimbursement of costs incurred. O&M Services recorded $2 million in each of the three months ended September 30, 2021 and 2020 and $5 million and $8 million in the nine months ended September 30, 2021 and 2020, respectively, of other revenues and $1 million and $2 million of accounts receivable as of September 30, 2021 and December 31, 2020, respectively, for services provided to Midship Pipeline under these agreements.

XML

Income Taxes

9 Months Ended

Sep. 30, 2021

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

We recorded an income tax benefit of $1,860 million and $1,864 million during the three and nine months ended September 30, 2021, respectively, and an income tax benefit of $75 million and income tax provision of $119 million during the three and nine months ended September 30, 2020, respectively.

The effective tax rates for the three and nine months ended September 30, 2021 were 67.0% and 79.7%, respectively. Our effective tax rate is based on income (loss) before income taxes and non-controlling interest and is significantly impacted by non-controlling interest that is not taxable to Cheniere. Our effective tax rate experienced volatility during the three and nine months ended September 30, 2021 due to variability in our earnings and the proportion of such earnings attributable to non-controlling interest. The variability in earnings in the three and nine months ended September 30, 2021 were mainly the result of approximately $3.5 billion and $4.2 billion, respectively, of pre-tax derivative losses, primarily on our commodity derivatives as a result of unfavorable shifts in international forward commodity curves.

The effective tax rates for the three and nine months ended September 30, 2020 were 12.9% and 19.3%, respectively, which were lower than the 21% federal statutory tax rate primarily due to income allocated to non-controlling interest that is not taxable to Cheniere, and in the nine months ended September 30, 2020, it was partially offset by a $38 million discrete tax expense related to an internal restructuring.

XML

Share-Based Compensation

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Share-Based Compensation

SHARE-BASED COMPENSATION

We have granted restricted stock shares, restricted stock units, performance stock units and phantom units to employees and non-employee directors under the 2011 Incentive Plan, as amended (the “2011 Plan”) and the 2020 Incentive Plan (the “2020 Plan”). For the nine months ended September 30, 2021, we granted 1.6 million restricted stock units and 0.3 million performance stock units at target performance under the 2020 Plan to certain employees. Additionally, 0.2 million incremental shares of our common stock were issued based on performance results from previously-granted performance stock unit awards.

Restricted stock units are stock awards that vest over a service period of three years and entitle the holder to receive shares of our common stock upon vesting, subject to restrictions on transfer and to a risk of forfeiture if the recipient terminates employment with us prior to the lapse of the restrictions. Performance stock units provide for cliff vesting after a period of three years with payouts based on metrics dependent upon market and performance achieved over the defined performance period compared to pre-established performance targets. The settlement amounts of the awards are based on market and performance metrics which include cumulative distributable cash flow per share, and in certain circumstances, absolute total shareholder return (“ATSR”) of our common stock. Where applicable, the compensation for performance stock units is based on fair value assigned to the market metric of ATSR using a Monte Carlo model upon grant, which remains constant through the vesting period, and a performance metric, which will vary due to changing estimates regarding the expected achievement of the performance metric of cumulative distributable cash flow per share. The number of shares that may be earned at the end of the vesting period ranges from 0% up to 300% of the target award amount. Both restricted stock units and performance stock units will be settled in Cheniere common stock (on a one-for-one basis) and are classified as equity awards, however, a portion of the performance stock units granted in 2021 will partially settle in cash, subject to individual limits. The portion of performance stock units expected to settle in Cheniere common stock (on a one-for-one basis) are classified as equity awards and the portion of performance stock units expected to settle in cash are classified as liability awards.

Total share-based compensation consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Share-based compensation costs, pre-tax:
Equity awards	$	28	$	26	$	92	$	86
Liability awards	1		1		3		2
Total share-based compensation	29		27		95		88
Capitalized share-based compensation	(1)		—		(4)		(4)
Total share-based compensation expense	$	28	$	27	$	91	$	84
Tax benefit associated with share-based compensation expense	$	3	$	2	$	30	$	21

XML

Net Income (Loss) Per Share Attributable to Common Stockholders

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Net Income (Loss) Per Share Attributable to Common Stockholders

NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

Basic net income (loss) per share attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS reflects potential dilution and is computed by dividing net income (loss) attributable to common stockholders by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued. The dilutive effect of unvested stock is calculated using the treasury-stock method and the dilutive effect of convertible securities is calculated using the if-converted method.

The following table reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net income (loss) attributable to common stockholders	$	(1,084)	$	(463)	$	(1,020)	$	109
Weighted average common shares outstanding:
Basic	253.6		252.2		253.3		252.5
Dilutive unvested stock	—		—		—		0.7
Diluted	253.6		252.2		253.3		253.2
Net income (loss) per share attributable to common stockholders—basic and diluted	$	(4.27)	$	(1.84)	$	(4.03)	$	0.43

Potentially dilutive securities that were not included in the diluted net income (loss) per share computations because their effects would have been anti-dilutive were as follows (in millions):

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021	2020	2021	2020
Unvested stock (1)	1.8	3.1	1.6	2.4
2045 Cheniere Convertible Senior Notes	4.5	4.5	4.5	4.5
Total potentially dilutive common shares	6.3	7.6	6.1	6.9

(1)Includes the impact of unvested shares containing performance conditions to the extent that the underlying performance conditions are satisfied based on actual results as of the respective dates.

XML

Stockholders' Equity

9 Months Ended

Sep. 30, 2021

Equity [Abstract]

Stockholders' Equity

STOCKHOLDERS’ EQUITY

Share Repurchase Programs

On June 3, 2019, we announced that our Board of Directors (the “Board”) authorized a three-year, $1.0 billion share repurchase program. On September 7, 2021, the Board authorized an increase in the share repurchase program to $1.0 billion, inclusive of any amounts remaining under the previous authorization as of September 30, 2021, for an additional three years beginning on October 1, 2021. The following table presents information with respect to repurchases of common stock during the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Aggregate common stock repurchased	0.1		—		0.1		2.9
Weighted average price paid per share	$	83.97	$	—	$	83.97	$	53.88
Total amount paid	$	6	$	—	$	6	$	155

As of September 30, 2021, we had up to $589 million of the share repurchase program available, which increased to $1.0 billion as of October 1, 2021.

Dividends

On September 7, 2021, we declared a quarterly dividend of $0.33 per share that is payable on November 17, 2021 to shareholders of record as of November 3, 2021. As of September 30, 2021, we had $85 million accrued related to this obligation, which is included in accrued liabilities and other non-current liabilities in our Consolidated Balance Sheets.

XML

Customer Concentration

9 Months Ended

Sep. 30, 2021

Risks and Uncertainties [Abstract]

Customer Concentration

CUSTOMER CONCENTRATION

The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with accounts receivable, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total accounts receivable, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively:

	Percentage of Total Revenues from External Customers				Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers
	Three Months Ended September 30,		Nine Months Ended September 30,		September 30,	December 31,
	2021	2020	2021	2020	2021	2020
Customer A	12%	*	14%	13%	*	14%
Customer B	15%	11%	13%	10%	*	12%
Customer C	11%	15%	11%	11%	*	*
Customer D	11%	13%	*	10%	*	*
Customer E	*	*	*	*	17%	*
Customer F	*	*	*	*	12%	*

* Less than 10%

XML

Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2021

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information

SUPPLEMENTAL CASH FLOW INFORMATION

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

	Nine Months Ended September 30,
	2021		2020
Cash paid during the period for interest on debt, net of amounts capitalized	$	902	$	977
Cash paid for income taxes, net of refunds	2		2
Non-cash investing and financing activities:
Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	234		262
Accrued and declared dividends on common stock	85		—

XML

Nature of Operations and Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation, Policy

Basis of PresentationThe accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2020.

Recent Accounting Standards

Recent Accounting Standards

In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-06, Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity. This guidance simplifies the accounting for convertible instruments primarily by eliminating the existing cash conversion and beneficial conversion models within Subtopic 470-20, which will result in fewer embedded conversion options being accounted for separately from the debt host. The guidance also amends and simplifies the calculation of earnings per share relating to convertible instruments. This guidance is effective for annual periods beginning after December 15, 2021, including interim periods within that reporting period, with earlier adoption permitted for fiscal years beginning after December 15, 2020, including interim periods within that reporting period, using either a full or modified retrospective approach. We plan to adopt

this guidance on January 1, 2022 using the modified retrospective approach. Preliminarily, we anticipate the adoption of ASU 2020-06 will primarily result in the reclassification of the previously bifurcated equity component associated with the 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to debt as a result of the elimination of the cash conversion model. We currently estimate that the reclassification of the $194 million equity component will result in an approximate $190 million increase in the carrying value of our 2045 Cheniere Convertible Senior Notes, with the difference primarily impacting retained earnings as of January 1, 2022. We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures. See Note 9—Debt for further discussion on the 2045 Cheniere Convertible Senior Notes.

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting. This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing contracts expected to arise from the market transition from LIBOR to alternative reference rates. We have various credit facilities and interest rate swaps indexed to LIBOR, as further described in Note 6—Derivative Instruments and Note 9—Debt. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time the optional expedients are no longer available.

XML

Restricted Cash (Tables)

9 Months Ended

Sep. 30, 2021

Restricted Cash [Abstract]

Schedule of Restricted Cash

As of September 30, 2021 and December 31, 2020, restricted cash consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Restricted cash
SPL Project	$	133	$	97
CCL Project	59		70
Cash held by our subsidiaries that is restricted to Cheniere	227		282
Total restricted cash	$	419	$	449

XML

Accounts and Other Receivables, Net of Current Expected Credit Losses (Tables)

9 Months Ended

Sep. 30, 2021

Receivables [Abstract]

Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses

As of September 30, 2021 and December 31, 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Trade receivables
SPL and CCL	$	584	$	482
Cheniere Marketing	272		113
Other accounts receivable	127		52
Total accounts and other receivables, net of current expected credit losses	$	983	$	647

XML

Inventory (Tables)

9 Months Ended

Sep. 30, 2021

Inventory Disclosure [Abstract]

Schedule of Inventory

As of September 30, 2021 and December 31, 2020, inventory consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
Materials	$	168	$	150
LNG in-transit	145		88
LNG	125		27
Natural gas	31		26
Other	2		1
Total inventory	$	471	$	292

XML

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)

9 Months Ended

Sep. 30, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment, Net of Accumulated Depreciation

As of September 30, 2021 and December 31, 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions):

	September 30,		December 31,
	2021		2020
LNG terminal
LNG terminal and interconnecting pipeline facilities	$	30,617	$	27,475
LNG site and related costs	441		324
LNG terminal construction-in-process	2,817		5,378
Accumulated depreciation	(3,663)		(2,935)
Total LNG terminal, net of accumulated depreciation	30,212		30,242
Fixed assets and other
Computer and office equipment	27		25
Furniture and fixtures	20		19
Computer software	122		117
Leasehold improvements	45		45
Land	1		59
Other	21		25
Accumulated depreciation	(181)		(164)
Total fixed assets and other, net of accumulated depreciation	55		126
Assets under finance lease
Tug vessels	60		60
Accumulated depreciation	(9)		(7)
Total assets under finance lease, net of accumulated depreciation	51		53
Property, plant and equipment, net of accumulated depreciation	$	30,318	$	30,421

Schedule of Depreciation and Offsets to LNG Terminal Costs

The following table shows depreciation expense and offsets to LNG terminal costs during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Depreciation expense	$	257	$	231	$	749	$	694
Offsets to LNG terminal costs (1)	—		—		227		—

(1)We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Projects during the testing phase for its construction.

XML

Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Assets and Liabilities

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 (in millions):

	Fair Value Measurements as of
	September 30, 2021								December 31, 2020
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
CCH Interest Rate Derivatives liability	$	—	$	(67)	$	—	$	(67)	$	—	$	(140)	$	—	$	(140)
Liquefaction Supply Derivatives asset (liability)	(21)		3		(2,611)		(2,629)		5		(6)		241		240
LNG Trading Derivatives asset (liability)	11		(444)		(680)		(1,113)		(3)		(131)		—		(134)
FX Derivatives asset (liability)	—		9		—		9		—		(22)		—		(22)

Fair Value Measurement Inputs and Valuation Techniques

The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives and Physical LNG Trading Derivatives as of September 30, 2021:

	Net Fair Value Liability (in millions)	Valuation Approach	Significant Unobservable Input	Range of Significant Unobservable Inputs / Weighted Average (1)
Physical Liquefaction Supply Derivatives	$(2,611)	Market approach incorporating present value techniques	Henry Hub basis spread	$(1.333) - $0.895 / $(0.006)
		Option pricing model	International LNG pricing spread, relative to Henry Hub (2)	158% - 516% / 224%
Physical LNG Trading Derivatives	$(680)	Market approach incorporating present value techniques	International LNG pricing spread, relative to Henry Hub or TTF, as applicable (2)	$(11.275) - $23.458 / $17.777

(1)Unobservable inputs were weighted by the relative fair value of the instruments.

(2)Spread contemplates U.S. dollar-denominated pricing.

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

The following table shows the changes in the fair value of our Level 3 Physical LNG Trading Derivatives and Physical Liquefaction Supply Derivatives during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Balance, beginning of period	$	(389)	$	590	$	241	$	138
Realized and mark-to-market gains (losses):
Included in cost of sales	(2,982)		(27)		(2,898)		454
Purchases and settlements:
Purchases	5		1		(657)		2
Settlements	75		(31)		23		(61)
Balance, end of period	$	(3,291)	$	533	$	(3,291)	$	533
Change in unrealized gains (losses) relating to instruments still held at end of period	$	(2,982)	$	(27)	$	(2,898)	$	454

Fair Value of Derivative Instruments by Balance Sheet Location

The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions):

	September 30, 2021
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	88	$	163	$	15	$	266
Derivative assets	—		71		—		—		71
Total derivative assets	—		159		163		15		337
Current derivative liabilities	(67)		(630)		(1,276)		(6)		(1,979)
Derivative liabilities	—		(2,158)		—		—		(2,158)
Total derivative liabilities	(67)		(2,788)		(1,276)		(6)		(4,137)
Derivative asset (liability), net	$	(67)	$	(2,629)	$	(1,113)	$	9	$	(3,800)
	December 31, 2020
	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives (1)		LNG Trading Derivatives (2)		FX Derivatives		Total
Consolidated Balance Sheets Location
Current derivative assets	$	—	$	27	$	—	$	5	$	32
Derivative assets	—		376		—		—		376
Total derivative assets	—		403		—		5		408
Current derivative liabilities	(100)		(54)		(134)		(25)		(313)
Derivative liabilities	(40)		(109)		—		(2)		(151)
Total derivative liabilities	(140)		(163)		(134)		(27)		(464)
Derivative asset (liability), net	$	(140)	$	240	$	(134)	$	(22)	$	(56)

(1)Does not include collateral posted with counterparties by us of $47 million and $9 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes derivative assets for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

(2)Does not include collateral posted with counterparties by us of $287 million and $7 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively.

Derivative Net Presentation on Consolidated Balance Sheets

The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions):

	CCH Interest Rate Derivatives		Liquefaction Supply Derivatives		LNG Trading Derivatives		FX Derivatives
As of September 30, 2021
Gross assets	$	—	$	179	$	174	$	30
Offsetting amounts	—		(20)		(11)		(15)
Net assets	$	—	$	159	$	163	$	15
Gross liabilities	$	(67)	$	(2,816)	$	(1,427)	$	(34)
Offsetting amounts	—		28		151		28
Net liabilities	$	(67)	$	(2,788)	$	(1,276)	$	(6)
As of December 31, 2020
Gross assets	$	—	$	452	$	—	$	6
Offsetting amounts	—		(49)		—		(1)
Net assets	$	—	$	403	$	—	$	5
Gross liabilities	$	(140)	$	(184)	$	(163)	$	(62)
Offsetting amounts	—		21		29		35
Net liabilities	$	(140)	$	(163)	$	(134)	$	(27)

Interest Rate Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Schedule of Notional Amounts of Outstanding Derivative Positions

As of September 30, 2021, we had the following Interest Rate Derivatives outstanding:

	Notional Amounts
	September 30, 2021	December 31, 2020	Latest Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
CCH Interest Rate Derivatives	$4.5 billion	$4.6 billion	May 31, 2022	2.30%	One-month LIBOR

Derivative Instruments, Gain (Loss)

The following table shows the effect and location of our Interest Rate Derivatives on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
CCH Interest Rate Derivatives	Interest rate derivative loss, net	$	(2)	$	—	$	(3)	$	(138)
CCH Interest Rate Forward Start Derivatives	Interest rate derivative loss, net	—		—		—		(95)

Commodity Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Schedule of Notional Amounts of Outstanding Derivative Positions

The following table shows the notional amounts of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”):

	September 30, 2021		December 31, 2020
	Liquefaction Supply Derivatives	LNG Trading Derivatives	Liquefaction Supply Derivatives	LNG Trading Derivatives
Notional amount, net (in TBtu) (1)	11,291	(14)	10,483	20

(1)Includes notional amounts for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

Derivative Instruments, Gain (Loss)

The following table shows the effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location (1)	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
LNG Trading Derivatives	LNG revenues	$	(1,098)	$	13	$	(1,539)	$	119
LNG Trading Derivatives	Cost of sales	55		(5)		136		(5)
Liquefaction Supply Derivatives (2)	LNG revenues	(4)		21		(3)		7
Liquefaction Supply Derivatives (2)	Cost of sales	(2,444)		(103)		(2,848)		372

(1)Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

(2)Does not include the realized value associated with derivative instruments that settle through physical delivery.

FX Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Derivative Instruments, Gain (Loss)

The following table shows the effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions):

		Gain (Loss) Recognized in Consolidated Statements of Operations
	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
FX Derivatives	LNG revenues	$	11	$	(5)	$	27	$	22

XML

Non-Controlling Interest and Variable Interest Entity (Tables)

9 Months Ended

Sep. 30, 2021

Cheniere Partners [Member]

Noncontrolling Interest and Variable Interest Entity [Line Items]

Condensed Balance Sheet of Cheniere Partners

The following table presents the summarized assets and liabilities (in millions) of Cheniere Partners, our consolidated VIE, which are included in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020. The assets in the table below may only be used to settle obligations of Cheniere Partners. In addition, there is no recourse to us for the consolidated VIE’s liabilities. The assets and liabilities in the table below include third-party assets and liabilities of Cheniere Partners only and exclude intercompany balances that eliminate in consolidation.

	September 30,		December 31,
	2021		2020
ASSETS
Current assets
Cash and cash equivalents	$	1,713	$	1,210
Restricted cash	133		97
Accounts and other receivables, net of current expected credit losses	358		318
Other current assets	283		182
Total current assets	2,487		1,807
Property, plant and equipment, net of accumulated depreciation	16,820		16,723
Other non-current assets, net	294		287
Total assets	$	19,601	$	18,817
LIABILITIES
Current liabilities
Accrued liabilities	$	846	$	658
Current debt, net of premium, discount and debt issuance costs	944		—
Other current liabilities	216		171
Total current liabilities	2,006		829
Long-term debt, net of premium, discount and debt issuance costs	17,171		17,580
Other non-current liabilities	98		126
Total liabilities	$	19,275	$	18,535

XML

Accrued Liabilities (Tables)

9 Months Ended

Sep. 30, 2021

Accrued Liabilities, Current [Abstract]

Schedule of Accrued Liabilities

As of September 30, 2021 and December 31, 2020, accrued liabilities consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Interest costs and related debt fees	$	360	$	245
Accrued natural gas purchases	900		576
LNG terminals and related pipeline costs	126		147
Compensation and benefits	88		123
Accrued LNG inventory	3		4
Accrued dividends	84		—
Other accrued liabilities	226		80
Total accrued liabilities	$	1,787	$	1,175

XML

Debt (Tables)

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Schedule of Debt Instruments

As of September 30, 2021 and December 31, 2020, our debt consisted of the following (in millions): 

	September 30,		December 31,
	2021		2020
Long-term debt:
SPL — 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 SPL Working Capital Facility”) (1)	$	13,128	$	13,650
Cheniere Partners — 3.250% to 5.625% senior notes due between October 2025 and January 2032 and credit facilities (“2019 CQP Credit Facilities”)	4,200		4,100
CCH — 2.742% to 7.000% senior secured notes due between June 2024 and December 2039 and CCH Credit Facility	10,128		10,217
Cheniere — 4.625% senior secured notes due October 2028 (the “2028 Cheniere Senior Notes”), convertible notes, revolving credit facility (“Cheniere Revolving Credit Facility”) and term loan facility (“Cheniere Term Loan Facility”)	2,625		3,145
Unamortized premium, discount and debt issuance costs, net of accumulated amortization	(600)		(641)
Total long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Current debt:
SPL — current portion of 6.25% senior secured notes due March 2022 (the “2022 SPL Senior Notes”) (1) (2)	522		—
Cheniere Partners — current portion of 5.625% senior notes due October 2026 (the “2026 CQP Senior Notes”) (3)	428		—
CCH — $1.2 billion CCH working capital facility (“CCH Working Capital Facility”) and current portion of CCH Credit Facility	104		271
Cheniere Marketing — trade finance facilities and letter of credit facility	—		—
Cheniere — current portion of the 4.875% convertible unsecured notes due May 2021 (“2021 Cheniere Convertible Notes”)	—		104
Unamortized discount and debt issuance costs, net of accumulated amortization	(7)		(3)
Total current debt, net of discount and debt issuance costs	1,047		372
Total debt, net of premium, discount and debt issuance costs	$	30,528	$	30,843

(1)A portion of the 2022 SPL Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 SPL Senior Notes and pay related fees, costs and expenses.

(2)In October 2021, $318 million of the 2022 SPL Senior Notes was redeemed with $100 million from the proceeds from Cheniere Partners’ issuance of the 3.250% senior notes due 2032 (the “2032 CQP Senior Notes”) and $218 million of cash on hand. See Issuances, Redemptions and Repayments section below for further discussion.

(3)In October 2021, Cheniere Partners redeemed the remaining outstanding aggregate principal amount of the 2026 CQP Senior Notes that were not purchased pursuant to the tender offer and consent solicitation in September 2021. See Issuances, Redemptions and Repayments section below for further discussion.

Schedule Of Debt Issuances, Redemptions And Repayments

The following table shows the issuances, redemptions and repayments of long-term debt during the nine months ended September 30, 2021, excluding intra-quarter borrowings and repayments (in millions):

Issuances	Principal Amount Issued
Three Months Ended March 31, 2021
Cheniere Partners — 4.000% Senior Notes due 2031 (the “2031 CQP Senior Notes”) (1)	$	1,500
Three Months Ended June 30, 2021
Cheniere — Cheniere Term Loan Facility (2)	220
Cheniere — Cheniere Revolving Credit Facility	134
Three Months Ended September 30, 2021
CCH — 2.742% Senior Notes due 2039 (the “2.742% CCH Senior Secured Notes”) (3)	750
Cheniere Partners — 2032 CQP Senior Notes (4)	1,200
Nine Months Ended September 30, 2021 total	$	3,804
Redemptions and Repayments	Principal Amount Redeemed/Repaid
Three Months Ended March 31, 2021
Cheniere Partners — 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) (1)	$	1,500
Cheniere — Cheniere Term Loan Facility (5)	148
Three Months Ended June 30, 2021
Cheniere — 2021 Cheniere Convertible Notes (2)	476
Cheniere — Cheniere Term Loan Facility (2)	220
Three Months Ended September 30, 2021
Cheniere — Cheniere Revolving Credit Facility	134
CCH — CCH Credit Facility (3)	866
Cheniere Partners — 2026 CQP Senior Notes (4)	672
Nine Months Ended September 30, 2021 total	$	4,016

(1)Net proceeds from the issuance of the 2031 CQP Senior Notes, together with cash on hand, were used to redeem all of Cheniere Partners’ outstanding 2025 CQP Senior Notes, resulting in $54 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs.

(2)The 2021 Cheniere Convertible Notes were repaid using a combination of borrowings under the Cheniere Term Loan Facility and cash on hand upon the maturity date at par value.

(3)Net proceeds of the 2.742% CCH Senior Secured Notes, together with cash on hand, were used to prepay a portion of the principal amount outstanding under the CCH Credit Facility, resulting in $9 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized issuance costs.

(4)Net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem a portion of the 2026 CQP Senior Notes in September 2021 pursuant to a tender offer and consent solicitation, resulting in $27 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs. In October 2021, the remaining net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 2022 SPL Senior Notes.

(5)The remaining commitments under the Cheniere Term Loan Facility were terminated in accordance with the credit agreement, resulting in $4 million of loss on extinguishment of debt relating to the write off of unamortized issuance costs.

Schedule of Line of Credit Facilities and Delayed Draw Term Loan

Below is a summary of our credit facilities outstanding as of September 30, 2021 (in millions):

	2020 SPL Working Capital Facility (1)		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Original facility size	$	1,200	$	1,500	$	8,404	$	350	$	750
Incremental commitments	—		—		1,566		850		500
Less:
Outstanding balance	—		—		1,761		—		—
Commitments prepaid or terminated	—		750		8,209		—		—
Letters of credit issued	396		—		—		360		—
Available commitment	$	804	$	750	$	—	$	840	$	1,250
Priority ranking	Senior secured		Senior secured		Senior secured		Senior secured		Senior secured
Interest rate on available balance	LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750%		LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125%		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Weighted average interest rate of outstanding balance	n/a		n/a		1.83%		n/a		n/a
Maturity date	March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		December 13, 2022

(1)The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL pays a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.

Schedule of Convertible Debt

Below is a summary of our convertible notes outstanding as of September 30, 2021 (in millions):

	2045 Cheniere Convertible Senior Notes
Aggregate original principal	$	625
Debt component, net of discount and debt issuance costs	$	320
Equity component	$	194
Interest payment method	Cash
Conversion by us (1)	(2)
Conversion by holders (1)	(3)
Conversion basis	Cash and/or stock
Conversion value in excess of principal	$	—
Maturity date	March 15, 2045
Contractual interest rate	4.25		%
Effective interest rate (4)	9.4		%
Remaining debt discount and debt issuance costs amortization period (5)	23.5 years

(1)Conversion is subject to various limitations and conditions, which have not been met as of the balance sheet date.

(2)Redeemable at any time at a redemption price payable in cash equal to the accreted amount of the $625 million aggregate principal amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date.

(3)Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes,

which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).

(4)Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

(5)We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity.

Schedule of Interest Expense

Total interest expense, net of capitalized interest, including interest expense related to our convertible notes, consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Interest cost on convertible notes:
Interest per contractual rate	$	6	$	20	$	29	$	140
Amortization of debt discount	1		7		9		41
Amortization of debt issuance costs	—		1		—		8
Total interest cost related to convertible notes	7		28		38		189
Interest cost on debt and finance leases excluding convertible notes	391		388		1,178		1,167
Total interest cost	398		416		1,216		1,356
Capitalized interest	(34)		(61)		(128)		(182)
Total interest expense, net of capitalized interest	$	364	$	355	$	1,088	$	1,174

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments

The following table shows the carrying amount and estimated fair value of our debt (in millions):

	September 30, 2021				December 31, 2020
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior notes — Level 2 (1)	$	25,978	$	28,565	$	24,700	$	27,897
Senior notes — Level 3 (2)	2,771		3,317		2,771		3,423
Credit facilities — Level 3 (3)	1,761		1,761		2,915		2,915
2021 Cheniere Convertible Notes — Level 3 (2)	—		—		476		480
2045 Cheniere Convertible Senior Notes — Level 1 (4)	625		538		625		496

(1)The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.

(2)The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 

(3)The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty. (4)The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

XML

Leases (Tables)

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Schedule of Leases, Balance Sheet Location

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):

		September 30,		December 31,
	Consolidated Balance Sheets Location	2021		2020
Right-of-use assets—Operating	Operating lease assets	$	2,064	$	759
Right-of-use assets—Financing	Property, plant and equipment, net of accumulated depreciation	51		53
Total right-of-use assets		$	2,115	$	812
Current operating lease liabilities	Current operating lease liabilities	$	458	$	161
Current finance lease liabilities	Other current liabilities	2		2
Non-current operating lease liabilities	Operating lease liabilities	1,590		597
Non-current finance lease liabilities	Finance lease liabilities	57		57
Total lease liabilities		$	2,107	$	817

Schedule of Lease Cost, Income Statement Location

The following table shows the classification and location of our lease costs on our Consolidated Statements of Operations (in millions):

	Consolidated Statements of Operations Location	Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Operating lease cost (a)	Operating costs and expenses (1)	$	145	$	77	$	441	$	316
Finance lease cost:
Amortization of right-of-use assets	Depreciation and amortization expense	—		—		2		2
Interest on lease liabilities	Interest expense, net of capitalized interest	2		2		7		7
Total lease cost		$	147	$	79	$	450	$	325
(a) Included in operating lease cost:
Short-term lease costs		$	22	$	9	$	103	$	60
Variable lease costs		7		3		20		12

(1)Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

Schedule of Maturity of Lease Liabilities

Future annual minimum lease payments for operating and finance leases as of September 30, 2021 are as follows (in millions): 

Years Ending December 31,	Operating Leases (1)		Finance Leases
2021	$	139	$	3
2022	515		10
2023	479		10
2024	433		10
2025	243		10
Thereafter	510		127
Total lease payments	2,319		170
Less: Interest	(271)		(111)
Present value of lease liabilities	$	2,048	$	59

(1)Does not include $758 million of legally binding minimum lease payments primarily for vessel charters which were executed as of September 30, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to seven years.

Lease, Other Quantitative Information

The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases:

	September 30, 2021		December 31, 2020
	Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	5.9	16.9	8.2	17.7
Weighted-average discount rate (1)	3.6%	16.2%	5.4%	16.2%

(1)The finance leases commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

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

	Nine Months Ended September 30,
	2021		2020
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows used in operating leases	$	331	$	226
Operating cash flows used in finance leases	7		8
Right-of-use assets obtained in exchange for operating lease liabilities	1,575		412

Schedule of Sublease Income

The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Fixed income	$	17	$	9	$	28	$	61
Variable income	15		1		21		24
Total sublease income	$	32	$	10	$	49	$	85

XML

Revenues from Contracts with Customers (Tables)

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following table represents a disaggregation of revenue earned from contracts with customers during the three and nine months ended September 30, 2021 and 2020 (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
LNG revenues (1)	$	4,169	$	1,344	$	10,505	$	6,088
Regasification revenues	68		67		202		202
Other revenues	22		10		66		48
Total revenues from customers	4,259		1,421		10,773		6,338
Net derivative gain (loss) (2)	(1,091)		29		(1,515)		148
Other (3)	32		10		49		85
Total revenues	$	3,200	$	1,460	$	9,307	$	6,571

(1)LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2021 and 2020 excluded zero and $458 million, respectively, and LNG revenues during the nine months ended September 30, 2021 and 2020 excluded $38 million and zero, respectively, that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

(2)See Note 6—Derivative Instruments for additional information about our derivatives.

(3)Includes revenues from LNG vessel subcharters. See Note 10—Leases for additional information about our subleases.

Contract Assets

The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Consolidated Balance Sheets (in millions):

	September 30,		December 31,
	2021		2020
Contract assets, net of current expected credit losses	$	123	$	80

Contract Liabilities

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Consolidated Balance Sheets (in millions):

	Nine Months Ended September 30, 2021
Deferred revenue, beginning of period	$	138
Cash received but not yet recognized in revenue	196
Revenue recognized from prior period deferral	(138)
Deferred revenue, end of period	$	196

Transaction Price Allocated to Future Performance Obligations

The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of September 30, 2021 and December 31, 2020:

	September 30, 2021			December 31, 2020
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues	$	100.6	10	$	102.3	10
Regasification revenues	1.9		4	2.1		5
Total revenues	$	102.5		$	104.4

(1)The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

XML

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2021

Natural Gas Supply Agreement [Member]

Related Party Transaction [Line Items]

Schedule of Related Party Transactions

The Liquefaction Supply Derivatives related to this agreement are recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount):

	September 30,		December 31,
	2021		2020
Current derivative assets	$	7	$	3
Derivative assets	10		1
Notional amount (in TBtu)	119		60

We recorded the following amounts on our Consolidated Statements of Operations during the three and nine months ended September 30, 2021 and 2020 related to this agreement (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Cost of sales (a)	$	53	$	29	$	124	$	77
(a) Included in costs of sales:
Liquefaction Supply Derivative gain	$	6	$	(5)	$	13	$	(3)

XML

Share-Based Compensation (Tables)

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Schedule of Share-based Compensation Expense, Net

Total share-based compensation consisted of the following (in millions):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Share-based compensation costs, pre-tax:
Equity awards	$	28	$	26	$	92	$	86
Liability awards	1		1		3		2
Total share-based compensation	29		27		95		88
Capitalized share-based compensation	(1)		—		(4)		(4)
Total share-based compensation expense	$	28	$	27	$	91	$	84
Tax benefit associated with share-based compensation expense	$	3	$	2	$	30	$	21

XML

Net Income (Loss) Per Share Attributable to Common Stockholders (Tables)

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The following table reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net income (loss) attributable to common stockholders	$	(1,084)	$	(463)	$	(1,020)	$	109
Weighted average common shares outstanding:
Basic	253.6		252.2		253.3		252.5
Dilutive unvested stock	—		—		—		0.7
Diluted	253.6		252.2		253.3		253.2
Net income (loss) per share attributable to common stockholders—basic and diluted	$	(4.27)	$	(1.84)	$	(4.03)	$	0.43

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

Potentially dilutive securities that were not included in the diluted net income (loss) per share computations because their effects would have been anti-dilutive were as follows (in millions):

	Three Months Ended September 30,		Nine Months Ended September 30,
	2021	2020	2021	2020
Unvested stock (1)	1.8	3.1	1.6	2.4
2045 Cheniere Convertible Senior Notes	4.5	4.5	4.5	4.5
Total potentially dilutive common shares	6.3	7.6	6.1	6.9

(1)Includes the impact of unvested shares containing performance conditions to the extent that the underlying performance conditions are satisfied based on actual results as of the respective dates.

XML

Stockholders' Equity (Tables)

9 Months Ended

Sep. 30, 2021

Equity [Abstract]

Schedule of Share Repurchases Under the Share Repurchase Program

The following table presents information with respect to repurchases of common stock during the three and nine months ended September 30, 2021 and 2020 (in millions, except per share data):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Aggregate common stock repurchased	0.1		—		0.1		2.9
Weighted average price paid per share	$	83.97	$	—	$	83.97	$	53.88
Total amount paid	$	6	$	—	$	6	$	155

XML

Customer Concentration (Tables)

9 Months Ended

Sep. 30, 2021

Risks and Uncertainties [Abstract]

Schedule of Revenue and Accounts Receivable by Major Customers

The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with accounts receivable, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total accounts receivable, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively:

	Percentage of Total Revenues from External Customers				Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers
	Three Months Ended September 30,		Nine Months Ended September 30,		September 30,	December 31,
	2021	2020	2021	2020	2021	2020
Customer A	12%	*	14%	13%	*	14%
Customer B	15%	11%	13%	10%	*	12%
Customer C	11%	15%	11%	11%	*	*
Customer D	11%	13%	*	10%	*	*
Customer E	*	*	*	*	17%	*
Customer F	*	*	*	*	12%	*

* Less than 10%

XML

Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2021

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

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

	Nine Months Ended September 30,
	2021		2020
Cash paid during the period for interest on debt, net of amounts capitalized	$	902	$	977
Cash paid for income taxes, net of refunds	2		2
Non-cash investing and financing activities:
Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	234		262
Accrued and declared dividends on common stock	85		—

XML

Organization and Nature of Operations (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($) milliontonnes / yr mi unit item trains
Nature of Operations and Basis of Presentation [Line Items]
Number Of Natural Gas Liquefaction And Export Facilities | unit	2
2045 Cheniere Convertible Senior Notes [Member]
Nature of Operations and Basis of Presentation [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Equity component | $	$ 194
Accounting Standards Update 2020-06 | 2045 Cheniere Convertible Senior Notes [Member]
Nature of Operations and Basis of Presentation [Line Items]
Equity component | $	194
IncreaseDecreaseDebtInstrumentConvertibleCarryingAmount | $	$ 190
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating	5
Number of Liquefaction LNG Trains Commissioning	1
Total Production Capability | milliontonnes / yr	30
Number of LNG Storage Tanks | unit	5
Number of Marine Berths Operating | item	2
Number of Marine Berths Constructing | item	1
Creole Trail Pipeline [Member]
Nature of Operations and Basis of Presentation [Line Items]
Length of Natural Gas Pipeline | mi	94
Corpus Christi LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating	3
Total Production Capability | milliontonnes / yr	15
Number of LNG Storage Tanks | unit	3
Number of Marine Berths Operating | item	2
Corpus Christi Pipeline [Member]
Nature of Operations and Basis of Presentation [Line Items]
Length of Natural Gas Pipeline | mi	23
Corpus Christi LNG Terminal Expansion [Member]
Nature of Operations and Basis of Presentation [Line Items]
Total Production Capability | milliontonnes / yr	10
Corpus Christi LNG Terminal Expansion [Member] | Maximum [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains	7
Cheniere Partners [Member]
Nature of Operations and Basis of Presentation [Line Items]
General Partner ownership percentage	100.00%
Limited Partner ownership percentage	48.60%

XML

Restricted Cash (Details) - USD ($) $ in Millions	Sep. 30, 2021		Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 419	[1]	$ 449
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	133		97
CCL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	59		70
Cash held by our subsidiaries restricted to Cheniere [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 227		$ 282

[1] Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

XML

Accounts and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Accounts and Other Receivables [Line Items]
Other accounts receivable	$ 127	$ 52
Total accounts and other receivables, net of current expected credit losses	983	647
SPL and CCL
Accounts and Other Receivables [Line Items]
Trade receivables	584	482
Cheniere Marketing
Accounts and Other Receivables [Line Items]
Trade receivables	$ 272	$ 113

XML

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Inventory [Line Items]
Inventory	$ 471	$ 292
Materials [Member]
Inventory [Line Items]
Inventory	168	150
LNG in-transit [Member]
Inventory [Line Items]
Inventory	145	88
LNG [Member]
Inventory [Line Items]
Inventory	125	27
Natural gas [Member]
Inventory [Line Items]
Inventory	31	26
Other [Member]
Inventory [Line Items]
Inventory	$ 2	$ 1

XML

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Property, Plant and Equipment, Net of Accumulated Depreciation (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 30,318	$ 30,421
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(3,663)	(2,935)
Property, plant and equipment, net of accumulated depreciation	30,212	30,242
LNG terminal and interconnecting pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	30,617	27,475
LNG site and related costs [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	441	324
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,817	5,378
Fixed assets and other [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(181)	(164)
Property, plant and equipment, net of accumulated depreciation	55	126
Computer and office equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	27	25
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	20	19
Computer software [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	122	117
Leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	45	45
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1	59
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	21	25
Tug vessels under finance lease [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	60	60
Accumulated depreciation	(9)	(7)
Property, plant and equipment, net of accumulated depreciation	$ 51	$ 53

XML

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Depreciation and Offsets to LNG Terminal Costs (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 257	$ 231	$ 749	$ 694
Offsets to LNG terminal costs	[1]	$ 0	$ 0	$ 227	$ 0

[1] We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Projects during the testing phase for its construction.

XML

Derivative Instruments - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	15 years
Financial Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	3 years
LNG Trading Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	2 years
FX Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount	$ 499	$ 786
FX Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	1 year

XML

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
CCH Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (67)	$ (140)
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(67)	(140)
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(2,629)	240
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(21)	5
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	3	(6)
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(2,611)	241
LNG Trading Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(1,113)	(134)
LNG Trading Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	11	(3)
LNG Trading Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(444)	(131)
LNG Trading Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(680)	0
FX Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	9	(22)
FX Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
FX Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	9	(22)
FX Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ 0

XML

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Fair Value, Inputs, Level 3 [Member]	9 Months Ended
	Sep. 30, 2021 USD ($)
Physical Liquefaction Supply Derivatives [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Net Fair Value Asset (Liability)	$ (2,611,000,000)
Physical Liquefaction Supply Derivatives [Member] | Valuation, Market Approach [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	(1.333)	[1]
Physical Liquefaction Supply Derivatives [Member] | Valuation, Market Approach [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	0.895	[1]
Physical Liquefaction Supply Derivatives [Member] | Valuation, Market Approach [Member] | Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	$ (0.006)	[1]
Physical Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	158.00%	[1],[2]
Physical Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	516.00%	[1],[2]
Physical Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model [Member] | Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	224.00%	[1],[2]
Physical LNG Trading Derivative [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Net Fair Value Asset (Liability)	$ (680,000,000)
Physical LNG Trading Derivative [Member] | Valuation, Market Approach [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	(11.275)	[1],[2]
Physical LNG Trading Derivative [Member] | Valuation, Market Approach [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	23.458	[1],[2]
Physical LNG Trading Derivative [Member] | Valuation, Market Approach [Member] | Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	$ 17.777	[1],[2]

[1] Unobservable inputs were weighted by the relative fair value of the instruments.

[2] Spread contemplates U.S. dollar-denominated pricing.

XML

Derivative Instruments - Schedule of Level 3 Derivatives Activity (Details) - Physical Liquefaction Supply Derivatives and Physical LNG Trading Derivative - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period	$ (389)	$ 590	$ 241	$ 138
Realized and mark-to-market gains (losses):
Included in cost of sales	(2,982)	(27)	(2,898)	454
Purchases and settlements:
Purchases	5	1	(657)	2
Settlements	75	(31)	23	(61)
Balance, end of period	(3,291)	533	(3,291)	533
Change in unrealized gains (losses) relating to instruments still held at end of period	$ (2,982)	$ (27)	$ (2,898)	$ 454

XML

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) $ in Billions		9 Months Ended
		Sep. 30, 2021 USD ($) tbtu	Dec. 31, 2020 USD ($) tbtu
CCH Interest Rate Derivatives [Member]
Derivative [Line Items]
Derivative, Notional Amount | $		$ 4.5	$ 4.6
Maturity Date		May 31, 2022
Weighted Average Fixed Interest Rate Paid		2.30%
Liquefaction Supply Derivatives [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	[1]	11,291	10,483
LNG Trading Derivatives [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	[1]	(14)	20

[1] Includes notional amounts for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

XML

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
CCH Interest Rate Derivatives [Member] | Interest rate derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ (2)	$ 0	$ (3)	$ (138)
CCH Interest Rate Forward Start Derivatives [Member] | Interest rate derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		0	0	0	(95)
LNG Trading Derivatives [Member] | LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	(1,098)	13	(1,539)	119
LNG Trading Derivatives [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	55	(5)	136	(5)
Liquefaction Supply Derivatives [Member] | LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1],[2]	(4)	21	(3)	7
Liquefaction Supply Derivatives [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1],[2]	(2,444)	(103)	(2,848)	372
FX Derivatives [Member] | LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ 11	$ (5)	$ 27	$ 22

[1] Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.

[2] Does not include the realized value associated with derivative instruments that settle through physical delivery.

XML

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 266	$ 32
Derivative assets		71	376
Total derivative assets		337	408
Current derivative liabilities		(1,979)	(313)
Derivative liabilities		(2,158)	(151)
Total derivative liabilities		(4,137)	(464)
Derivative asset (liability), net		(3,800)	(56)
Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets		266	32
Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		71	376
Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities		(1,979)	(313)
Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(2,158)	(151)
CCH Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		0	0
Total derivative liabilities		(67)	(140)
Derivative asset (liability), net		(67)	(140)
CCH Interest Rate Derivatives [Member] | Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets		0	0
CCH Interest Rate Derivatives [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		0	0
CCH Interest Rate Derivatives [Member] | Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities		(67)	(100)
CCH Interest Rate Derivatives [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		0	(40)
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	159	403
Total derivative liabilities	[1]	(2,788)	(163)
Derivative asset (liability), net	[1]	(2,629)	240
Derivative, collateral posted by us		47	9
Liquefaction Supply Derivatives [Member] | Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	88	27
Liquefaction Supply Derivatives [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	71	376
Liquefaction Supply Derivatives [Member] | Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(630)	(54)
Liquefaction Supply Derivatives [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	(2,158)	(109)
LNG Trading Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[2]	163	0
Total derivative liabilities	[2]	(1,276)	(134)
Derivative asset (liability), net	[2]	(1,113)	(134)
Derivative, collateral posted by us		287	7
LNG Trading Derivatives [Member] | Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[2]	163	0
LNG Trading Derivatives [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[2]	0	0
LNG Trading Derivatives [Member] | Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[2]	(1,276)	(134)
LNG Trading Derivatives [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[2]	0	0
FX Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		15	5
Total derivative liabilities		(6)	(27)
Derivative asset (liability), net		9	(22)
FX Derivatives [Member] | Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets		15	5
FX Derivatives [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		0	0
FX Derivatives [Member] | Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities		(6)	(25)
FX Derivatives [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		$ 0	$ (2)

[1] Does not include collateral posted with counterparties by us of $47 million and $9 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes derivative assets for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

[2] Does not include collateral posted with counterparties by us of $287 million and $7 million, which are included in margin deposits and other current assets in our Consolidated Balance Sheets as of September 30, 2021 and December 31, 2020, respectively.

XML

Derivative Instruments - Derivative Net Presentation on Consolidated Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
CCH Interest Rate Derivative Asset
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 0	$ 0
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	0	0
CCH Interest Rate Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(67)	(140)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(67)	(140)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	179	452
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(20)	(49)
Derivative Assets (Liabilities), at Fair Value, Net	159	403
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(2,816)	(184)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	28	21
Derivative Assets (Liabilities), at Fair Value, Net	(2,788)	(163)
LNG Trading Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	174	0
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(11)	0
Derivative Assets (Liabilities), at Fair Value, Net	163	0
LNG Trading Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(1,427)	(163)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	151	29
Derivative Assets (Liabilities), at Fair Value, Net	(1,276)	(134)
FX Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	30	6
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(15)	(1)
Derivative Assets (Liabilities), at Fair Value, Net	15	5
FX Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(34)	(62)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	28	35
Derivative Assets (Liabilities), at Fair Value, Net	$ (6)	$ (27)

XML

Non-Controlling Interest and Variable Interest Entity (Details) - USD ($) shares in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2021		Dec. 31, 2020
Noncontrolling Interest and Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 2,203	[1]	$ 1,628
Restricted cash	419	[1]	449
Accounts and other receivables, net of current expected credit losses	983		647
Other current assets	185		96
Total current assets	4,863		3,169
Property, plant and equipment, net of accumulated depreciation	30,318		30,421
Other non-current assets, net	425		406
Total assets	40,179	[1]	35,697
Accrued liabilities	1,787		1,175
Current debt, net of discount and debt issuance costs	1,047		372
Other current liabilities	129		2
Total current liabilities	5,660		2,196
Long-term debt, net of premium, discount and debt issuance costs	29,481		30,471
Other non-current liabilities	$ 20		7
Cheniere Partners [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Limited Partner ownership percentage	48.60%
General Partner ownership percentage	100.00%
Cheniere Partners [Member] | Common Units [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Partners Capital Account, Units, Units Held	239.9
Cheniere Partners [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 1,713		1,210
Restricted cash	133		97
Accounts and other receivables, net of current expected credit losses	358		318
Other current assets	283		182
Total current assets	2,487		1,807
Property, plant and equipment, net of accumulated depreciation	16,820		16,723
Other non-current assets, net	294		287
Total assets	19,601		18,817
Accrued liabilities	846		658
Current debt, net of discount and debt issuance costs	944		0
Other current liabilities	216		171
Total current liabilities	2,006		829
Long-term debt, net of premium, discount and debt issuance costs	17,171		17,580
Other non-current liabilities	98		126
Total liabilities	$ 19,275		$ 18,535

[1] Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 7— Non-controlling Interest and Variable Interest Entity. As of September 30, 2021, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.6 billion and $19.3 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

XML

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 360	$ 245
Accrued natural gas purchases	900	576
LNG terminals and related pipeline costs	126	147
Compensation and benefits	88	123
Accrued LNG inventory	3	4
Accrued dividends	84	0
Other accrued liabilities	226	80
Total accrued liabilities	$ 1,787	$ 1,175

XML

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended	9 Months Ended
		Oct. 31, 2021	Sep. 30, 2021	Sep. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Total Long-Term Debt, Net of Premium, Discount and Debt Issuance Costs			$ 29,481	$ 29,481	$ 30,471
Total current debt, net of discount and debt issuance costs			1,047	1,047	372
Total Debt, Net of Premium, Discount and Debt Issuance Costs			30,528	30,528	30,843
Repayments of Debt				4,016
Long-term Debt [Member]
Debt Instrument [Line Items]
Unamortized premium, discount and debt issuance costs, net			(600)	(600)	(641)
Current Debt [Member]
Debt Instrument [Line Items]
Unamortized premium, discount and debt issuance costs, net			(7)	(7)	(3)
2022 SPL Senior Notes [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 318
2022 SPL Senior Notes [Member] | Proceeds of 2032 CQP Senior Notes | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Debt		100
2022 SPL Senior Notes [Member] | Cash [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 218
CCH Working Capital Facility [Member]
Debt Instrument [Line Items]
Current debt, net of discount and debt issuance costs			0	0
2037 Private Placement Senior Secured Notes
Debt Instrument [Line Items]
Aggregate principal amount			482	482
SPL [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1]		$ 13,128	$ 13,128	13,650
SPL [Member] | Senior Notes [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.20%	4.20%
SPL [Member] | Senior Notes [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.25%	6.25%
SPL [Member] | 2022 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Current portion of senior secured notes	[1],[2]		$ 522	$ 522	0
Debt Instrument, Interest Rate, Stated Percentage			6.25%	6.25%
Cheniere Partners [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 4,200	$ 4,200	4,100
Total current debt, net of discount and debt issuance costs			$ 944	$ 944	0
Cheniere Partners [Member] | Senior Notes [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.25%	3.25%
Cheniere Partners [Member] | Senior Notes [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.625%	5.625%
Cheniere Partners [Member] | 2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Current portion of senior secured notes	[3]		$ 428	$ 428	0
Debt Instrument, Interest Rate, Stated Percentage			5.625%	5.625%
CCH [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			$ 10,128	$ 10,128	10,217
Current debt, net of discount and debt issuance costs			$ 104	$ 104	271
CCH [Member] | Senior Notes [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			2.742%	2.742%
CCH [Member] | Senior Notes [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			7.00%	7.00%
CCH [Member] | CCH Working Capital Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 1,200	$ 1,200
Cheniere Marketing
Debt Instrument [Line Items]
Current debt, net of discount and debt issuance costs			0	0	0
Cheniere [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross			2,625	2,625	3,145
Current portion of convertible notes			$ 0	$ 0	$ 104
Cheniere [Member] | 2028 Cheniere Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.625%	4.625%
Cheniere [Member] | 2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Repayments of Debt	[4]		$ 672
Cheniere [Member] | 2021 Convertible Unsecured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.875%	4.875%

[1] A portion of the 2022 SPL Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 SPL Senior Notes and pay related fees, costs and expenses.

[2] In October 2021, $318 million of the 2022 SPL Senior Notes was redeemed with $100 million from the proceeds from Cheniere Partners’ issuance of the 3.250% senior notes due 2032 (the “2032 CQP Senior Notes”) and $218 million of cash on hand. See Issuances, Redemptions and Repayments section below for further discussion.

[3] In October 2021, Cheniere Partners redeemed the remaining outstanding aggregate principal amount of the 2026 CQP Senior Notes that were not purchased pursuant to the tender offer and consent solicitation in September 2021. See Issuances, Redemptions and Repayments section below for further discussion.

[4] Net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem a portion of the 2026 CQP Senior Notes in September 2021 pursuant to a tender offer and consent solicitation, resulting in $27 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs. In October 2021, the remaining net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 2022 SPL Senior Notes.

XML

Debt - Schedule of Issuances, Redemptions and Repayments (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended						9 Months Ended
		Oct. 31, 2021	Sep. 30, 2021	Jun. 30, 2021		Mar. 31, 2021		Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Debt Instrument [Line Items]
Proceeds from issuances of debt									$ 3,804
Repayments of Debt									4,016
Debt modification and extinguishment costs			$ (36)					$ (171)	$ (95)	$ (215)
2022 SPL Senior Notes [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 318
Cheniere Partners [Member] | 2031 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.00%						4.00%
Proceeds from issuances of debt	[1]					$ 1,500
Cheniere Partners [Member] | 2032 Cheniere Energy Partners Senior Notes
Debt Instrument [Line Items]
Proceeds from issuances of debt	[2]		$ 1,200
Cheniere Partners [Member] | 2025 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.25%						5.25%
Repayments of Debt	[1]					1,500
Debt modification and extinguishment costs									$ 54
Cheniere Partners [Member] | 2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			5.625%						5.625%
Debt modification and extinguishment costs									$ 27
CCH [Member] | 2.742% CCH Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			2.742%						2.742%
Proceeds from issuances of debt	[3]		$ 750
CCH [Member] | CCH Credit Facility [Member]
Debt Instrument [Line Items]
Repayments of Debt	[3]		866
Debt modification and extinguishment costs									$ 9
Cheniere [Member] | Cheniere Term Loan Facility [Member]
Debt Instrument [Line Items]
Proceeds from issuances of debt	[4]			$ 220
Repayments of Debt				220	[4]	$ 148	[5]
Debt modification and extinguishment costs									$ 4
Cheniere [Member] | Cheniere Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Proceeds from issuances of debt				134
Repayments of Debt			$ 134
Cheniere [Member] | 2032 Cheniere Energy Partners Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.25%						3.25%
Cheniere [Member] | 2021 Cheniere Convertible Notes [Member]
Debt Instrument [Line Items]
Repayments of Debt	[4]			$ 476
Cheniere [Member] | 2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Repayments of Debt	[2]		$ 672

[1] Net proceeds from the issuance of the 2031 CQP Senior Notes, together with cash on hand, were used to redeem all of Cheniere Partners’ outstanding 2025 CQP Senior Notes, resulting in $54 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs.

[2] Net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem a portion of the 2026 CQP Senior Notes in September 2021 pursuant to a tender offer and consent solicitation, resulting in $27 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized debt premium and issuance costs. In October 2021, the remaining net proceeds from the issuance of the 2032 CQP Senior Notes were used to redeem the remaining outstanding principal amount of the 2026 CQP Senior Notes and, together with cash on hand, redeem $318 million of the 2022 SPL Senior Notes.

[3] Net proceeds of the 2.742% CCH Senior Secured Notes, together with cash on hand, were used to prepay a portion of the principal amount outstanding under the CCH Credit Facility, resulting in $9 million of loss on extinguishment of debt relating to the payment of early redemption fees and write off of unamortized issuance costs.

[4] The 2021 Cheniere Convertible Notes were repaid using a combination of borrowings under the Cheniere Term Loan Facility and cash on hand upon the maturity date at par value.

[5] The remaining commitments under the Cheniere Term Loan Facility were terminated in accordance with the credit agreement, resulting in $4 million of loss on extinguishment of debt relating to the write off of unamortized issuance costs.

XML

Debt - Credit Facilities Table (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($) Rate
2020 SPL Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 1,200	[1]
Incremental commitments	0	[1]
Outstanding balance	0	[1]
Commitments prepaid or terminated	0	[1]
Letters of credit issued	396	[1]
Available commitment	$ 804	[1]
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Maturity date	Mar. 19, 2025	[1]
2020 SPL Working Capital Facility [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	0.10%
2020 SPL Working Capital Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	0.30%
2020 SPL Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.125%
2020 SPL Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.75%
2020 SPL Working Capital Facility [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.125%
2020 SPL Working Capital Facility [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.75%
2019 CQP Credit Facilities [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 1,500
Incremental commitments	0
Outstanding balance	0
Commitments prepaid or terminated	750
Letters of credit issued	0
Available commitment	$ 750
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Maturity date	May 29, 2024
2019 CQP Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.25%
2019 CQP Credit Facilities [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	2.125%
2019 CQP Credit Facilities [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.25%
2019 CQP Credit Facilities [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.125%
CCH Credit Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 8,404
Incremental commitments	1,566
Outstanding balance	1,761
Commitments prepaid or terminated	8,209
Letters of credit issued	0
Available commitment	$ 0
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Weighted average interest rate on current debt	1.83%
Maturity date	Jun. 30, 2024
CCH Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.75%
CCH Credit Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.75%
CCH Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 350
Incremental commitments	850
Outstanding balance - current	0
Commitments prepaid or terminated	0
Letters of credit issued	360
Available commitment	$ 840
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Maturity date	Jun. 29, 2023
CCH Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.25%
CCH Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.75%
CCH Working Capital Facility [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.25%
CCH Working Capital Facility [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.75%
Cheniere Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 750
Incremental commitments	500
Outstanding balance	0
Commitments prepaid or terminated	0
Letters of credit issued	0
Available commitment	$ 1,250
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Maturity date	Dec. 13, 2022
Cheniere Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.75%
Cheniere Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	2.50%
Cheniere Revolving Credit Facility [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	0.75%
Cheniere Revolving Credit Facility [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	1.50%

[1] The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL pays a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.

XML

Debt - Convertible Notes Table (Details) - 2045 Cheniere Convertible Senior Notes [Member]	9 Months Ended
	Sep. 30, 2021 USD ($) $ / shares
Debt Instrument [Line Items]
Aggregate original principal	$ 625,000,000
Debt component, net of discount and debt issuance costs	320,000,000
Equity component	194,000,000
Conversion value in excess of principal	$ 0
Maturity date	Mar. 15, 2045
Contractual interest rate	4.25%
Effective interest rate	9.40%	[1]
Remaining debt discount and debt issuance costs amortization period	23 years 6 months	[2]
Debt Instrument, Convertible, Conversion Ratio	7.2265
Debt Instrument, Convertible, Conversion Price | $ / shares	$ 138.38

[1] Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

[2] We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity.

XML

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Debt Instrument [Line Items]
Total interest cost	$ 398	$ 416	$ 1,216	$ 1,356
Capitalized interest	(34)	(61)	(128)	(182)
Total interest expense, net of capitalized interest	364	355	1,088	1,174
Convertible Debt [Member]
Debt Instrument [Line Items]
Interest per contractual rate	6	20	29	140
Amortization of debt discount	1	7	9	41
Amortization of debt issuance costs	0	1	0	8
Total interest cost	7	28	38	189
Debt and Finance Leases Excluding Convertible Debt [Member]
Debt Instrument [Line Items]
Total interest cost	$ 391	$ 388	$ 1,178	$ 1,167

XML

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Sep. 30, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt		$ 30,528	$ 30,843
Senior Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[1]	25,978	24,700
Senior Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[2]	2,771	2,771
Senior Notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	28,565	27,897
Senior Notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	3,317	3,423
Line of Credit [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[3]	1,761	2,915
Line of Credit [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[3]	1,761	2,915
2021 Convertible Unsecured Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[2]	0	476
2021 Convertible Unsecured Notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Convertible Debt, Estimated Fair Value	[2]	0	480
2045 Cheniere Convertible Senior Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[4]	625	625
2045 Cheniere Convertible Senior Notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Convertible Debt, Estimated Fair Value	[4]	$ 538	$ 496

[1] The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.

[2] The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. 

[3] The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

[4] The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

XML

Leases - Balance Sheet Location Table (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Right-of-use assets—Operating	$ 2,064	$ 759
Total right-of-use assets	2,115	812
Current operating lease liabilities	458	161
Non-current operating lease liabilities	1,590	597
Non-current finance lease liabilities	57	57
Total lease liabilities	2,107	817
Operating lease assets, net [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets—Operating	2,064	759
Property, plant and equipment, net of accumulated depreciation [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets—Financing	51	53
Current operating lease liabilities [Member]
Lessee, Lease, Description [Line Items]
Current operating lease liabilities	458	161
Other current liabilities [Member]
Lessee, Lease, Description [Line Items]
Current finance lease liabilities	2	2
Operating lease liabilities [Member]
Lessee, Lease, Description [Line Items]
Non-current operating lease liabilities	1,590	597
Finance lease liabilities [Member]
Lessee, Lease, Description [Line Items]
Non-current finance lease liabilities	$ 57	$ 57

XML

Leases - Income Statement Location Table (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Finance lease cost:
Total lease cost		$ 147	$ 79	$ 450	$ 325
Operating costs and expenses [Member]
Lessee, Lease, Description [Line Items]
Operating lease cost	[1]	145	77	441	316
Finance lease cost:
Short-term lease costs		22	9	103	60
Variable lease costs		7	3	20	12
Depreciation and amortization expense [Member]
Finance lease cost:
Amortization of right-of-use assets		0	0	2	2
Interest expense, net of capitalized interest [Member]
Finance lease cost:
Interest on lease liabilities		$ 2	$ 2	$ 7	$ 7

[1] Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

XML

Leases - Future Minimum Payments Table (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Operating Leases, Future Minimum Payments
2021	$ 139	[1]
2022	515	[1]
2023	479	[1]
2024	433	[1]
2025	243	[1]
Thereafter	510	[1]
Total lease payments	2,319	[1]
Less: Interest	(271)	[1]
Present value of lease liabilities	2,048	[1]
Finance Leases, Future Minimum Payments
2021	3
2022	10
2023	10
2024	10
2025	10
Thereafter	127
Total lease payments	170
Less: Interest	(111)
Present value of lease liabilities	59
Operating Lease, Lease Not yet Commenced, Payments Due	$ 758
Lessee, Operating Lease, Lease Not yet Commenced, Period Until Commencement	1 year
Maximum [Member]
Finance Leases, Future Minimum Payments
Operating Leases, Lease Not yet Commenced, Term of Contract	7 years

[1] Does not include $758 million of legally binding minimum lease payments primarily for vessel charters which were executed as of September 30, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to seven years.

XML

Leases - Other Quantitative Information (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Operating Leases
Weighted-average remaining lease term		5 years 10 months 24 days		8 years 2 months 12 days
Weighted-average discount rate	[1]	3.60%		5.40%
Finance Leases
Weighted-average remaining lease term		16 years 10 months 24 days		17 years 8 months 12 days
Weighted-average discount rate	[1]	16.20%		16.20%
Operating cash flows used in operating leases		$ 331	$ 226
Operating cash flows used in finance leases		7	8
Right-of-use assets obtained in exchange for operating lease liabilities		$ 1,575	$ 412

[1] The finance leases commenced prior to the adoption of the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

XML

Leases - Subleases (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Leases [Abstract]
Sublease payments to be received	$ 0		$ 0		$ 0
Sublease Income, Fixed	17	$ 9	28	$ 61
Sublease Income, Variable	15	1	21	24
Sublease Income, Total	$ 32	$ 10	$ 49	$ 85

XML

Revenues from Contracts with Customers - Narrative (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	61.00%	37.00%	56.00%	35.00%
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	5.00%	6.00%	5.00%	6.00%

XML

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 4,259	$ 1,421	$ 10,773	$ 6,338
Net derivative gains (losses)	[1]	(1,091)	29	(1,515)	148
Other revenues	[2]	32	10	49	85
Total revenues		3,200	1,460	9,307	6,571
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	[3]	4,169	1,344	10,505	6,088
Total revenues		3,078	1,373	8,990	6,236
Suspension Fees and LNG Cover Damages Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	171	0	932
Suspension Fees and LNG Cover Damages Revenue [Member] | Subsequent Period
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			47		47
Suspension Fees and LNG Cover Damages Revenue [Member] | Current Period
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	458	38	0
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		68	67	202	202
Other [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		22	10	66	48
Total revenues		$ 54	$ 20	$ 115	$ 133

[1] See Note 6—Derivative Instruments for additional information about our derivatives.

[2] Includes revenues from LNG vessel subcharters. See Note 10—Leases for additional information about our subleases.

[3] LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $171 million and $932 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $47 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2021 and 2020 excluded zero and $458 million, respectively, and LNG revenues during the nine months ended September 30, 2021 and 2020 excluded $38 million and zero, respectively, that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

XML

Revenues from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 123	$ 80
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	138
Cash received but not yet recognized in revenue	196
Revenue recognized from prior period deferral	(138)
Deferred revenue, end of period	$ 196

XML

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		Sep. 30, 2021	Dec. 31, 2020
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 104.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 102.5
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 102.3
Weighted Average Recognition Timing	[1]		10 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 100.6
Weighted Average Recognition Timing	[1]	10 years
Regasification [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 2.1
Weighted Average Recognition Timing	[1]		5 years
Regasification [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 1.9
Weighted Average Recognition Timing	[1]	4 years

[1] The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

XML

Related Party Transactions - Narrative (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($) tbtu	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) tbtu	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($) tbtu
Related Party Transaction [Line Items]
Operating and maintenance expense	$ 350,000,000	$ 317,000,000	$ 1,057,000,000	$ 988,000,000
Cost of sales (excluding items shown separately below)	4,868,000,000	768,000,000	8,408,000,000	2,295,000,000
Accrued liabilities	1,787,000,000		1,787,000,000		$ 1,175,000,000
Revenues	3,200,000,000	1,460,000,000	9,307,000,000	6,571,000,000
Accounts and other receivables, net of current expected credit losses	983,000,000		983,000,000		$ 647,000,000
Other [Member]
Related Party Transaction [Line Items]
Revenues	$ 54,000,000	20,000,000	$ 115,000,000	133,000,000
SPL [Member] | Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term			5 years
Derivative, Nonmonetary Notional Amount | tbtu	99		99		91
Derivative Assets (Liabilities), at Fair Value, Net	$ 0		$ 0		$ 0
CCL [Member] | Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales (excluding items shown separately below)	53,000,000	29,000,000	124,000,000	77,000,000
Accrued liabilities	19,000,000		$ 19,000,000		13,000,000
CCL [Member] | Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term			10 years
Operating and maintenance expense	2,000,000	2,000,000	$ 7,000,000	4,000,000
Accrued liabilities	1,000,000		1,000,000
Sabine Pass Liquefaction LLC and Cheniere Creole Trail Pipeline LP [Member] | Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense	12,000,000		34,000,000
Cost of sales (excluding items shown separately below)	0		1,000,000
Accrued liabilities	5,000,000		$ 5,000,000		4,000,000
Sabine Pass Liquefaction LLC and Cheniere Creole Trail Pipeline LP [Member] | Natural Gas Transportation and Storage Agreements [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term			10 years
Cheniere LNG O&M Services, LLC [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Accounts and other receivables, net of current expected credit losses	1,000,000		$ 1,000,000		$ 2,000,000
Cheniere LNG O&M Services, LLC [Member] | Operation and Maintenance Agreement [Member] | Other [Member]
Related Party Transaction [Line Items]
Revenues	$ 2,000,000	$ 2,000,000	$ 5,000,000	$ 8,000,000

XML

Related Party Transactions - Schedule of Related Party Transactions (Details) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021 USD ($) tbtu	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) tbtu	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($) tbtu
Related Party Transaction [Line Items]
Current derivative assets		$ 266		$ 266		$ 32
Derivative assets		71		71		$ 376
Cost of sales		$ 4,868	$ 768	$ 8,408	$ 2,295
Liquefaction Supply Derivatives [Member]
Related Party Transaction [Line Items]
Derivative, Nonmonetary Notional Amount | tbtu	[1]	11,291		11,291		10,483
CCL [Member] | Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales		$ 53	29	$ 124	77
CCL [Member] | Natural Gas Supply Agreement [Member] | Liquefaction Supply Derivatives [Member]
Related Party Transaction [Line Items]
Current derivative assets		7		7		$ 3
Derivative assets		$ 10		$ 10		$ 1
Derivative, Nonmonetary Notional Amount | tbtu		119		119		60
Liquefaction Supply Derivative gain		$ 6	$ (5)	$ 13	$ (3)

[1] Includes notional amounts for natural gas supply contracts that SPL and CCL have with related parties. See Note 12—Related Party Transactions.

XML

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income tax provision (benefit)	$ (1,860)	$ (75)	$ (1,864)	$ 119
Effective Income Tax Rate	67.00%	12.90%	79.70%	19.30%
Loss on Derivative Instruments, Net, Pretax	$ 3,500		$ 4,200
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	21.00%	21.00%	21.00%	21.00%
Income tax expense as a result of one-time discrete event				$ 38

XML

Share-Based Compensation - Narrative (Details) shares in Millions	9 Months Ended
	Sep. 30, 2021 shares
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share Based Compensation Arrangement By Share Based Payment Award, Award Vesting Period, Vests Ratably Over Service Period	3 years
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award Vesting Period, Cliff Vesting	3 years
Performance Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of Target Amount Earned Upon Vesting If Threshold Performance is Met	0.00%
Performance Units [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of Target Amount Earned Upon Vesting If Threshold Performance is Met	300.00%
Common Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Units Granted	0.2
2020 Incentive Plan [Member] | Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Units Granted	1.6
2020 Incentive Plan [Member] | Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Units Granted	0.3

XML

Share-Based Compensation - Schedule of Share-Based Compensation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation	$ 29	$ 27	$ 95	$ 88
Capitalized share-based compensation	(1)	0	(4)	(4)
Total share-based compensation expense	28	27	91	84
Tax benefit associated with share-based compensation expense	3	2	30	21
Equity Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation	28	26	92	86
Liability Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation	$ 1	$ 1	$ 3	$ 2

XML

Net Income (Loss) Per Share Attributable to Common Stockholders (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended						9 Months Ended
		Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021	Sep. 30, 2020
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net income (loss) attributable to common stockholders		$ (1,084)	$ (329)	$ 393	$ (463)	$ 197	$ 375	$ (1,020)	$ 109
Weighted average number of common shares outstanding, basic		253.6			252.2			253.3	252.5
Dilutive Unvested Stock		0.0			0.0			0.0	0.7
Weighted Average Number of Shares Outstanding, Diluted		253.6			252.2			253.3	253.2
Net income (loss) per share attributable to common stockholders—basic and diluted		$ (4.27)			$ (1.84)			$ (4.03)	$ 0.43
Antidilutive securities excluded from computation of earnings per share		6.3			7.6			6.1	6.9
Unvested stock
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	[1]	1.8			3.1			1.6	2.4
2045 Cheniere Convertible Senior Notes [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share		4.5			4.5			4.5	4.5

[1] Includes the impact of unvested shares containing performance conditions to the extent that the underlying performance conditions are satisfied based on actual results as of the respective dates.

XML

Stockholders' Equity - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 589
Initial Board Approval [Member]
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Period in Force	3 years
Stock Repurchase Program, Authorized Amount	$ 1,000
Subsequent Board Approved Increase [Member]
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Period in Force	3 years
Stock Repurchase Program, Authorized Amount	$ 1,000

XML

Stockholders' Equity - Schedule of Share Repurchases (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Equity [Abstract]
Aggregate common stock repurchased	100,000	0	100,000	2,900,000
Weighted average price paid per share	$ 83.97	$ 0	$ 83.97	$ 53.88
Total amount paid	$ 6	$ 0	$ 6	$ 155

XML

Stockholders' Equity - Dividends (Details) - USD ($) $ / shares in Units, $ in Millions	Sep. 07, 2021	Sep. 30, 2021	Sep. 30, 2020
Equity [Abstract]
Common Stock, Dividends, Per Share, Declared	$ 0.33
Dividends Payable		$ 85	$ 0

XML

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12.00%		14.00%	13.00%
Customer A [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					14.00%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15.00%	11.00%	13.00%	10.00%
Customer B [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					12.00%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	11.00%	15.00%	11.00%	11.00%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	11.00%	13.00%		10.00%
Customer E [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			17.00%
Customer F | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			12.00%

XML

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized	$ 902	$ 977
Cash paid for income taxes, net of refunds	2	2
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	234	262
Dividends Payable	$ 85	$ 0