Cheniere Energy (LNG) 10-K24 Feb 222021 FY Annual reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
Document and Entity Information - USD ($) $ in Billions	Dec. 31, 2021	Feb. 18, 2022	Jun. 30, 2021
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 21.8
Entity Common Stock, Shares Outstanding		254,397,855
Documents Incorporated by Reference	The definitive proxy statement for the registrant’s Annual Meeting of Stockholders (to be filed within 120 days of the close of the registrant’s fiscal year) is incorporated by reference into Part III.
Entity Central Index Key	0000003570
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2021
Audit Information [Abstract]
Auditor Name	KPMG LLP
Auditor Location	Houston, Texas
Auditor Firm ID	185

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues
Revenues		$ 15,864	$ 9,358	$ 9,730
Revenues from contracts with customers		17,531	9,293	9,157
Operating costs and expenses
Cost of sales (excluding items shown separately below)		13,773	4,161	5,079
Operating and maintenance expense		1,444	1,320	1,154
Development expense		7	6	9
Selling, general and administrative expense		325	302	310
Depreciation and amortization expense		1,011	932	794
Impairment expense and loss on disposal of assets		5	6	23
Total operating costs and expenses		16,565	6,727	7,369
Income (loss) from operations		(701)	2,631	2,361
Other expense
Interest expense, net of capitalized interest		(1,438)	(1,525)	(1,432)
Loss on modification or extinguishment of debt		(116)	(217)	(55)
Interest rate derivative loss, net		(1)	(233)	(134)
Other expense, net		(22)	(112)	(25)
Total other expense		(1,577)	(2,087)	(1,646)
Income (loss) before income taxes and non-controlling interest		(2,278)	544	715
Less: income tax provision (benefit)		(713)	43	(517)
Net income (loss)		(1,565)	501	1,232
Less: net income attributable to non-controlling interest		778	586	584
Net income (loss) attributable to common stockholders		$ (2,343)	$ (85)	$ 648
Net income (loss) per share attributable to common stockholders—basic		$ (9.25)	$ (0.34)	$ 2.53
Net income (loss) per share attributable to common stockholders—diluted		$ (9.25)	$ (0.34)	$ 2.51
Weighted average number of common shares outstanding—basic		253.4	252.4	256.2
Weighted average number of common shares outstanding—diluted		253.4	252.4	258.1
LNG [Member]
Revenues
Revenues		$ 15,395	$ 8,924	$ 9,246
Revenues from contracts with customers	[1]	17,171	8,954	8,817
Regasification [Member]
Revenues
Revenues from contracts with customers		269	269	266
Other [Member]
Revenues
Revenues		200	165	218
Revenues from contracts with customers		$ 91	$ 70	$ 74

[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 year ended December 31, 2020, we recognized $969 million in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $38 million would have been recognized during the year ended December 31, 2021 had the cargoes been 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 years ended December 31, 2021 and 2019. 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.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 1,404	[1]	$ 1,628
Restricted cash and cash equivalents	413	[1]	449
Accounts and other receivables, net of current expected credit losses	1,506		647
Inventory	706		292
Current derivative assets	55		32
Margin deposits	765		25
Other current assets	207		96
Total current assets	5,056		3,169
Property, plant and equipment, net of accumulated depreciation	30,288		30,421
Operating lease assets	2,102		759
Derivative assets	69		376
Goodwill	77		77
Deferred tax assets	1,204		489
Other non-current assets, net	462		406
Total assets	39,258	[1]	35,697
Current liabilities
Accounts payable	155		35
Accrued liabilities	2,299		1,175
Current debt, net of discount and debt issuance costs	366		372
Deferred revenue	155		138
Current operating lease liabilities	535		161
Current derivative liabilities	1,089		313
Other current liabilities	94		2
Total current liabilities	4,693		2,196
Long-term debt, net of premium, discount and debt issuance costs	29,449		30,471
Operating lease liabilities	1,541		597
Finance lease liabilities	57		57
Derivative liabilities	3,501		151
Other non-current liabilities	50		7
Commitments and Contingencies
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; 275.2 million shares and 273.1 million shares issued at December 31, 2021 and 2020, respectively	1		1
Treasury stock: 21.6 million shares and 20.8 million shares at December 31, 2021 and 2020, respectively, at cost	(928)		(872)
Additional paid-in-capital	4,377		4,273
Accumulated deficit	(6,021)		(3,593)
Total stockholders' deficit	(2,571)		(191)
Non-controlling interest	2,538		2,409
Total equity (deficit)	(33)		2,218
Total liabilities and stockholders’ equity (deficit)	$ 39,258	[1]	$ 35,697

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Consolidated Balance Sheets Par

Consolidated Balance Sheets Parentheticals - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020
Assets	$ 39,258	[1]	$ 35,697
Cash and cash equivalents	$ 1,404	[1]	$ 1,628
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	275,200,000		273,100,000
Treasury Stock, Shares	21,600,000		20,800,000
CQP [Member]
Assets	$ 18,985		$ 18,817
Liabilities	18,554		18,535
Cash and cash equivalents	876		1,210
Restricted cash and cash equivalents	$ 98		$ 97

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity - USD ($) shares in Millions, $ 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, 2018		257
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2018			12.8
Stockholders' Equity, Beginning of Period at Dec. 31, 2018	$ 1,929	$ 1	$ (406)	$ 4,035	$ (4,156)	$ 2,455
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units and performance stock units, shares		0.9	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	131	$ 0	$ 0	131	0	0
Shares withheld from employees related to share-based compensation, at cost, shares, common stock		(0.3)
Shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			0.3
Shares withheld from employees related to share-based compensation, at cost	(19)	$ 0	$ (19)	0	0	0
Shares repurchased, at cost, shares		(4)	4
Shares repurchased, at cost	(249)	$ 0	$ (249)	0	0	0
Net income attributable to non-controlling interest	584	0	0	0	0	584
Reacquisition of equity component of convertible notes, net of tax	1	0	0	1	0	0
Distributions to non-controlling interest	(590)	0	0	0	0	(590)
Net income (loss)	648	$ 0	$ 0	0	648	0
Common Stock, Shares, Outstanding, End of Period at Dec. 31, 2019		253.6
Treasury Stock, Shares, End of Period at Dec. 31, 2019			17.1
Stockholders' Equity, End 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		2.4	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	114	$ 0	$ 0	114	0	0
Shares withheld from employees related to share-based compensation, at cost, shares, common stock		(0.8)
Shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			0.8
Shares withheld from employees related to share-based compensation, at cost	(43)	$ 0	$ (43)	0	0	0
Shares repurchased, at cost, shares		(2.9)	2.9
Shares repurchased, at cost	(155)	$ 0	$ (155)	0	0	0
Net income attributable to non-controlling interest	586	0	0	0	0	586
Reacquisition of equity component of convertible notes, net of tax	(8)	0	0	(8)	0	0
Distributions to non-controlling interest	(626)	0	0	0	0	(626)
Net income (loss)	$ (85)	0	0	0	(85)	0
Common Stock, Shares, Outstanding, End of Period at Dec. 31, 2020	252.3
Treasury Stock, Shares, End of Period at Dec. 31, 2020	20.8
Stockholders' Equity, End 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		2.1	0
Vesting of restricted stock units and performance stock units	0	$ 0	$ 0	0	0	0
Share-based compensation	105	$ 0	$ 0	105	0	0
Shares withheld from employees related to share-based compensation, at cost, shares, common stock		(0.7)
Shares withheld from employees related to share-based compensation, at cost, shares, treasury shares			0.7
Shares withheld from employees related to share-based compensation, at cost	(48)	$ 0	$ (47)	(1)	0	0
Shares repurchased, at cost, shares		(0.1)	0.1
Shares repurchased, at cost	(9)	$ 0	$ (9)	0	0	0
Net income attributable to non-controlling interest	778	0	0	0	0	778
Distributions to non-controlling interest	(649)	0	0	0	0	(649)
Dividends declared ($0.33 per common share)	(85)	0	0	0	(85)	0
Net income (loss)	$ (2,343)	0	0	0	(2,343)	0
Common Stock, Shares, Outstanding, End of Period at Dec. 31, 2021	253.6
Treasury Stock, Shares, End of Period at Dec. 31, 2021	21.6
Stockholders' Equity, End of Period at Dec. 31, 2021	$ (33)	$ 1	$ (928)	$ 4,377	$ (6,021)	$ 2,538

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity Parentheticals	12 Months Ended
	Dec. 31, 2021$ / shares
Common Stock
Common Stock, Dividends, Per Share, Declared	$ 0.33

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash flows from operating activities
Net income (loss)	$ (1,565)	$ 501	$ 1,232
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	1,011	932	794
Share-based compensation expense	140	110	131
Non-cash interest expense	19	51	143
Amortization of debt issuance costs, premium and discount	72	114	103
Reduction of right-of-use assets	393	291	350
Loss on modification or extinguishment of debt	116	217	55
Total losses (gains) on derivatives, net	5,989	211	(400)
Net cash provided by (used for) settlement of derivative instruments	(1,579)	74	138
Impairment expense and loss on disposal of assets	5	6	23
Impairment expense and loss on equity method investments	24	126	88
Deferred taxes	(715)	40	(521)
Repayment of paid-in-kind interest related to repurchase of convertible notes	(190)	(911)	0
Other	4	2	0
Changes in operating assets and liabilities:
Accounts and other receivables, net of current expected credit losses	(799)	(154)	1
Inventory	(409)	21	11
Margin deposits	(741)	(13)	6
Other current assets	(101)	(14)	(24)
Accounts payable and accrued liabilities	1,144	54	52
Deferred revenue	55	(23)	22
Operating lease liabilities	(418)	(277)	(366)
Other, net	14	(93)	(5)
Net cash provided by operating activities	2,469	1,265	1,833
Cash flows from investing activities
Property, plant and equipment	(966)	(1,839)	(3,056)
Proceeds from sale of fixed assets	68	0	0
Investment in equity method investment	0	(100)	(105)
Other	(14)	(8)	(2)
Net cash used in investing activities	(912)	(1,947)	(3,163)
Cash flows from financing activities
Proceeds from issuances of debt	5,911	7,823	6,434
Redemptions and repayments of debt	(6,810)	(6,940)	(4,346)
Debt issuance and other financing costs	(53)	(125)	(51)
Debt modification or extinguishment costs	(82)	(172)	(15)
Distributions to non-controlling interest	(649)	(626)	(590)
Payments related to tax withholdings for share-based compensation	(48)	(43)	(19)
Repurchase of common stock	(9)	(155)	(249)
Cash dividends to shareholders	(85)	0	0
Other	8	3	4
Net cash provided by (used in) financing activities	(1,817)	(235)	1,168
Net decrease in cash, cash equivalents and restricted cash and cash equivalents	(260)	(917)	(162)
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	2,077	2,994	3,156
Cash, cash equivalents and restricted cash and cash equivalents—end of period	$ 1,817	$ 2,077	$ 2,994

Consolidated Statements of Ca_2

Consolidated Statements of Cash Flows - Balances per Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Balances per Consolidated Balance Sheets:
Cash and cash equivalents	$ 1,404	[1]	$ 1,628
Total cash, cash equivalents and restricted cash and cash equivalents	$ 1,817		$ 2,077	$ 2,994	$ 3,156

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Organization and Nature of Oper

Organization and Nature of Operations	12 Months Ended
Organization and Nature of Operations	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Nature of Operations	ORGANIZATION AND NATURE OF OPERATIONS 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”). CQP owns the Sabine Pass LNG Terminal located in Cameron Parish, Louisiana, which has natural gas liquefaction facilities consisting of six operational natural gas liquefaction Trains, with Train 6 achieving substantial completion on February 4, 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. CQP 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 December 31, 2021, we owned 100% of the general partner interest and 48.6% of the limited partner interest in CQP. 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 21.5-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 over 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”).

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
Summary of Significant Accounting Policies	Dec. 31, 2021
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation Our Consolidated Financial Statements have been prepared in accordance with GAAP. The Consolidated Financial Statements include the accounts of Cheniere, its subsidiaries and affiliates in which we hold a controlling interest, reflecting ownership of a majority of the voting interest, as of the financial statement date. Additionally, we consolidate a VIE under certain criteria discussed further below. All intercompany accounts and transactions have been eliminated in consolidation. When necessary, reclassifications that are not material to our Consolidated Financial Statements are made to prior period financial information to conform to the current year presentation. VIEs We make a determination at the inception of each arrangement whether an entity in which we have made an investment or in which we have other variable interests is considered a VIE. Generally, an entity is a VIE if either (1) the entity does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties, (2) the entity’s investors lack any characteristics of a controlling financial interest or (3) which was established with non-substantive voting. We consolidate VIEs when we are deemed to be the primary beneficiary. The primary beneficiary of a VIE is generally the party that both: (1) has the power to make decisions that most significantly affect the economic performance of the VIE and (2) has the obligation to absorb losses or the right to receive benefits that in either case could potentially be significant to the VIE. If we are not deemed to be the primary beneficiary of a VIE, we account for the investment or other variable interests in a VIE in accordance with applicable GAAP. Non-controlling Interests When we consolidate an entity, we include 100% of the assets, liabilities, revenues and expenses of the subsidiary in our Consolidated Financial Statements. For those entities that we consolidate in which our ownership is less than 100%, we record a non-controlling interest as a component of equity on our Consolidated Balance Sheets, which represents the third party ownership in the net assets of the respective consolidated subsidiary. Additionally, the portion of the net income or loss attributable to the non-controlling interest is reported as net income (loss) attributable to non-controlling interest on our Consolidated Statements of Operations. Changes in our ownership interests in an entity that do not result in deconsolidation are generally recognized within equity. See Note 9—Non-controlling Interest and Variable Interest Entities for additional details about our non-controlling interest. Equity Method Investments Investments in non-controlled entities, which Cheniere has the ability to exercise significant influence over operating and financial policies are accounted for using the equity method of accounting, with our share of earnings or losses reported in other income (expense) on our Consolidated Statements of Operations. In applying the equity method of accounting, the investments are initially recognized at cost, and subsequently adjusted for our proportionate share of earnings, losses and distributions. Investments accounted for using the equity method of accounting are reported as a component of other noncurrent assets. See Note 8 — Other Non-Current Assets , N et for additional details about our equity method investments. Use of 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. Management evaluates its estimates and related assumptions regularly, including those related to fair value measurements of derivatives and other instruments, useful lives of property, plant and equipment, certain valuations including leases and asset retirement obligations (“AROs”) and recoverability of deferred tax assets, each as further discussed under the respective sections within this note. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates. Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation approaches used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs that are directly or indirectly observable for the asset or liability, other than quoted prices included within Level 1. Hierarchy Level 3 inputs are inputs that are not observable in the market. In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates. Recurring fair-value measurements are performed for derivative instruments, as disclosed in Note 7—Derivative Instruments , and liability-classified share-based compensation awards, as disclosed in Note 16 — S hare-Ba sed Compen s ation . The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Consolidated Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt in the open market, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 11—Debt , are based on quoted market prices for identical instruments, if available, or based on valuations of similar debt instruments using observable or unobservable inputs. Revenue Recognition We recognize revenues when we transfer control of promised goods or services to our customers in an amount that reflects the consideration to which we expect to be entitled to in exchange for those goods or services. See Note 13—Revenues from Contracts with Customers for further discussion of our revenue streams and accounting policies related to revenue recognition. Cash and Cash Equivalents We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. Restricted Cash and Cash Equivalents Restricted cash and cash equivalents consist 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. Accounts and Other Receivables Accounts and other receivables are reported net of any current expected credit losses. Current expected credit losses consider the risk of loss based on past events, current conditions and reasonable and supportable forecasts. A counterparty’s ability to pay is assessed through a credit review process that considers payment terms, the counterparty’s established credit rating or our assessment of the counterparty’s credit worthiness, contract terms, payment status, and other risks or available financial assurances. Adjustments to current expected credit losses are recorded in selling, general and administrative expense in our Consolidated Statements of Operations. As of both December 31, 2021 and 2020, we had current expected credit losses on our accounts and other receivables of $5 million. Inventory LNG and natural gas inventory are recorded at the lower of weighted average cost and net realizable value. Materials and other inventory are recorded at the lower of cost and net realizable value. Inventory is charged to expense when sold, or, for certain qualifying costs, capitalized to property, plant and equipment when issued, primarily using the weighted average method. Property, Plant and Equipment Property, plant and equipment are recorded at cost. Expenditures for construction and commissioning activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs (including those for planned major maintenance projects) to maintain property, plant and equipment in operating condition are generally expensed as incurred. Generally, we begin capitalizing the costs of our LNG terminals once the individual project meets the following criteria: (1) regulatory approval has been received, (2) financing for the project is available and (3) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a project are expensed as incurred. These costs primarily include professional fees associated with preliminary front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to our LNG terminals. Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land acquisition costs, detailed engineering design work and certain permits that are capitalized as other non-current assets. We realize offsets to LNG terminal costs for sales of commissioning cargoes that were earned or loaded prior to the start of commercial operations of the respective Train during the testing phase for its construction. We depreciate our property, plant and equipment using the straight-line depreciation method over assigned useful lives. Refer to Note 6 — Prope rty, Plant and Equipment, N et of Accumulated Depreciation for additional discussion of our useful lives by asset category. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in impairment expense and loss (gain) on disposal of assets. Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets for purposes of assessing recoverability. Recoverability generally is determined by comparing the carrying value of the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value. We recorded $8 million of impairments related to property, plant and equipment during the year ended December 31, 2021. We did not record any impairments related to property, plant and equipment during the years ended December 31, 2020 and 2019. Interest Capitalization We capitalize interest costs during the construction period of our LNG terminals and related assets as construction-in-process. Upon commencement of operations, these costs are transferred out of construction-in-process into terminal and interconnecting pipeline facilities assets and are amortized over the estimated useful life of the asset. Regulated Natural Gas Pipelines The Creole Trail Pipeline and Corpus Christi Pipeline are subject to the jurisdiction of the FERC in accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of 1978. The economic effects of regulation can result in a regulated company recording as assets those costs that have been or are expected to be approved for recovery from customers, or recording as liabilities those amounts that are expected to be required to be returned to customers, in a rate-setting process in a period different from the period in which the amounts would be recorded by an unregulated enterprise. Accordingly, we record assets and liabilities that result from the regulated rate-making process that may not be recorded under GAAP for non-regulated entities. We continually assess whether regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes and recent rate orders applicable to other regulated entities. Based on this continual assessment, we believe the existing regulatory assets are probable of recovery. These regulatory assets and liabilities are primarily classified in our Consolidated Balance Sheets as other assets and other liabilities. We periodically evaluate their applicability under GAAP and consider factors such as regulatory changes and the effect of competition. If cost-based regulation ends or competition increases, we may have to write off the associated regulatory assets and liabilities. Items that may influence our assessment are: • inability to recover cost increases due to rate caps and rate case moratoriums; • inability to recover capitalized costs, including an adequate return on those costs through the rate-making process and the FERC proceedings; • excess capacity; • increased competition and discounting in the markets we serve; and • impacts of ongoing regulatory initiatives in the natural gas industry. Natural gas pipeline costs include amounts capitalized as an Allowance for Funds Used During Construction (“AFUDC”). The rates used in the calculation of AFUDC are determined in accordance with guidelines established by the FERC. AFUDC represents the cost of debt and equity funds used to finance our natural gas pipeline additions during construction. AFUDC is capitalized as a part of the cost of our natural gas pipelines. Under regulatory rate practices, we generally are permitted to recover AFUDC, and a fair return thereon, through our rate base after our natural gas pipelines are placed in service. Derivative Instruments We use derivative instruments to hedge our exposure to cash flow variability from interest rate, commodity price and foreign currency exchange (“FX”) rate risk. Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria for, and we elect, the normal purchases and sales exception, under which we account for the instrument under the accrual method of accounting, whereby revenues and expenses are recognized only upon delivery, receipt or realization of the underlying transaction. When we have the contractual right and intent to net settle, derivative assets and liabilities are reported on a net basis. Changes in the fair value of our derivative instruments are recorded in earnings, unless we elect to apply hedge accounting and meet specified criteria. We did not have any derivative instruments designated as cash flow or fair value hedges during the years ended December 31, 2021, 2020 and 2019. See Note 7—Derivative Instruments for additional details about our derivative instruments. Leases We determine if an arrangement is, or contains, a lease at inception of the arrangement. When we determine the arrangement is, or contains, a lease, we classify the lease as either an operating lease or a finance lease. Operating and finance leases are recognized on our Consolidated Balance Sheets by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. Operating and finance lease right-of-use assets and liabilities are generally recognized based on the present value of minimum lease payments over the lease term. In determining the present value of minimum lease payments, we use the implicit interest rate in the lease if readily determinable. In the absence of a readily determinable implicitly interest rate, we discount our expected future lease payments using our relevant subsidiary’s incremental borrowing rate. The incremental borrowing rate is an estimate of the interest rate that a given subsidiary would have to pay to borrow on a collateralized basis over a similar term to that of the lease term. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability, only to the extent they are reasonably certain to be exercised. We have elected practical expedients to (1) omit leases with an initial term of 12 months or less from recognition on our balance sheet and (2) to combine both the lease and non-lease components of an arrangement in calculating the right-of-use asset and lease liability for all classes of leased assets. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Lease expense for finance leases is recognized as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities using the effective interest method over the lease term. Certain of our leases also contain variable payments, such as inflation, that are included in the right-of-use asset and lease liability only when the contract terms require the payment of a fixed amount that is unavoidable. See Note 12—Leases for additional details about our leases. Concentration of Credit Risk Financial instruments that potentially subject us to a concentration of credit risk consist principally of derivative instruments and accounts receivable related to our long-term SPAs and regasification contracts, each discussed further below. Additionally, we maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred credit losses related to these cash balances to date. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Certain of our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded within other current assets. Our interest rate and FX derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments. We have contracted our anticipated production capacity under SPAs and under IPM agreements. 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 agreements had approximately 17 years of weighted average remaining life as of December 31, 2021. We market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. We are dependent on the respective customers’ creditworthiness and their willingness to perform under their respective agreements. SPLNG has entered into two long-term TUAs with third parties for regasification capacity at the Sabine Pass LNG Terminal. SPLNG is dependent on the respective customers’ creditworthiness and their willingness to perform under their respective TUAs. SPLNG has mitigated this credit risk by securing TUAs for a significant portion of its regasification capacity with creditworthy third party customers with a minimum Standard & Poor’s rating of A. See Note 21—Customer Concentration for additional details about our customer concentration. Our arrangements with our customers incorporate certain provisions to mitigate our exposure to credit losses and include, under certain circumstances, customer collateral, netting of exposures through the use of industry standard commercial agreements and margin deposits with certain counterparties in the over-the-counter derivative market, with such margin deposits primarily facilitated by independent system operators and by clearing brokers. Payments on margin deposits, either by us or by the counterparty depending on the position, are required when the value of a derivative exceeds our pre-established credit limit with the counterparty. Margin deposits are returned to us (or to the counterparty) on or near the settlement date for non-exchange traded derivatives, and we exchange margin calls on a daily basis for exchange traded transactions. Goodwill Goodwill is the excess of acquisition cost of a business over the estimated fair value of net assets acquired. Goodwill is not amortized however we test goodwill for impairment at least annually as of October 1st, or more frequently if events or circumstances indicate goodwill is more likely than not impaired. When evaluating goodwill for impairment, we may either perform a qualitative assessment or a quantitative test. The qualitative assessment is an assessment of historical information and relevant events and circumstances to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, including goodwill. If it is concluded that it is more-likely-than not that an impairment exists, a quantitative test is required which compares the estimated fair value of a reporting unit to its carrying value and measures any goodwill impairment as the amount by which the carrying amount of the reporting unit exceeds its fair value. We may elect not to perform the qualitative assessment and instead perform a quantitative impairment test. We completed our annual assessment of goodwill impairment in the current year by performing a qualitative assessment; which indicated it was not more likely than not that there was an impairment and therefore no quantitative test was required. Significant judgments and assumptions are inherent in our estimate of future cash flows used to determine the estimate of the reporting unit’s fair value. Factors that could trigger a lower fair value estimate include significant negative industry or economic trends, cost increases, disruptions to our business, regulatory or political environment changes or other unanticipated events. Debt Our debt consists of current and long-term secured and unsecured debt securities, convertible debt securities and credit facilities with banks and other lenders. Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors. Debt is recorded on our Consolidated Balance Sheets at par value adjusted for unamortized discount or premium and net of unamortized debt issuance costs related to term notes. Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. If debt issuance costs are incurred in connection with a line of credit arrangement or on undrawn funds, the debt issuance costs are presented as an asset on our Consolidated Balance Sheets. Discounts, premiums and debt issuance costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net of capitalized interest using the effective interest method. Gains and losses on the extinguishment or modification of debt are recorded in loss on modification or extinguishment of debt on our Consolidated Statements of Operations. We classify debt on our Consolidated Balance Sheets based on contractual maturity, with the following exceptions: • We classify term debt that is contractually due within one year as long-term debt if management has the intent and ability to refinance the current portion of such debt with future cash proceeds from an executed long-term debt agreement. • We evaluate the classification of long-term debt extinguished after the balance sheet date but before the financial statements are issued based on facts and circumstances existing as of the balance sheet date. Asset Retirement Obligations We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. We have not recorded an ARO associated with the Sabine Pass LNG Terminal. Based on the real property lease agreements at the Sabine Pass LNG Terminal, at the expiration of the term of the leases we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at the Sabine Pass LNG Terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender the Sabine Pass LNG Terminal in good order and repair, with normal wear and tear and casualty expected, is immaterial. We have not recorded an ARO associated with the Creole Trail Pipeline or the Corpus Christi Pipeline. We believe that it is not feasible to predict when the natural gas transportation services provided by the Creole Trail Pipeline or the Corpus Christi Pipeline will no longer be utilized. In addition, our right-of-way agreements associated with the Creole Trail Pipeline and the Corpus Christi Pipeline have no stipulated termination dates. We intend to operate the Creole Trail Pipeline and the Corpus Christi Pipeline as long as supply and demand for natural gas exists in the United States and intend to maintain it regularly. Share-based Compensation We have awarded share-based compensation in the form of stock (immediately vested), restricted stock shares, restricted stock units, performance stock units and phantom units. The awards and our related accounting policies are more fully described in Note 16—Share-based Compensation . Income Taxes Provisions for income taxes are based on taxes payable or refundable for the current year and deferred taxes on temporary differences between the tax basis of assets and liabilities and their reported amounts in our Consolidated Financial Statements. Deferred tax assets and liabilities are included in our Consolidated Financial Statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the current period’s provision for income taxes. A valuation allowance is recorded to reduce the carrying value of our deferred tax assets when it is more likely than not that a portion or all of the deferred tax assets will expire before realization of the benefit or future deductibility is not probable. We recognize the financial statement effects of a tax position when it is more likely than not, based on the technical merits, that the position will be sustained upon examination. Net Income (Loss) Per Share 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 treasury or if-converted method. Refer to Note 18— Net Income (Loss) per Sh are A ttributable to Common Stockholders for additional details of EPS for the years ended December 31, 2021, 2020 and 2019. Business Segment We have determined that we operate as a single operating and reportable segment. Substantially all of our long-lived assets are located in the United States. Our chief operating decision maker makes resource allocation decisions and assesses performance based on financial information presented on a consolidated basis in the delivery of an integrated source of LNG to our customers. 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. In December 2021, we issued a notice of redemption for all $625 million aggregate principal amount outstanding of 2045 Cheniere Convertible Senior Notes, which were redeemed on January 5, 2022. We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures. See Note 11—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. The transition period under this standard is effective March 12, 2020 and will apply through December 31, 2022. We have various credit facilities and interest rate swaps indexed to LIBOR, as further described in Note 7—Derivative Instruments and Note 11—Debt . To date, we have amended certain of our credit facilities to incorporate a fallback replacement rate indexed to SOFR as a result of the expected LIBOR transition. We elected to apply the optional expedients as applicable to certain modified terms, however the impact of applying the optional expedients has not been material thus far. We will continue to elect to apply the optional expedients to qualifying contract modifications in the future.

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	12 Months Ended
Restricted Cash and Cash Equivalents	Dec. 31, 2021
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS Restricted cash and cash equivalents 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 December 31, 2021 and 2020, restricted cash and cash equivalents consisted of the following (in millions): December 31, 2021 2020 Restricted cash and cash equivalents SPL Project $ 98 $ 97 CCL Project 44 70 Cash held by our subsidiaries that is restricted to Cheniere 271 282 Total restricted cash and cash equivalents $ 413 $ 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.

Accounts and Other Receivables,

Accounts and Other Receivables, Net of Current Expected Credit Losses	12 Months Ended
	Dec. 31, 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 December 31, 2021 and 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions): December 31, 2021 2020 Trade receivables SPL and CCL $ 802 $ 482 Cheniere Marketing 640 113 Other accounts receivable 64 52 Total accounts and other receivables, net of current expected credit losses $ 1,506 $ 647

Inventory

Inventory	12 Months Ended
Inventory	Dec. 31, 2021
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of December 31, 2021 and 2020, inventory consisted of the following (in millions): December 31, 2021 2020 Materials $ 174 $ 150 LNG in-transit 312 88 LNG 153 27 Natural gas 64 26 Other 3 1 Total inventory $ 706 $ 292

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION As of December 31, 2021 and 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): December 31, 2021 2020 LNG terminal LNG terminal and interconnecting pipeline facilities $ 30,660 $ 27,475 LNG site and related costs 441 324 LNG terminal construction-in-process 2,995 5,378 Accumulated depreciation (3,912) (2,935) Total LNG terminal, net of accumulated depreciation 30,184 30,242 Fixed assets and other Computer and office equipment 25 25 Furniture and fixtures 20 19 Computer software 120 117 Leasehold improvements 45 45 Land 1 59 Other 19 25 Accumulated depreciation (176) (164) Total fixed assets and other, net of accumulated depreciation 54 126 Assets under finance lease Tug vessels 60 60 Accumulated depreciation (10) (7) Total assets under finance lease, net of accumulated depreciation 50 53 Property, plant and equipment, net of accumulated depreciation $ 30,288 $ 30,421 The following table shows depreciation expense and offsets to LNG terminal costs during the years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 Depreciation expense $ 1,006 $ 926 $ 788 Offsets to LNG terminal costs (1) 319 19 301 (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. LNG Terminal Costs Our LNG terminals are depreciated using the straight-line depreciation method applied to groups of LNG terminal assets with varying useful lives. The identifiable components of our LNG terminals have depreciable lives between 6 and 50 years, as follows: Components Useful life (years) LNG storage tanks 50 Natural gas pipeline facilities 40 Marine berth, electrical, facility and roads 35 Water pipelines 30 Regasification processing equipment 30 Sendout pumps 20 Liquefaction processing equipment 6-50 Other 10-30 Fixed Assets and Other Our fixed assets and other are recorded at cost and are depreciated on a straight-line method based on estimated lives of the individual assets or groups of assets.

Derivative Instruments

Derivative Instruments	12 Months Ended
Derivative Instruments	Dec. 31, 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 issuances 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 December 31, 2021 and 2020 (in millions): Fair Value Measurements as of December 31, 2021 December 31, 2020 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total CCH Interest Rate Derivatives liability $ — $ (40) $ — $ (40) $ — $ (140) $ — $ (140) Liquefaction Supply Derivatives asset (liability) 7 (9) (4,036) (4,038) 5 (6) 241 240 LNG Trading Derivatives liability (22) (378) — (400) (3) (131) — (134) FX Derivatives asset (liability) — 12 — 12 — (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, but not limited to, evaluation of whether the respective market exists from the perspective of market participants as infrastructure is developed. 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 as of December 31, 2021: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(4,036) Market approach incorporating present value techniques Henry Hub basis spread $(1.368) - $0.628 / $(0.016) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 185% - 662% / 248% (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 years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 Balance, beginning of period $ 241 $ 138 $ (29) Realized and mark-to-market gains (losses): Included in cost of sales (4,305) 156 (77) Purchases and settlements: Purchases (1) 5 199 Settlements 29 (65) 44 Transfers into Level 3, net (1) — 7 1 Balance, end of period $ (4,036) $ 241 $ 138 Change in unrealized gain (loss) relating to instruments still held at end of period $ (4,305) $ 156 $ (77) (1) Transferred into Level 3 as a result of unobservable market, or out of Level 3 as a result of observable market for the underlying natural gas purchase agreements. 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 December 31, 2021, we had the following Interest Rate Derivatives outstanding: Notional Amounts December 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Year Ended December 31, 2021 2020 2019 CCH Interest Rate Derivatives Interest rate derivative loss, net $ (1) $ (138) $ (101) CCH Interest Rate Forward Start Derivatives Interest rate derivative loss, net — (95) (33) Commodity Derivatives SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges, including those associated with transactions under our IPM agreements, 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 one year. The following table shows the notional amounts of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”): December 31, 2021 December 31, 2020 Liquefaction Supply Derivatives LNG Trading Derivatives Liquefaction Supply Derivatives LNG Trading Derivatives Notional amount, net (in TBtu) (1) 11,238 33 10,483 20 (1) The balances as of December 31, 2020 include notional amounts for natural gas supply contracts that SPL and CCL have with related parties. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions . The following table shows the effect and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Year Ended December 31, 2021 2020 2019 LNG Trading Derivatives LNG revenues $ (1,812) $ (26) $ 402 LNG Trading Derivatives Cost of sales 91 (42) (89) Liquefaction Supply Derivatives (2) LNG revenues 3 (1) 2 Liquefaction Supply Derivatives (2) Cost of sales (4,303) 94 194 (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 $762 million and $786 million as of December 31, 2021 and 2020, respectively. The following table shows the effect and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Year Ended December 31, 2021 2020 2019 FX Derivatives LNG revenues $ 33 $ (3) $ 25 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): December 31, 2021 CCH Interest Rate Derivatives Liquefaction Supply Derivatives (1) LNG Trading Derivatives (2) FX Derivatives Total Consolidated Balance Sheets Location Current derivative assets $ — $ 38 $ 2 $ 15 $ 55 Derivative assets — 69 — — 69 Total derivative assets — 107 2 15 124 Current derivative liabilities (40) (644) (402) (3) (1,089) Derivative liabilities — (3,501) — — (3,501) Total derivative liabilities (40) (4,145) (402) (3) (4,590) Derivative asset (liability), net $ (40) $ (4,038) $ (400) $ 12 $ (4,466) 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 $20 million and $9 million as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets. Includes derivative assets for natural gas supply contracts that SPL and CCL had with related parties as of December 31, 2020. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions . (2) Does not include collateral posted with counterparties by us of $745 million and $16 million, as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets. 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 December 31, 2021 Gross assets $ — $ 155 $ 10 $ 48 Offsetting amounts — (48) (8) (33) Net assets $ — $ 107 $ 2 $ 15 Gross liabilities $ (40) $ (4,382) $ (551) $ (10) Offsetting amounts — 237 149 7 Net liabilities $ (40) $ (4,145) $ (402) $ (3) 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)

Other Non-Current Assets

Other Non-Current Assets	12 Months Ended
Other Non-Current Assets	Dec. 31, 2021
Other Assets, Noncurrent [Abstract]
Other Non-Current Assets	OTHER NON-CURRENT ASSETS, NET As of December 31, 2021 and 2020, other non-current assets, net consisted of the following (in millions): December 31, 2021 2020 Contract assets, net of current expected credit losses $ 135 $ 80 Advances made to municipalities for water system enhancements 81 84 Equity method investments 56 81 Advances and other asset conveyances to third parties to support LNG terminals 80 60 Debt issuance costs and debt discount, net of accumulated amortization 34 42 Advances made under EPC and non-EPC contracts 5 9 Advance tax-related payments and receivables 17 20 Other 54 30 Total other non-current assets, net $ 462 $ 406 Equity Method Investments As of December 31, 2021, our equity method investment consists of our interest in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“Midship Pipeline”). Midship Pipeline is currently operating an approximately 200-mile natural gas pipeline project (the “Midship Project”) that connects production in the Anadarko Basin to Gulf Coast markets. The Midship Project commenced operations in April 2020. During the years ended December 31, 2021 and 2020, we recognized other-than-temporary impairment losses of $37 million and $129 million, respectively, related to our investment in Midship Holdings. Impairment during the years ended December 31, 2021 and 2020 was precipitated primarily due to declining market conditions in the energy industry and customer credit risk, resulting in a reduction in the fair value of our equity interests. During the year ended December 31, 2019, we recognized losses of $87 million related to our investments in certain equity method investees, including Midship Holdings. Impairments during the year ended December 31, 2019 were primarily the result of cost overruns and extended construction timelines for operating infrastructure of our investees’ projects, resulting in a reduction of the fair value of our equity interests. The fair values of our equity interests were measured using an income approach, which utilized level 3 fair value inputs such as projected earnings and discount rates, and/or market approach. Impairment losses associated with our equity method investments are presented in other expense, net. Our investment in Midship Holdings, net of impairment losses, was $56 million and $80 million as of December 31, 2021 and 2020, respectively.

Non-Controlling Interest and Va

Non-Controlling Interest and Variable Interest Entity	12 Months Ended
Non-Controlling Interest and Variable Interest Entity	Dec. 31, 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 CQP in the form of 239.9 million common units, with the remaining non-controlling limited partner interest held by Blackstone Inc., Brookfield Asset Management Inc. and the public. In July 2020, the board of directors of CQP’s general partner confirmed and approved that, following the distribution with respect to the three months ended June 30, 2020, the financial tests required for conversion of CQP’s subordinated units, all of which were held by us, were met under the terms of CQP’s partnership agreement. Accordingly, effective August 17, 2020, the first business day following the payment of the distribution, all of CQP’s subordinated units were automatically converted into common units on a one-for-one basis and the subordination period was terminated. We also own 100% of the general partner interest and the incentive distribution rights in CQP. CQP is accounted for as a consolidated VIE. CQP is a limited partnership formed by us in 2006 to own and operate the Sabine Pass LNG Terminal and related assets. Our subsidiary, Cheniere Partners GP, is the general partner of CQP. In 2012, CQP, Cheniere and Blackstone CQP Holdco LP (“Blackstone CQP Holdco”) entered into a unit purchase agreement whereby CQP sold 100.0 million Class B units to Blackstone CQP Holdco in a private placement. The board of directors of Cheniere Partners GP was modified to include three directors appointed by Blackstone CQP Holdco, four directors appointed by us and four independent directors mutually agreed upon by Blackstone CQP Holdco and us and appointed by us. In addition, we provided Blackstone CQP Holdco with a right to maintain one board seat on our Board of Directors (our “Board”). A quorum of Cheniere Partners GP directors consists of a majority of all directors, including at least two directors appointed by Blackstone CQP Holdco, two directors appointed by us and two independent directors. Blackstone CQP Holdco will no longer be entitled to appoint Cheniere Partners GP directors in the event that Blackstone CQP Holdco’s ownership in CQP is less than 20% of outstanding common units and subordinated units. As a holder of common units of CQP, we are not obligated to fund losses of CQP. However, our capital account, which would be considered in allocating the net assets of CQP were it to be liquidated, continues to share in losses of CQP. We have determined that Cheniere Partners GP is a VIE and that we, as the holder of the equity at risk, do not have a controlling financial interest due to the rights held by Blackstone CQP Holdco. However, we continue to consolidate CQP as a result of Blackstone CQP Holdco’s right to maintain one board seat on our Board which creates a de facto agency relationship between Blackstone CQP Holdco and us. GAAP requires that when a de facto agency relationship exists, one of the members of the de facto agency relationship must consolidate the VIE based on certain criteria. As a result, we consolidate CQP in our Consolidated Financial Statements. The following table presents the summarized assets and liabilities (in millions) of CQP, our consolidated VIE, which are included in our Consolidated Balance Sheets as of December 31, 2021 and 2020. The assets in the table below may only be used to settle obligations of CQP. 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 CQP only and exclude intercompany balances that eliminate in consolidation. December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 876 $ 1,210 Restricted cash and cash equivalents 98 97 Accounts and other receivables, net of current expected credit losses 580 318 Other current assets 285 182 Total current assets 1,839 1,807 Property, plant and equipment, net of accumulated depreciation 16,830 16,723 Other non-current assets, net 316 287 Total assets $ 18,985 $ 18,817 LIABILITIES Current liabilities Accrued liabilities $ 1,077 $ 662 Other current liabilities 200 167 Total current liabilities 1,277 829 Long-term debt, net of premium, discount and debt issuance costs 17,177 17,580 Other non-current liabilities 100 126 Total liabilities $ 18,554 $ 18,535

Accrued Liabilities

Accrued Liabilities	12 Months Ended
Accrued Liabilities	Dec. 31, 2021
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of December 31, 2021 and 2020, accrued liabilities consisted of the following (in millions): December 31, 2021 2020 Accrued natural gas purchases $ 1,323 $ 576 Accrued derivative settlements 329 — Interest costs and related debt fees 214 245 LNG terminals and related pipeline costs 144 147 Compensation and benefits 180 123 Accrued LNG inventory 34 4 Other accrued liabilities 75 80 Total accrued liabilities $ 2,299 $ 1,175

Debt

Debt	12 Months Ended
Debt	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt	DEBT As of December 31, 2021 and 2020, our debt consisted of the following (in millions): December 31, 2021 2020 SPL: Senior Secured Notes: 6.25% due 2022 $ — $ 1,000 5.625% due 2023 1,500 1,500 5.75% due 2024 2,000 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.27% weighted average rate due 2037 1,282 800 Total SPL Senior Secured Notes 13,132 13,650 $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”) — — Total debt - SPL 13,132 13,650 CQP: Senior Notes: 5.250% due 2025 — 1,500 5.625% due 2026 — 1,100 4.500% due 2029 1,500 1,500 4.000% due 2031 1,500 — 3.25% due 2032 1,200 — Total CQP Senior Notes 4,200 4,100 CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”) — — Total debt - CQP 4,200 4,100 CCH: Senior Secured Notes: 7.000% due 2024 1,250 1,250 5.875% due 2025 1,500 1,500 5.125% due 2027 1,500 1,500 3.700% due 2029 1,500 1,500 3.72% weighted average rate due 2039 2,721 1,971 Total CCH Senior Secured Notes 8,471 7,721 CCH Credit Facility (1) 1,728 2,627 $1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) (2) 250 140 Total debt - CCH 10,449 10,488 Cheniere: 4.625% Senior Secured Notes due 2028 (“Cheniere Senior Secured Notes”) 2,000 2,000 4.875% Convertible Unsecured Notes due 2021 (“2021 Cheniere Convertible Unsecured Notes”) (1) — 476 2045 Cheniere Convertible Senior Notes (3) 625 625 $1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”) — — Cheniere’s term loan facility (“Cheniere Term Loan Facility”) — 148 Total debt - Cheniere 2,625 3,249 Cheniere Marketing: trade finance facilities and letter of credit facility (2) — — Total debt 30,406 31,487 Current portion of long-term debt (117) (232) Short-term debt (250) (140) Unamortized premium, discount and debt issuance costs, net (590) (644) Total long-term debt, net of premium, discount and debt issuance costs $ 29,449 $ 30,471 (1) A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt. (2) These debt instruments are classified as short-term debt. (3) The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption. Senior Notes SPL Senior Secured Notes The SPL Senior Secured Notes are senior secured obligations of SPL, ranking equally in right of payment with SPL’s other existing and future senior debt and secured by the same collateral and senior in right of payment to any of its future subordinated debt. Subject to permitted liens, the SPL Senior Secured 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, at any time, redeem all or part of the SPL Senior Secured Notes at specified prices set forth in the respective indentures governing the SPL Senior Secured Notes, plus accrued and unpaid interest, if any, to the date of redemption. The series of SPL Senior Secured Notes due in 2037 are fully amortizing according to a fixed sculpted amortization schedule, as set forth in the respective indentures. CQP Senior Notes The CQP Senior Notes are jointly and severally guaranteed by each of CQP’s 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 senior obligations of CQP, ranking equally in right of payment with CQP’s other existing and future unsubordinated debt and senior to any of its future subordinated debt. In the event that the aggregate amount of CQP’s 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 unconditionally guaranteed and secured by a first-priority lien (subject to permitted encumbrances) on substantially all the existing and future tangible and intangible assets and rights of CQP 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. CQP may, at any time, redeem all or part of the CQP Senior Notes at specified prices set forth in the respective indentures governing the CQP Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. CCH Senior Secured Notes The CCH Senior Secured 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 CCH Senior Secured Notes are senior secured obligations of CCH, ranking senior in right of payment to any and all of CCH’s future indebtedness that is subordinated to the CCH Senior Secured 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 Secured Notes. The CCH Senior Secured Notes are secured by a first-priority security interest in substantially all of CCH’s and the CCH Guarantors’ assets. CCH may, at any time, redeem all or part of the CCH Senior Secured Notes at specified prices set forth in the respective indentures governing the CCH Senior Secured Notes, plus accrued and unpaid interest, if any, to the date of redemption. Cheniere Senior Secured Notes The Cheniere Senior Secured 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 Cheniere Senior Secured Notes and equally in right of payment with all of our other existing and future unsubordinated indebtedness. The Cheniere Senior Secured 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 Cheniere Senior Secured 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 December 31, 2021, the Cheniere Senior Secured Notes are not guaranteed by any of our subsidiaries. In the future, the Cheniere Senior Secured Notes will be guaranteed by our subsidiaries who guarantee our other material indebtedness. We may, at any time, redeem all or part of the Cheniere Senior Secured Notes at specified prices set forth in the indenture governing the Cheniere Senior Secured Notes, plus accrued and unpaid interest, if any, to the date of redemption. Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2021 (in millions): Years Ending December 31, Principal Payments 2022 (1) $ 992 2023 1,567 2024 4,794 2025 3,537 2026 1,579 Thereafter 17,937 Total $ 30,406 (1) Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Consolidated Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. See Convertible Notes section below for further discussion of the redemption. Credit Facilities Below is a summary of our committed credit facilities outstanding as of December 31, 2021 (in millions): 2020 SPL Working Capital Facility (1) 2019 CQP Credit Facilities (2) CCH Credit Facility (3) CCH Working Capital Facility (4) Cheniere Revolving Credit Facility (5) Original facility size $ 1,200 $ 1,500 $ 8,404 $ 350 $ 750 Incremental commitments — — 1,566 850 500 Less: Outstanding balance — — 1,729 250 — Commitments prepaid or terminated — 750 8,241 — — Letters of credit issued 395 — — 361 — Available commitment $ 805 $ 750 $ — $ 589 $ 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% (6) LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75% (6) LIBOR plus 1.250% - 2.375% or base rate plus 0.250% - 1.375% (6) Weighted average interest rate of outstanding balance n/a n/a 1.85% 3.50% n/a Commitment fees on undrawn balance 0.20% 0.49% n/a 0.50% 0.25% Maturity date March 19, 2025 May 29, 2024 June 30, 2024 June 29, 2023 October 28, 2026 (1) 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 Secured Notes. The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions (2) See CQP Senior Notes section above for discussion of the rights and privileges of the 2019 CQP Credit Facilities. (3) 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 of its limited liability company interests in CCH. (4) 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 Secured Notes and the CCH Credit Facility. (5) 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 (other than certain excluded subsidiaries). The Cheniere Revolving Credit Facility contains a financial covenant requiring us to maintain a non-consolidated leverage ratio not to exceed 5.50:1.00 as of the end of any fiscal quarter if (i) as of the last day of such fiscal quarter the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit is greater than 35% of the aggregate commitments under the Cheniere Revolving Credit Facility (a “Covenant Trigger Event”) or (ii) a Covenant Trigger Event had occurred and been continuing as of the last day of the immediately preceding fiscal quarter and as of the last day of such ending fiscal quarter such Covenant Trigger Event had not ceased for a period of at least thirty consecutive days. (6) These facilities were amended in 2021 to establish a SOFR-indexed replacement rate for LIBOR. Convertible Notes As of December 31, 2021, we had $625 million aggregate principal amount of the 2045 Cheniere Convertible Senior Notes outstanding, of which $321 million was recorded as debt, net of discount and debt issuance costs of $304 million, and $194 million was recorded as equity. The effective interest rate as of December 31, 2021 was 9.4%, which was the rate to accrete the discounted carrying value of the notes to the face value over the remaining contractual amortization period. Subject to various limitations and conditions under the indenture, the notes were convertible by us or by the holders to 7.2265 shares of our common stock per $1,000 principal amount. Additionally, we had the right, at our option, to redeem all or any part of the 2045 Cheniere Convertible Senior Notes at a redemption price equal to the accreted amount of the notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date. On December 6, 2021, we issued a notice of redemption for all $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes. The notice of redemption allowed holders to elect to convert their notes at any time prior to a specified deadline on December 31, 2021, with settlement of such converted notes in cash, as elected by the Company, on January 5, 2022. The impact of holders electing conversion was immaterial to the financial statements. The 2045 Cheniere Convertible Senior Notes not converted were redeemed on January 5, 2022 with borrowings under the Cheniere Revolving Credit Facility. 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. SPL, CQP and CCH are restricted from making distributions under agreements governing their respective indebtedness generally until, among other requirements, deposits are made into any required debt service reserve accounts and a historical debt service coverage ratio and projected debt service coverage ratio of at least 1.25:1.00 is satisfied. At December 31, 2021, our restricted net assets of consolidated subsidiaries were approximately $1.5 billion. As of December 31, 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): Year Ended December 31, 2021 2020 2019 Interest cost on convertible notes: Interest per contractual rate $ 36 $ 152 $ 256 Amortization of debt discount 10 45 40 Amortization of debt issuance costs — 8 12 Total interest cost related to convertible notes 46 205 308 Interest cost on debt and finance leases excluding convertible notes 1,558 1,568 1,538 Total interest cost 1,604 1,773 1,846 Capitalized interest (166) (248) (414) Total interest expense, net of capitalized interest $ 1,438 $ 1,525 $ 1,432 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): December 31, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 24,550 $ 26,725 $ 24,700 $ 27,897 Senior notes — Level 3 (2) 3,253 3,693 2,771 3,423 Credit facilities — Level 3 (3) 1,978 1,978 2,915 2,915 2021 Cheniere Convertible Unsecured Notes — Level 3 (2) — — 476 480 2045 Cheniere Convertible Senior Notes — Level 1 (4) 625 526 625 496 (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.

Leases

Leases	12 Months Ended
Leases	Dec. 31, 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): December 31, Consolidated Balance Sheets Location 2021 2020 Right-of-use assets—Operating Operating lease assets $ 2,102 $ 759 Right-of-use assets—Financing Property, plant and equipment, net of accumulated depreciation 50 53 Total right-of-use assets $ 2,152 $ 812 Current operating lease liabilities Current operating lease liabilities $ 535 $ 161 Current finance lease liabilities Other current liabilities 2 2 Non-current operating lease liabilities Operating lease liabilities 1,541 597 Non-current finance lease liabilities Finance lease liabilities 57 57 Total lease liabilities $ 2,135 $ 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 Year Ended December 31, 2021 2020 2019 Operating lease cost (a) Operating costs and expenses (1) $ 621 $ 432 $ 612 Finance lease cost: Amortization of right-of-use assets Depreciation and amortization expense 3 2 3 Interest on lease liabilities Interest expense, net of capitalized interest 9 7 10 Total lease cost $ 633 $ 441 $ 625 (a) Included in operating lease cost: Short-term lease costs $ 139 $ 93 $ 230 Variable lease costs 21 16 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. Future annual minimum lease payments for operating and finance leases as of December 31, 2021 are as follows (in millions): Years Ending December 31, Operating Leases (1) Finance Leases 2022 $ 600 $ 11 2023 514 10 2024 456 10 2025 244 10 2026 218 10 Thereafter 294 117 Total lease payments 2,326 168 Less: Interest (250) (109) Present value of lease liabilities $ 2,076 $ 59 (1) Does not include approximately $1.2 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of December 31, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to 10 years. The following table shows the weighted-average remaining lease term and the weighted-average discount rate for our operating leases and finance leases: December 31, 2021 December 31, 2020 Operating Leases Finance Leases Operating Leases Finance Leases Weighted-average remaining lease term (in years) 5.6 16.7 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): Year Ended December 31, 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 483 $ 309 $ 389 Operating cash flows from finance leases 10 10 9 Right-of-use assets obtained in exchange for operating lease liabilities 1,736 615 235 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 December 31, 2021 and 2020, we had $15 million and zero 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): Year Ended December 31, 2021 2020 2019 Fixed income $ 72 $ 68 $ 122 Variable income 37 27 22 Total sublease income $ 109 $ 95 $ 144

Revenues from Contracts with Cu

Revenues from Contracts with Customers	12 Months Ended
Revenues from Contracts with Customers	Dec. 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 LNG revenues (1) $ 17,171 $ 8,954 $ 8,817 Regasification revenues 269 269 266 Other revenues 91 70 74 Total revenues from customers 17,531 9,293 9,157 Net derivative gain (loss) (2) (1,776) (30) 429 Other (3) 109 95 144 Total revenues $ 15,864 $ 9,358 $ 9,730 (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 year ended December 31, 2020, we recognized $969 million in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $38 million would have been recognized during the year ended December 31, 2021 had the cargoes been 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 years ended December 31, 2021 and 2019. 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 7—Derivative Instruments for additional information about our derivatives. (3) Includes revenues from LNG vessel subcharters. See Note 12—Leases for additional information about our subleases. LNG Revenues We have entered into numerous SPAs with third party customers for the sale of LNG on a free on board (“FOB”) (delivered to the customer at either the Sabine Pass or Corpus Christi LNG terminal) or delivered at terminal (“DAT”) (delivered to the customer at their LNG receiving terminal) basis. Our customers generally purchase LNG 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 115% of Henry Hub. The fixed fee component is the amount payable to us regardless of a cancellation or suspension of LNG cargo deliveries by the customers. The variable fee component is the amount generally payable to us only upon delivery of LNG plus all future adjustments to the fixed fee for inflation. 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. We intend to primarily use LNG sourced from our Sabine Pass or Corpus Christi LNG terminals to provide contracted volumes to our customers. However, we supplement this LNG with volumes procured from third parties. LNG revenues recognized from LNG that was procured from third parties was $499 million, $414 million and $268 million for the years ended December 31, 2021, 2020 and 2019, respectively. Revenues from the sale of LNG are recognized at a point in time when the LNG is delivered to the customer, either at the Sabine Pass or Corpus Christi LNG terminal or at the customer’s LNG receiving terminal, based on the terms of the contract, which is the point legal title, physical possession and the risks and rewards of ownership transfer to the customer. Each individual molecule of LNG is viewed as a separate performance obligation. The stated contract price (including both fixed and variable fees) per MMBtu in each LNG sales arrangement is representative of the stand-alone selling price for LNG at the time the contract was negotiated. We have concluded that the variable fees meet the exception for allocating variable consideration to specific parts of the contract. As such, the variable consideration for these contracts is allocated to each distinct molecule of LNG and recognized when that distinct molecule of LNG is delivered to the customer. Because of the use of the exception, variable consideration related to the sale of LNG is also not included in the transaction price. When we sell LNG on a DAT basis, we consider all transportation costs, including vessel chartering, loading/unloading and canal fees, as fulfillment costs and not as separate services provided to the customer within the arrangement, regardless of whether or not such activities occur prior to or after the customer obtains control of the LNG. We expense fulfillment costs as incurred unless otherwise dictated by GAAP. Fees received pursuant to SPAs are recognized as LNG revenues only after substantial completion of the respective Train. Prior to substantial completion, sales generated during the commissioning phase are offset against the cost of construction for the respective Train, as the production and removal of LNG from storage is necessary to test the facility and bring the asset to the condition necessary for its intended use. Regasification Revenues The Sabine Pass LNG Terminal has operational regasification capacity of approximately 4 Bcf/d. Approximately 2 Bcf/d of the regasification capacity at the Sabine Pass LNG Terminal has been reserved under two long-term TUAs with unaffiliated third party customers, under which they are required to pay fixed monthly fees regardless of their use of the LNG terminal. Each of the customers has reserved approximately 1 Bcf/d of regasification capacity. The customers are each obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually for 20 years that commenced in 2009, which is representative of fixed consideration in the contract. A portion of this fee is adjusted annually for inflation which is considered variable consideration. The remaining capacity of the Sabine Pass LNG Terminal has been reserved by SPL, for which the associated revenues are eliminated in consolidation. Because SPLNG is continuously available to provide regasification service on a daily basis with the same pattern of transfer, we have concluded that SPLNG provides a single performance obligation to its customers on a continuous basis over time. We have determined that an output method of recognition based on elapsed time best reflects the benefits of this service to the customer and accordingly, LNG regasification capacity reservation fees are recognized as regasification revenues on a straight-line basis over the term of the respective TUAs. In 2012, SPL entered into a partial TUA assignment agreement with TotalEnergies Gas & Power North America, Inc. (“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 and permit SPL to more flexibly manage its LNG storage capacity. 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 and we continue to recognize the payments received from Total as revenue. During the years ended December 31, 2021, 2020 and 2019, SPL recorded $129 million, $129 million and $104 million, respectively, as operating and maintenance expense under this partial TUA assignment agreement. 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): December 31, 2021 2020 Contract assets, net of current expected credit losses $ 140 $ 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 year ended December 31, 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): Year Ended December 31, 2021 Deferred revenue, beginning of period $ 138 Cash received but not yet recognized in revenue 194 Revenue recognized from prior period deferral (138) Deferred revenue, end of period $ 194 We record deferred revenue when we receive consideration, or such consideration is unconditionally due from a customer, prior to transferring goods or services to the customer under the terms of a sales contract. Changes in deferred revenue during the years ended December 31, 2021 and 2020 are primarily attributable to differences between the timing of revenue recognition and the receipt of advance payments related to delivery of LNG under certain SPAs. 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 December 31, 2021 and 2020: December 31, 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 $ 107.1 9 $ 102.3 10 Regasification revenues 1.9 4 2.1 5 Total revenues $ 109.0 $ 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 60% and 40% of our LNG revenues from contracts included in the table above during the years ended December 31, 2021 and 2020, respectively, were related to variable consideration received from customers. During each of the years ended December 31, 2021 and 2020, approximately 5% 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.

Related Party Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2021
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Natural Gas Supply Agreements SPL Natural Gas Supply Agreement SPL was party to a natural gas supply agreement with a related party in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the SPL Project. This related party was partially owned by Blackstone Inc., who also partially owns CQP’s limited partner interests. This entity was acquired by a non-related party on December 31, 2021; therefore, as of such date, this agreement ceased to be considered a related party agreement. CCL Natural Gas Supply Agreement CCL was party to a natural gas supply agreement with a related party in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the CCL Project. However, this entity was acquired by a non-related party on November 1, 2021; therefore, as of such date, this agreement ceased to be considered a related party and the related party transactions disclosed herein were recognized prior to this date. The Liquefaction Supply Derivatives related to this agreement were recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount): December 31, 2021 2020 Current derivative assets $ — $ 3 Derivative assets — 1 Notional amount (in TBtu) — 60 We recorded the following amounts on our Consolidated Statements of Operations during the years ended December 31, 2021, 2020 and 2019 related to these agreements (in millions): Year Ended December 31, 2021 2020 2019 Cost of sales (a) (1) $ 162 $ 114 $ 85 (a) Included in costs of sales: Liquefaction Supply Derivative gain (1) $ 13 $ (1) $ (1) (1) Includes amounts recorded related to natural gas supply contracts that SPL and CCL had with related parties. These agreements ceased to be considered related party agreements during 2021, as discussed above. 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 CQP’s limited partner interests in September 2020. We recorded LNG revenue of $1 million and zero, operating and maintenance expense of $46 million and $13 million and cost of sales of $1 million and zero during the years ended December 31, 2021 and 2020, respectively. Additionally, we recorded accrued liabilities of $4 million as of both December 31, 2021 and 2020 with this related party. CCL is party to natural gas transportation agreements with 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, which manages the business and affairs of Midship Pipeline, as an equity method investment. We recorded operating and maintenance expense of $9 million and $6 million during the years ended December 31, 2021 and 2020, respectively. Additionally, we recorded accrued liabilities of $1 million as of both December 31, 2021 and 2020 with this related party. Operation and Maintenance Service Agreements

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES The jurisdictional components of income before income taxes and non-controlling interest on our Consolidated Statements of Operations for the years ended December 31, 2021, 2020 and 2019 are as follows (in millions): Year Ended December 31, 2021 2020 2019 U.S. $ (2,317) $ 720 $ 289 International 39 (176) 426 Total income (loss) before income taxes and non-controlling interest $ (2,278) $ 544 $ 715 Income tax provision (benefit) included in our reported net income consisted of the following (in millions): Year Ended December 31, 2021 2020 2019 Current: Federal $ — $ — $ — State 3 — — Foreign 5 — 4 Total current 8 — 4 Deferred: Federal (633) 41 (475) State (89) 2 (46) Foreign 1 — — Total deferred (721) 43 (521) Total income tax provision (benefit) $ (713) $ 43 $ (517) Our income tax rates do not bear a customary relationship to statutory income tax rates. A reconciliation of the federal statutory income tax rate of 21% to our effective income tax rate is as follows: Year Ended December 31, 2021 2020 2019 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Non-controlling interest 7.2 (22.6) (17.2) State tax, net of federal benefit (2.5) — (5.4) Executive compensation (0.5) 1.4 1.3 Nondeductible interest expense — 8.0 5.0 Foreign earnings taxed in the U.S. — 1.2 6.7 Foreign rate differential (0.1) (3.7) (11.4) Tax credits 0.6 (4.5) (5.2) Internal restructuring — 7.0 — Other — 1.0 1.4 Valuation allowance 5.6 (0.9) (68.5) Effective tax rate as reported 31.3 % 7.9 % (72.3) % Significant components of our deferred tax assets and liabilities at December 31, 2021 and 2020 are as follows (in millions): December 31, 2021 2020 Deferred tax assets Net operating loss carryforwards and credits Federal $ 3,231 $ 3,084 Foreign 2 3 State 244 257 Federal and state tax credits 108 95 Derivative instruments 951 7 Other 584 283 Less: valuation allowance (63) (190) Total deferred tax assets 5,057 3,539 Deferred tax liabilities Investment in partnerships (716) (765) Property, plant and equipment (2,638) (2,089) Other (499) (196) Total deferred tax liabilities (3,853) (3,050) Net deferred tax assets $ 1,204 $ 489 Valuation Allowance We recognize deferred tax assets and liabilities for future tax consequences arising from differences between the carrying amounts of existing assets and liabilities under GAAP and their respective tax bases, and for net operating loss (“NOL”) carryforwards and tax credit carryforwards. We evaluate the realizability of our deferred tax assets as of each reporting date, weighing all positive and negative evidence, and establish a valuation allowance if we determine that it is more likely than not that some or all of our deferred tax assets will not be realized. The assessment requires significant judgment and is performed in each of our applicable jurisdictions. In making such determination, we consider various factors such as historical profitability, future projections of sustained profitability underpinned by fixed-price long-term SPAs, reversal of existing deferred tax liabilities, construction and operational milestones reached on our Liquefaction Projects and our long-term SPAs achieving date of first commercial delivery. We recorded a valuation allowance of $190 million in 2020 against our deferred tax assets. Our valuation allowance decreased by $127 million for the year ended December 31, 2021, which was primarily attributable to a portion of our Louisiana NOLs no longer requiring a valuation allowance. Positive evidence supporting such conclusion included a change in Louisiana tax law allowing for indefinite carryover of NOLs, coupled with successful completion and subsequent operations of Train 3 of the CCL Project, and forecasts of sustained future profitability underpinned by fixed-price long-term SPAs. We maintained a valuation allowance of $63 million at December 31, 2021 primarily against state NOL carryforward deferred tax assets, for which we continue to believe the more likely than not recognition threshold was not met. NOL and tax credit carryforwards As of December 31, 2021, we had federal, state and foreign NOL carryforwards of approximately $15.7 billion, $2.4 billion and $10.0 million, respectively. Approximately $13.8 billion of our NOLs have an indefinite carryforward period. All other NOLs will expire between 2028 and 2037. As of December 31, 2021, we had federal and state tax credit carryforwards of $107 million and $1 million, respectively. The federal tax credit carryforwards include investment tax credit carryforwards of $60 million related to capital equipment placed in service at our Liquefaction Projects. We account for our federal investment tax credits under the flow-through method. The federal tax credit carryforwards also include $44 million of foreign tax credits related to tax years 2014 through 2021. The federal and state tax credit carryforwards will expire between 2024 and 2041. We experienced an ownership change within the provisions of U.S. Internal Revenue Code (“IRC”) Section 382 in 2008, 2010 and 2012. An analysis of the annual limitation on the utilization of our NOLs was performed in accordance with IRC Section 382. It was determined that IRC Section 382 will not limit the use of our NOLs over the carryover period. We continue to monitor trading activity in our shares which may cause an additional ownership change which could ultimately affect our ability to fully utilize our existing NOL carryforwards. Unrecognized Tax Benefits As of December 31, 2021, we had unrecognized tax benefits of $65 million. If recognized, $56 million of unrecognized tax benefits would affect our effective tax rate in future periods. Currently, we do not recognize interest and penalties associated with the unrecognized tax benefits provided in our Consolidated Statements of Operations or our Consolidated Balance Sheets because settlement of uncertain tax positions would result in an adjustment to our NOL carryforward. Interest and penalties related to income tax matters would be recognized as part of income tax expense. We are subject to tax in the U.S. and various state and foreign jurisdictions and we remain subject to periodic audits and reviews by taxing authorities. Federal and state tax returns for the years after 2017 remain open for examination. Tax authorities may have the ability to review and adjust carryover attributes that were generated prior to these periods if utilized in an open tax year. A reconciliation of the beginning and ending amounts of our unrecognized tax benefits for the years ended December 31, 2021 and 2020, is as follows (in millions): Year Ended December 31, 2021 2020 Balance at beginning of the year $ 62 $ 61 Additions based on tax positions related to current year 3 1 Additions for tax positions of prior years — — Reductions for tax positions of prior years — — Settlements — — U.S. tax reform rate change — — Balance at end of the year $ 65 $ 62

Share-Based Compensation

Share-Based Compensation	12 Months Ended
Share-Based Compensation	Dec. 31, 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”). The 2011 Plan and the 2020 Incentive Plan provide for the issuance of 35.0 million shares and 8.0 million shares, respectively, of our common stock that may be in the form of various share-based performance awards deemed by the Compensation Committee of our Board (the “Compensation Committee”). We recognize share-based compensation based upon the estimated fair value of awards. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. For equity-classified share-based compensation awards (which include restricted stock shares, restricted stock units and performance stock units granted to employees and non-employee directors), compensation cost is recognized based on the grant-date fair value and not subsequently remeasured unless modified. The fair value is recognized as expense (net of any capitalization) using the straight-line basis for awards that vest based solely on service conditions and using the accelerated recognition method for awards that vest based on performance conditions. For awards with both time and performance-based conditions, we recognize compensation cost based on the probable outcome of the performance condition at each reporting period. For liability-classified share-based compensation awards that cash settle (which include phantom units and a portion of performance stock units), compensation costs are remeasured at fair value through settlement or maturity. We account for forfeitures as they occur. Total share-based compensation consisted of the following (in millions): Year Ended December 31, 2021 2020 2019 Share-based compensation costs, pre-tax: Equity awards $ 105 $ 114 $ 131 Liability awards (1) 40 2 9 Total share-based compensation 145 116 140 Capitalized share-based compensation (5) (6) (9) Total share-based compensation expense $ 140 $ 110 $ 131 Tax benefit associated with share-based compensation expense $ 33 $ 23 $ 14 (1) The amount of share-based compensation recognized in 2021 associated with liability awards includes 0.2 million of performance share units held by five employees that are scheduled to vest in 2022 that were reclassified from equity awards to liability awards during 2021 as a result of a modification to settle the awards in cash in lieu of shares. We recognized approximately $18 million in incremental expense as a result of the modification. The total unrecognized compensation cost at December 31, 2021 relating to non-vested share-based compensation arrangements consisted of the following: Unrecognized Compensation Cost Recognized over a weighted average period Restricted Stock Share Awards $ 1 0.3 Restricted Stock Unit and Performance Stock Unit Awards $ 140 1.5 Restricted Stock Share Awards Restricted stock share awards are awards of common stock that are 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. These awards vest based on service conditions ( one two three four The table below provides a summary of our restricted stock outstanding (in millions, except for per share information): Shares Weighted Average Grant Date Fair Value Per Share Non-vested at January 1, 2021 0.1 $ 41.78 Granted 0.0 0.00 Vested (0.1) 45.10 Forfeited 0.0 0.00 Non-vested at December 31, 2021 0.0 $ 0.00 The fair value of restricted stock share awards vested for the years ended December 31, 2021, 2020 and 2019 were $2 million, $3 million and $3 million, respectively. Restricted Stock Unit and 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 a performance condition consisting of cumulative distributable cash flow per share, and in certain circumstances, a market condition consisting of absolute total shareholder return (“ATSR”) of our common stock. All performance stock units will settle entirely in stock, with the exception of awards granted in 2021 and 2022 to certain officers which will settle in cash up to a cap of $3 million and certain awards vesting in 2022 that settled in cash in lieu of shares. In addition, in December 2021 the Board authorized the Compensation Committee, in its discretion, to permit certain officers to make an election to cash settle their performance stock units that are earned and vest in 2023 and 2024. Where applicable, the compensation for performance stock units containing a market condition of ATSR is based on a fair value assigned to the market metric using a Monte Carlo model as of the grant date, which utilizes level 3 inputs such as projected stock volatility and projected risk free rates, and remains constant through the vesting period for the equity-settled component and is remeasured each reporting period for the cash-settled component. Compensation cost attributed to the performance metric 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 and 2022 will partially settle in cash, subject to individual limits. In addition, in December 2021 the Board authorized the Compensation Committee, in its discretion, to permit certain officers to make an election to cash settle their performance stock units that are earned and vest in 2023 and 2024. 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. The table below provides a summary of our restricted share unit and performance stock unit awards outstanding assuming payout at target for awards containing performance conditions (in millions, except for per unit information): Units Weighted Average Grant Date Fair Value Per Unit Non-vested at January 1, 2021 3.7 $ 60.00 Granted (1) 2.2 70.99 Vested (2.1) 59.57 Forfeited (0.1) 64.31 Non-vested at December 31, 2021 (2) 3.7 $ 66.71 (1) This number includes 0.2 million incremental shares of our common stock that were issued based on performance results from previously-granted performance stock unit awards. (2) This number excludes 1.3 million performance stock units, which represent the incremental number of common units that would be issued if the maximum level of performance under the target awards amount is achieved. The table below provides a summary of restricted share unit and performance stock unit awards issued and fair value of units vested: Year Ended December 31, 2021 2020 2019 Units issued (in millions) 2.2 1.8 1.9 Weighted average grant date fair value per unit $ 70.99 $ 53.88 $ 67.47 Fair value of units vested (in millions) $ 123 $ 137 $ 45 Phantom Units Awards Phantom units are share-based awards granted to employees over a vesting period that entitle the grantee to receive the cash equivalent to the value of a share of our common stock upon each vesting. Phantom units are not eligible to receive quarterly distributions. These awards vest based on service conditions ( two three four

Employee Benefit Plan

Employee Benefit Plan	12 Months Ended
Employee Benefit Plan	Dec. 31, 2021
Retirement Benefits [Abstract]
Employee Benefit Plan	EMPLOYEE BENEFIT PLANWe have a defined contribution plan (“401(k) Plan”) which allows eligible employees to contribute up to 75% of their compensation up to the Internal Revenue Service maximum. We match each employee’s deferrals (contributions) up to 6% of compensation and may make additional contributions at our discretion. Employees are immediately vested in the contributions made by us. Our contributions to the 401(k) Plan were $15 million for each of the years ended December 31, 2021, 2020 and 2019. We have made no discretionary contributions to the 401(k) Plan to date.

Net Income (Loss) Per Share Att

Net Income (Loss) Per Share Attributable to Common Stockholders	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Net Income (Loss) Per Share Attributable to Common Stockholders	NET INCOME (LOSS) PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS The following table reconciles basic and diluted weighted average common shares outstanding for the years ended December 31, 2021, 2020 and 2019 (in millions, except per share data): Year Ended December 31, 2021 2020 2019 Net income (loss) attributable to common stockholders $ (2,343) $ (85) 648 Weighted average common shares outstanding: Basic 253.4 252.4 256.2 Dilutive unvested stock — — 1.9 Diluted 253.4 252.4 258.1 Net income (loss) per share attributable to common stockholders—basic $ (9.25) $ (0.34) $ 2.53 Net income (loss) per share attributable to common stockholders—diluted $ (9.25) $ (0.34) $ 2.51 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): Year Ended December 31, 2021 2020 2019 Unvested stock (1) 1.8 3.4 2.3 Convertible notes 2021 Cheniere Convertible Unsecured Notes (2) — — 13.7 11% Convertible Senior Secured Notes due 2025 (“2025 CCH HoldCo II Convertible Senior Notes”) (3) — — 25.5 2045 Cheniere Convertible Senior Notes (4) — 4.5 4.5 Total potentially dilutive common shares 1.8 7.9 46.0 (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. (2) In the second quarter of 2021, we repaid the remaining principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash; therefore, the 2021 Cheniere Convertible Unsecured Notes were not included in the computation of net income per share for the year ended December 31, 2021. Additionally, since we had the intent and ability to settle the remaining outstanding principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash and the excess conversion premium (the “conversion spread”) in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2020. However, since the average market price of our common stock did not exceed the conversion price of our 2021 Cheniere Convertible Unsecured Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2020. (3) In the third quarter of 2020, we redeemed the remaining principal amount of the 2025 CCH HoldCo II Convertible Senior Notes and the related premium in cash; therefore, the 2025 CCH HoldCo II Convertible Senior Notes were not included in the computation of net income per share for the year ended December 31, 2021 and 2020. (4) Since we had the intent and ability to settle the outstanding principal amount of the 2045 Cheniere Convertible Senior Notes in cash and the conversion spread in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2021. However, since the average market price of our common stock did not exceed the conversion price for our 2045 Cheniere Convertible Senior Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2021.

Stockholders' Equity

Stockholders' Equity	12 Months Ended
Stockholders' Equity	Dec. 31, 2021
Equity [Abstract]
Stockholders' Equity	STOCKHOLDERS’ EQUITY Share Repurchase Programs On June 3, 2019, we announced that our Board authorized a three Year Ended December 31, 2021 2020 2019 Aggregate common stock repurchased 0.1 2.9 4.0 Weighted average price paid per share $ 87.32 $ 53.88 $ 62.27 Total amount paid $ 9 $ 155 $ 249 As of December 31, 2021, we had up to $998 million of the share repurchase program available. Dividends

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES We have various contractual obligations which are recorded as liabilities in our Consolidated Financial Statements. Other items, such as certain unconditional purchase commitments and other executed contracts which do not meet the definition of a liability as of December 31, 2021, are not recognized as liabilities but require disclosures in our Consolidated Financial Statements. LNG Terminal Commitments and Contingencies EPC Contract SPL has a lump sum turnkey contract with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for the engineering, procurement and construction of Train 6 of the SPL Project. The total contract price of the EPC contract for Train 6 of the SPL Project, which achieved substantial completion on February 4, 2022, and the third marine berth that is currently under construction is approximately $2.5 billion, reflecting amounts incurred under change orders through December 31, 2021. As of December 31, 2021, we had approximately $0.2 billion remaining under this contract. Natural Gas Supply, Transportation and Storage Service Agreements SPL, CCL and CCL Stage III have physical natural gas supply contracts to secure natural gas feedstock for the SPL Project, the CCL Project and potential future development of Corpus Christi Stage 3, respectively. The remaining terms of these contracts range up to 15 years. Additionally, SPL and CCL have natural gas transportation and storage service agreements for the SPL Project and the CCL Project, respectively. The initial terms of the natural gas transportation agreements range up to 20 years for the SPL Project and the CCL Project, with renewal options for certain contracts, and commence upon the occurrence of conditions precedent. The initial term of the natural gas storage service agreements for the SPL Project ranges up to 10 years and the initial term of the natural gas storage service agreements for the CCL Project ranges up to five years. As of December 31, 2021, the obligations of SPL, CCL and CCL Stage III under natural gas supply, transportation and storage service agreements for contracts in which conditions precedent were met were as follows (in billions): Years Ending December 31, Payments Due (1) 2022 $ 8.8 2023 6.3 2024 4.6 2025 3.3 2026 2.7 Thereafter 16.5 Total $ 42.2 (1) Pricing of natural gas supply contracts is variable based on market commodity basis prices adjusted for basis spread, and pricing of IPM agreements is variable based on global gas market prices less fixed liquefaction fees and certain costs by us . Amounts included are based on estimated forward prices and basis spreads as of December 31, 2021. Some of our contracts may not have been negotiated as part of arranging financing for the underlying assets providing the natural gas supply, transportation and storage services. Does not include incremental volumes of approximately 1,790 TBtu and 548 TBtu, respectively, pursuant to an amended IPM agreement and gas supply agreement with EOG Resources, Inc. that was executed subsequent to December 31, 2021, a portion of which is conditional on the in-service date of certain asset infrastructure and substantially all of which will be delivered after 2026. Environmental and Regulatory Matters Our LNG terminals and pipelines are subject to extensive regulation under federal, state and local statutes, rules, regulations and laws. These laws require that we engage in consultations with appropriate federal and state agencies and that we obtain and maintain applicable permits and other authorizations. Failure to comply with such laws could result in legal proceedings, which may include substantial penalties. We believe that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our results of operations, financial condition or cash flows. Legal Proceedings We are, and 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. We recognize legal costs in connection with legal and regulatory matters as they are incurred. While the results of these litigation matters and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material impact on our operating results, financial position or cash flows.

Customer Concentration

Customer Concentration	12 Months Ended
Customer Concentration	Dec. 31, 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 Year Ended December 31, December 31, 2021 2020 2019 2021 2020 Customer A 12% 14% 16% 10% 14% Customer B 12% 12% 10% * 12% Customer C 10% 10% 11% * * Customer D * 10% 11% * * * Less than 10% The following table shows revenues from external customers attributable to the country in which the revenues were derived (in millions). We attribute revenues from external customers to the country in which the party to the applicable agreement has its principal place of business. Revenues from External Customers Year Ended December 31, 2021 2020 2019 Ireland $ 1,838 $ 1,130 $ 989 Singapore 1,740 646 533 South Korea 1,680 942 1,207 Spain 1,577 1,034 598 India 1,375 1,021 1,160 United States 1,340 2,466 2,807 United Kingdom 1,246 678 559 Other countries 5,068 1,441 1,877 Total $ 15,864 $ 9,358 $ 9,730

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
Supplemental Cash Flow Information	Dec. 31, 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): Year Ended December 31, 2021 2020 2019 Cash paid during the period for interest on debt, net of amounts capitalized $ 1,365 $ 1,395 $ 1,126 Cash paid for income taxes, net of refunds 4 2 24 Non-cash investing and financing activities: Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities 339 282 473

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information of Registrant	12 Months Ended
Schedule I - Condensed Financial Information of Registrant	Dec. 31, 2021
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information of Registrant	CHENIERE ENERGY, INC. CONDENSED STATEMENTS OF OPERATIONS (in millions) Year Ended December 31, 2021 2020 2019 General and administrative expense $ 17 $ 20 $ 17 Depreciation expense 1 — — Total operating costs and expenses 18 20 17 Other income (expense) Interest expense, net of capitalized interest (151) (155) (141) Interest income — — 1 Loss on modification or extinguishment of debt (6) (50) — Equity in income (loss) of subsidiaries (2,584) 77 490 Total other income (expense) (2,741) (128) 350 Income (loss) before income taxes (2,759) (148) 333 Less: income tax benefit (416) (63) (315) Net income (loss) attributable to common stockholders $ (2,343) $ (85) $ 648 The accompanying notes are an integral part of these condensed financial statements. CHENIERE ENERGY, INC. CONDENSED BALANCE SHEETS (in millions) December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 17 $ — Restricted cash and cash equivalents — 1 Other current assets 1 1 Total current assets 18 2 Property, plant and equipment, net of accumulated depreciation 35 30 Operating lease assets 19 22 Debt issuance and deferred financing costs, net of accumulated amortization 16 15 Investments in subsidiaries — 2,324 Deferred tax assets 797 381 Total assets $ 885 $ 2,774 LIABILITIES AND STOCKHOLDERS’ DEFICIT Current liabilities Current operating lease liabilities $ 6 $ 5 Current debt — 103 Other current liabilities 30 37 Total current liabilities 36 145 Long-term debt, net of discount and debt issuance costs 2,285 2,790 Investments in subsidiaries 1,110 — Operating lease liabilities 24 30 Other non-current liabilities 1 — Stockholders’ deficit (2,571) (191) Total liabilities and stockholders’ deficit $ 885 $ 2,774 The accompanying notes are an integral part of these condensed financial statements. CHENIERE ENERGY, INC. CONDENSED STATEMENTS OF CASH FLOWS (in millions) Year Ended December 31, 2021 2020 2019 Net cash provided by (used in) operating activities $ (232) $ (285) $ 74 Cash flows from investing activities Property, plant and equipment (6) (13) (2) Distribution from (investment in) subsidiaries 1,498 (481) 842 Net cash provided by (used in) investing activities 1,492 (494) 840 Cash flows from financing activities Proceeds from issuance of debt 1,579 4,778 — Redemptions and repayments of debt (2,022) (3,143) — Debt issuance and other financing costs (9) (57) — Debt modification or extinguishment costs (1) (29) — Cash dividends to shareholders (85) — — Distributions to non-controlling interest (649) (626) (591) Payments related to tax withholdings for share-based compensation (48) (43) (19) Repurchase of common stock (9) (155) (249) Net cash provided by (used in) financing activities (1,244) 725 (859) Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents 16 (54) 55 Cash, cash equivalents and restricted cash and cash equivalents—beginning of period 1 55 — Cash, cash equivalents and restricted cash and cash equivalents—end of period $ 17 $ 1 $ 55 Balances per Condensed Balance Sheets: December 31, 2021 2020 Cash and cash equivalents $ 17 $ — Restricted cash and cash equivalents — 1 Total cash, cash equivalents and restricted cash and cash equivalents $ 17 $ 1 The accompanying notes are an integral part of these condensed financial statements. NOTE 1—SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The Condensed Financial Statements represent the financial information required by Securities and Exchange Commission Regulation S-X 5-04 for Cheniere. In the Condensed Financial Statements, Cheniere’s investments in affiliates are presented at the net amount attributable to Cheniere. Under this method, the assets and liabilities of affiliates are not consolidated. The investments in net assets of the affiliates are recorded on the Condensed Balance Sheets. The income from operations of the affiliates is reported on a net basis as investment in affiliates (equity in income of subsidiaries). A substantial amount of Cheniere’s operating, investing and financing activities are conducted by its affiliates. The Condensed Financial Statements should be read in conjunction with Cheniere’s Consolidated Financial Statements. Recent Accounting Standards 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. The transition period under this standard is effective March 12, 2020 and will apply through December 31, 2022. We have a revolving credit facility indexed to LIBOR. To date, we have amended our revolving credit facility to incorporate a fallback replacement rate indexed to SOFR as a result of the expected LIBOR transition. We elected to apply the optional expedients as applicable to certain modified terms, however the impact of applying the optional expedients has not been material thus far. We will continue to elect to apply the optional expedients to qualifying contract modifications in the future. NOTE 2—DEBT As of December 31, 2021 and 2020, our debt consisted of the following (in millions): December 31, 2021 2020 4.625% Senior Secured Notes due 2028 2,000 2,000 4.875% Convertible Unsecured Notes due 2021 (1) — 476 4.25% Convertible Senior Notes due 2045 (2) 625 625 Cheniere Revolving Credit Facility — — Cheniere Term Loan Facility — 148 Total debt 2,625 3,249 Current portion of long-term debt — (104) Unamortized discount and debt issuance costs, net (340) (355) Total long-term debt, net of discount and debt issuance costs $ 2,285 $ 2,790 (1) A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt. (2) The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 4.25% Convertible Senior Notes due 2045 were classified as long-term debt as of December 31, 2021. Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2021 (in millions): Years Ending December 31, Principal Payments 2022 (1) $ 625 2023 — 2024 — 2025 — 2026 — Thereafter 2,000 Total $ 2,625 (1) Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. NOTE 3—GUARANTEES Cheniere has various financial and performance guarantees and indemnifications which are issued in the normal course of business. These contracts include performance guarantees and stand-by letters of credit. Cheniere enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. As of December 31, 2021, outstanding guarantees and other assurances aggregated approximately $472 million of varying duration, consisting of parental guarantees. No liabilities were recognized under these guarantee arrangements as of December 31, 2021. NOTE 4—LEASES Our leased assets consist primarily of office space and facilities, which are classified as operating leases. The following table shows the classification and location of our right-of-use assets and lease liabilities on our Condensed Balance Sheets (in millions): December 31, Condensed Balance Sheet Location 2021 2020 Right-of-use assets—Operating Operating lease assets $ 19 $ 22 Total right-of-use assets $ 19 $ 22 Current operating lease liabilities Current operating lease liabilities $ 6 $ 5 Non-current operating lease liabilities Operating lease liabilities 24 30 Total lease liabilities $ 30 $ 35 The following table shows the classification and location of our lease cost on our Condensed Statements of Operations (in millions): Year Ended December 31, Condensed Statements of Operations Location 2021 2020 Operating lease cost (1) General and administrative expense $ 9 $ 10 (1) Includes $4 million of variable lease costs paid to the lessor during each of the years ended December 31, 2021 and 2020. Future annual minimum lease payments for operating leases as of December 31, 2021 are as follows (in millions): Years Ending December 31, Operating Leases (1) 2022 $ 8 2023 8 2024 7 2025 6 2026 6 Thereafter 1 Total lease payments 36 Less: Interest (6) Present value of lease liabilities $ 30 The following table shows the weighted-average remaining lease term (in years) and the weighted-average discount rate for our operating leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) 4.8 5.7 Weighted-average discount rate 6.6% 6.6% The following table includes other quantitative information for our operating leases (in millions): Year Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 7 $ 7 Right-of-use assets obtained in exchange for new operating lease liabilities — 5 NOTE 5—STOCKHOLDERS’ EQUITY On June 3, 2019, we announced that our Board authorized a three three Year Ended December 31, 2021 2020 2019 Aggregate common stock repurchased 0.1 2.9 4.0 Weighted average price paid per share $ 87.32 $ 53.88 $ 62.27 Total amount paid (in millions) $ 9 $ 155 $ 249 As of December 31, 2021, we had up to $998 million of the share repurchase program available. Dividends During the year ended December 31, 2021, we declared and paid an inaugural quarterly dividend of $0.33 per common share. On January 25, 2022, we declared a quarterly dividend of $0.33 per common share that is payable on February 28, 2022 to shareholders of record as of February 7, 2022. NOTE 6 —SUPPLEMENTAL CASH FLOW INFORMATION The following table provides supplemental disclosure of cash flow information (in millions): Year Ended December 31, 2021 2020 2019 Cash paid during the period for interest, net of amounts capitalized $ 130 $ 45 $ 36 Non-cash investing and financing activities: Non-cash capital distributions (1) — 79 490 (1) Amounts represent undistributed equity income of affiliates.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
Schedule II - Valuation and Qualifying Accounts	Dec. 31, 2021
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	Balance at beginning of period Charged to costs and expenses Charged to other accounts Deductions Balance at end of period Year Ended December 31, 2021 Current expected credit losses on receivables and contract assets $ 7 $ 2 $ — $ — $ 9 Deferred tax asset valuation allowance 190 (127) — — 63 Year Ended December 31, 2020 Current expected credit losses on receivables and contract assets $ — $ 7 $ — $ — $ 7 Deferred tax asset valuation allowance 196 (6) — — 190 Year Ended December 31, 2019 Allowance for credit losses or doubtful accounts on receivables and contract assets $ 30 $ 16 $ — $ (46) $ — Deferred tax asset valuation allowance 686 (490) — — 196

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
Summary of Significant Accounting Policies (Policies)	Dec. 31, 2021
Accounting Policies [Abstract]
Basis of Presentation, Policy	Basis of Presentation Our Consolidated Financial Statements have been prepared in accordance with GAAP. The Consolidated Financial Statements include the accounts of Cheniere, its subsidiaries and affiliates in which we hold a controlling interest, reflecting ownership of a majority of the voting interest, as of the financial statement date. Additionally, we consolidate a VIE under certain criteria discussed further below. All intercompany accounts and transactions have been eliminated in consolidation. When necessary, reclassifications that are not material to our Consolidated Financial Statements are made to prior period financial information to conform to the current year presentation. VIEs We make a determination at the inception of each arrangement whether an entity in which we have made an investment or in which we have other variable interests is considered a VIE. Generally, an entity is a VIE if either (1) the entity does not have sufficient equity at risk to finance its activities without additional subordinated financial support from other parties, (2) the entity’s investors lack any characteristics of a controlling financial interest or (3) which was established with non-substantive voting. We consolidate VIEs when we are deemed to be the primary beneficiary. The primary beneficiary of a VIE is generally the party that both: (1) has the power to make decisions that most significantly affect the economic performance of the VIE and (2) has the obligation to absorb losses or the right to receive benefits that in either case could potentially be significant to the VIE. If we are not deemed to be the primary beneficiary of a VIE, we account for the investment or other variable interests in a VIE in accordance with applicable GAAP. Non-controlling Interests When we consolidate an entity, we include 100% of the assets, liabilities, revenues and expenses of the subsidiary in our Consolidated Financial Statements. For those entities that we consolidate in which our ownership is less than 100%, we record a non-controlling interest as a component of equity on our Consolidated Balance Sheets, which represents the third party ownership in the net assets of the respective consolidated subsidiary. Additionally, the portion of the net income or loss attributable to the non-controlling interest is reported as net income (loss) attributable to non-controlling interest on our Consolidated Statements of Operations. Changes in our ownership interests in an entity that do not result in deconsolidation are generally recognized within equity. See Note 9—Non-controlling Interest and Variable Interest Entities for additional details about our non-controlling interest. Equity Method Investments Investments in non-controlled entities, which Cheniere has the ability to exercise significant influence over operating and financial policies are accounted for using the equity method of accounting, with our share of earnings or losses reported in other income (expense) on our Consolidated Statements of Operations. In applying the equity method of accounting, the investments are initially recognized at cost, and subsequently adjusted for our proportionate share of earnings, losses and distributions. Investments accounted for using the equity method of accounting are reported as a component of other noncurrent assets. See Note 8 — Other Non-Current Assets , N et
Use of Estimates, Policy	Use of 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. Management evaluates its estimates and related assumptions regularly, including those related to fair value measurements of derivatives and other instruments, useful lives of property, plant and equipment, certain valuations including leases and asset retirement obligations (“AROs”) and recoverability of deferred tax assets, each as further discussed under the respective sections within this note. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates.
Fair Value Measurements, Policy	Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation approaches used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs that are directly or indirectly observable for the asset or liability, other than quoted prices included within Level 1. Hierarchy Level 3 inputs are inputs that are not observable in the market. In determining fair value, we use observable market data when available, or models that incorporate observable market data. In addition to market information, we incorporate transaction-specific details that, in management’s judgment, market participants would take into account in measuring fair value. We maximize the use of observable inputs and minimize our use of unobservable inputs in arriving at fair value estimates. Recurring fair-value measurements are performed for derivative instruments, as disclosed in Note 7—Derivative Instruments , and liability-classified share-based compensation awards, as disclosed in Note 16 — S hare-Ba sed Compen s ation . The carrying amount of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable reported on the Consolidated Balance Sheets approximates fair value. The fair value of debt is the estimated amount we would have to pay to repurchase our debt in the open market, including any premium or discount attributable to the difference between the stated interest rate and market interest rate at each balance sheet date. Debt fair values, as disclosed in Note 11—Debt
Revenue Recognition, Policy	Revenue Recognition We recognize revenues when we transfer control of promised goods or services to our customers in an amount that reflects the consideration to which we expect to be entitled to in exchange for those goods or services. See Note 13—Revenues from Contracts with Customers for further discussion of our revenue streams and accounting policies related to revenue recognition.
Cash and Cash Equivalents, Policy	Cash and Cash Equivalents We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Restricted Cash and Cash Equivalents, Policy	Restricted Cash and Cash Equivalents Restricted cash and cash equivalents consist 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.
Accounts and Notes Receivables, Policy	Accounts and Other Receivables Accounts and other receivables are reported net of any current expected credit losses. Current expected credit losses consider the risk of loss based on past events, current conditions and reasonable and supportable forecasts. A counterparty’s ability to pay is assessed through a credit review process that considers payment terms, the counterparty’s established credit rating or our assessment of the counterparty’s credit worthiness, contract terms, payment status, and other risks or available financial assurances. Adjustments to current expected credit losses are recorded in selling, general and administrative expense in our Consolidated Statements of Operations. As of both December 31, 2021 and 2020, we had current expected credit losses on our accounts and other receivables of $5 million.
Inventory, Policy	InventoryLNG and natural gas inventory are recorded at the lower of weighted average cost and net realizable value. Materials and other inventory are recorded at the lower of cost and net realizable value. Inventory is charged to expense when sold, or, for certain qualifying costs, capitalized to property, plant and equipment when issued, primarily using the weighted average method.
Property, Plant and Equipment, Policy	Property, Plant and Equipment Property, plant and equipment are recorded at cost. Expenditures for construction and commissioning activities, major renewals and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs (including those for planned major maintenance projects) to maintain property, plant and equipment in operating condition are generally expensed as incurred. Generally, we begin capitalizing the costs of our LNG terminals once the individual project meets the following criteria: (1) regulatory approval has been received, (2) financing for the project is available and (3) management has committed to commence construction. Prior to meeting these criteria, most of the costs associated with a project are expensed as incurred. These costs primarily include professional fees associated with preliminary front-end engineering and design work, costs of securing necessary regulatory approvals and other preliminary investigation and development activities related to our LNG terminals. Generally, costs that are capitalized prior to a project meeting the criteria otherwise necessary for capitalization include: land acquisition costs, detailed engineering design work and certain permits that are capitalized as other non-current assets. We realize offsets to LNG terminal costs for sales of commissioning cargoes that were earned or loaded prior to the start of commercial operations of the respective Train during the testing phase for its construction. We depreciate our property, plant and equipment using the straight-line depreciation method over assigned useful lives. Refer to Note 6 — Prope rty, Plant and Equipment, N et of Accumulated Depreciation for additional discussion of our useful lives by asset category. Upon retirement or other disposition of property, plant and equipment, the cost and related accumulated depreciation are removed from the account, and the resulting gains or losses are recorded in impairment expense and loss (gain) on disposal of assets. Management tests property, plant and equipment for impairment whenever events or changes in circumstances have indicated that the carrying amount of property, plant and equipment might not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets for purposes of assessing recoverability. Recoverability generally is determined by comparing the carrying value of the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value.
Interest Capitalization, Policy	Interest Capitalization We capitalize interest costs during the construction period of our LNG terminals and related assets as construction-in-process. Upon commencement of operations, these costs are transferred out of construction-in-process into terminal and interconnecting pipeline facilities assets and are amortized over the estimated useful life of the asset.
Regulated Natural Gas Pipelines, Policy	Regulated Natural Gas Pipelines The Creole Trail Pipeline and Corpus Christi Pipeline are subject to the jurisdiction of the FERC in accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of 1978. The economic effects of regulation can result in a regulated company recording as assets those costs that have been or are expected to be approved for recovery from customers, or recording as liabilities those amounts that are expected to be required to be returned to customers, in a rate-setting process in a period different from the period in which the amounts would be recorded by an unregulated enterprise. Accordingly, we record assets and liabilities that result from the regulated rate-making process that may not be recorded under GAAP for non-regulated entities. We continually assess whether regulatory assets are probable of future recovery by considering factors such as applicable regulatory changes and recent rate orders applicable to other regulated entities. Based on this continual assessment, we believe the existing regulatory assets are probable of recovery. These regulatory assets and liabilities are primarily classified in our Consolidated Balance Sheets as other assets and other liabilities. We periodically evaluate their applicability under GAAP and consider factors such as regulatory changes and the effect of competition. If cost-based regulation ends or competition increases, we may have to write off the associated regulatory assets and liabilities. Items that may influence our assessment are: • inability to recover cost increases due to rate caps and rate case moratoriums; • inability to recover capitalized costs, including an adequate return on those costs through the rate-making process and the FERC proceedings; • excess capacity; • increased competition and discounting in the markets we serve; and • impacts of ongoing regulatory initiatives in the natural gas industry. Natural gas pipeline costs include amounts capitalized as an Allowance for Funds Used During Construction (“AFUDC”). The rates used in the calculation of AFUDC are determined in accordance with guidelines established by the FERC. AFUDC represents the cost of debt and equity funds used to finance our natural gas pipeline additions during construction. AFUDC is capitalized as a part of the cost of our natural gas pipelines. Under regulatory rate practices, we generally are permitted to recover AFUDC, and a fair return thereon, through our rate base after our natural gas pipelines are placed in service.
Derivative Instruments, Policy	Derivative Instruments We use derivative instruments to hedge our exposure to cash flow variability from interest rate, commodity price and foreign currency exchange (“FX”) rate risk. Derivative instruments are recorded at fair value and included in our Consolidated Balance Sheets as assets or liabilities depending on the derivative position and the expected timing of settlement, unless they satisfy criteria for, and we elect, the normal purchases and sales exception, under which we account for the instrument under the accrual method of accounting, whereby revenues and expenses are recognized only upon delivery, receipt or realization of the underlying transaction. When we have the contractual right and intent to net settle, derivative assets and liabilities are reported on a net basis. Changes in the fair value of our derivative instruments are recorded in earnings, unless we elect to apply hedge accounting and meet specified criteria. We did not have any derivative instruments designated as cash flow or fair value hedges during the years ended December 31, 2021, 2020 and 2019. See Note 7—Derivative Instruments for additional details about our derivative instruments.
Leases, Policy	Leases We determine if an arrangement is, or contains, a lease at inception of the arrangement. When we determine the arrangement is, or contains, a lease, we classify the lease as either an operating lease or a finance lease. Operating and finance leases are recognized on our Consolidated Balance Sheets by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. Operating and finance lease right-of-use assets and liabilities are generally recognized based on the present value of minimum lease payments over the lease term. In determining the present value of minimum lease payments, we use the implicit interest rate in the lease if readily determinable. In the absence of a readily determinable implicitly interest rate, we discount our expected future lease payments using our relevant subsidiary’s incremental borrowing rate. The incremental borrowing rate is an estimate of the interest rate that a given subsidiary would have to pay to borrow on a collateralized basis over a similar term to that of the lease term. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability, only to the extent they are reasonably certain to be exercised. We have elected practical expedients to (1) omit leases with an initial term of 12 months or less from recognition on our balance sheet and (2) to combine both the lease and non-lease components of an arrangement in calculating the right-of-use asset and lease liability for all classes of leased assets. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Lease expense for finance leases is recognized as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities using the effective interest method over the lease term. Certain of our leases also contain variable payments, such as inflation, that are included in the right-of-use asset and lease liability only when the contract terms require the payment of a fixed amount that is unavoidable. See Note 12—Leases for additional details about our leases.
Concentration of Credit Risk, Policy	Concentration of Credit Risk Financial instruments that potentially subject us to a concentration of credit risk consist principally of derivative instruments and accounts receivable related to our long-term SPAs and regasification contracts, each discussed further below. Additionally, we maintain cash balances at financial institutions, which may at times be in excess of federally insured levels. We have not incurred credit losses related to these cash balances to date. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments. Certain of our commodity derivative transactions are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. Collateral deposited for such contracts is recorded within other current assets. Our interest rate and FX derivative instruments are placed with investment grade financial institutions whom we believe are acceptable credit risks. We monitor counterparty creditworthiness on an ongoing basis; however, we cannot predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk. Should one of these counterparties not perform, we may not realize the benefit of some of our derivative instruments. We have contracted our anticipated production capacity under SPAs and under IPM agreements. 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 agreements had approximately 17 years of weighted average remaining life as of December 31, 2021. We market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. We are dependent on the respective customers’ creditworthiness and their willingness to perform under their respective agreements. SPLNG has entered into two long-term TUAs with third parties for regasification capacity at the Sabine Pass LNG Terminal. SPLNG is dependent on the respective customers’ creditworthiness and their willingness to perform under their respective TUAs. SPLNG has mitigated this credit risk by securing TUAs for a significant portion of its regasification capacity with creditworthy third party customers with a minimum Standard & Poor’s rating of A. See Note 21—Customer Concentration for additional details about our customer concentration. Our arrangements with our customers incorporate certain provisions to mitigate our exposure to credit losses and include, under certain circumstances, customer collateral, netting of exposures through the use of industry standard commercial agreements and margin deposits with certain counterparties in the over-the-counter derivative market, with such margin deposits primarily facilitated by independent system operators and by clearing brokers. Payments on margin deposits, either by us or by the counterparty depending on the position, are required when the value of a derivative exceeds our pre-established credit limit with the counterparty. Margin deposits are returned to us (or to the counterparty) on or near the settlement date for non-exchange traded derivatives, and we exchange margin calls on a daily basis for exchange traded transactions.
Goodwill, Policy	Goodwill Goodwill is the excess of acquisition cost of a business over the estimated fair value of net assets acquired. Goodwill is not amortized however we test goodwill for impairment at least annually as of October 1st, or more frequently if events or circumstances indicate goodwill is more likely than not impaired. When evaluating goodwill for impairment, we may either perform a qualitative assessment or a quantitative test. The qualitative assessment is an assessment of historical information and relevant events and circumstances to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount, including goodwill. If it is concluded that it is more-likely-than not that an impairment exists, a quantitative test is required which compares the estimated fair value of a reporting unit to its carrying value and measures any goodwill impairment as the amount by which the carrying amount of the reporting unit exceeds its fair value. We may elect not to perform the qualitative assessment and instead perform a quantitative impairment test. We completed our annual assessment of goodwill impairment in the current year by performing a qualitative assessment; which indicated it was not more likely than not that there was an impairment and therefore no quantitative test was required. Significant judgments and assumptions are inherent in our estimate of future cash flows used to determine the estimate of the reporting unit’s fair value. Factors that could trigger a lower fair value estimate include significant negative industry or economic trends, cost increases, disruptions to our business, regulatory or political environment changes or other unanticipated events.
Debt, Policy	Debt Our debt consists of current and long-term secured and unsecured debt securities, convertible debt securities and credit facilities with banks and other lenders. Debt issuances are placed directly by us or through securities dealers or underwriters and are held by institutional and retail investors. Debt is recorded on our Consolidated Balance Sheets at par value adjusted for unamortized discount or premium and net of unamortized debt issuance costs related to term notes. Debt issuance costs consist primarily of arrangement fees, professional fees, legal fees and printing costs. If debt issuance costs are incurred in connection with a line of credit arrangement or on undrawn funds, the debt issuance costs are presented as an asset on our Consolidated Balance Sheets. Discounts, premiums and debt issuance costs directly related to the issuance of debt are amortized over the life of the debt and are recorded in interest expense, net of capitalized interest using the effective interest method. Gains and losses on the extinguishment or modification of debt are recorded in loss on modification or extinguishment of debt on our Consolidated Statements of Operations. We classify debt on our Consolidated Balance Sheets based on contractual maturity, with the following exceptions: • We classify term debt that is contractually due within one year as long-term debt if management has the intent and ability to refinance the current portion of such debt with future cash proceeds from an executed long-term debt agreement. • We evaluate the classification of long-term debt extinguished after the balance sheet date but before the financial statements are issued based on facts and circumstances existing as of the balance sheet date.
Asset Retirement Obligations, Policy	Asset Retirement Obligations We recognize AROs for legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset and for conditional AROs in which the timing or method of settlement are conditional on a future event that may or may not be within our control. The fair value of a liability for an ARO is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The fair value of the liability is added to the carrying amount of the associated asset. This additional carrying amount is depreciated over the estimated useful life of the asset. We have not recorded an ARO associated with the Sabine Pass LNG Terminal. Based on the real property lease agreements at the Sabine Pass LNG Terminal, at the expiration of the term of the leases we are required to surrender the LNG terminal in good working order and repair, with normal wear and tear and casualty expected. Our property lease agreements at the Sabine Pass LNG Terminal have terms of up to 90 years including renewal options. We have determined that the cost to surrender the Sabine Pass LNG Terminal in good order and repair, with normal wear and tear and casualty expected, is immaterial. We have not recorded an ARO associated with the Creole Trail Pipeline or the Corpus Christi Pipeline. We believe that it is not feasible to predict when the natural gas transportation services provided by the Creole Trail Pipeline or the Corpus Christi Pipeline will no longer be utilized. In addition, our right-of-way agreements associated with the Creole Trail Pipeline and the Corpus Christi Pipeline have no stipulated termination dates. We intend to operate the Creole Trail Pipeline and the Corpus Christi Pipeline as long as supply and demand for natural gas exists in the United States and intend to maintain it regularly.
Share-based Compensation, Policy	Share-based Compensation We have awarded share-based compensation in the form of stock (immediately vested), restricted stock shares, restricted stock units, performance stock units and phantom units. The awards and our related accounting policies are more fully described in Note 16—Share-based Compensation
Income Taxes, Policy	Income Taxes Provisions for income taxes are based on taxes payable or refundable for the current year and deferred taxes on temporary differences between the tax basis of assets and liabilities and their reported amounts in our Consolidated Financial Statements. Deferred tax assets and liabilities are included in our Consolidated Financial Statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the current period’s provision for income taxes. A valuation allowance is recorded to reduce the carrying value of our deferred tax assets when it is more likely than not that a portion or all of the deferred tax assets will expire before realization of the benefit or future deductibility is not probable.
Net Income (Loss) Per Share, Policy	Net Income (Loss) Per Share 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 treasury or if-converted method. Refer to Note 18— Net Income (Loss) per Sh are A ttributable to Common Stockholders
Business Segment, Policy	Business SegmentWe have determined that we operate as a single operating and reportable segment. Substantially all of our long-lived assets are located in the United States. Our chief operating decision maker makes resource allocation decisions and assesses performance based on financial information presented on a consolidated basis in the delivery of an integrated source of LNG to our customers.
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. In December 2021, we issued a notice of redemption for all $625 million aggregate principal amount outstanding of 2045 Cheniere Convertible Senior Notes, which were redeemed on January 5, 2022. We continue to evaluate the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures. See Note 11—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. The transition period under this standard is effective March 12, 2020 and will apply through December 31, 2022. We have various credit facilities and interest rate swaps indexed to LIBOR, as further described in Note 7—Derivative Instruments and Note 11—Debt . To date, we have amended certain of our credit facilities to incorporate a fallback replacement rate indexed to SOFR as a result of the expected LIBOR transition. We elected to apply the optional expedients as applicable to certain modified terms, however the impact of applying the optional expedients has not been material thus far. We will continue to elect to apply the optional expedients to qualifying contract modifications in the future.

Restricted Cash and Cash Equi_2

Restricted Cash and Cash Equivalents (Tables)	12 Months Ended
Restricted Cash and Cash Equivalents (Tables)	Dec. 31, 2021
Restricted Cash and Cash Equivalents [Abstract]
Schedule of Restricted Cash and Cash Equivalents	As of December 31, 2021 and 2020, restricted cash and cash equivalents consisted of the following (in millions): December 31, 2021 2020 Restricted cash and cash equivalents SPL Project $ 98 $ 97 CCL Project 44 70 Cash held by our subsidiaries that is restricted to Cheniere 271 282 Total restricted cash and cash equivalents $ 413 $ 449

Accounts and Other Receivable_2

Accounts and Other Receivables, Net of Current Expected Credit Losses (Tables)	12 Months Ended
	Dec. 31, 2021
Receivables [Abstract]
Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses	As of December 31, 2021 and 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions): December 31, 2021 2020 Trade receivables SPL and CCL $ 802 $ 482 Cheniere Marketing 640 113 Other accounts receivable 64 52 Total accounts and other receivables, net of current expected credit losses $ 1,506 $ 647

Inventory (Tables)

Inventory (Tables)	12 Months Ended
Inventory (Tables)	Dec. 31, 2021
Inventory Disclosure [Abstract]
Schedule of Inventory	As of December 31, 2021 and 2020, inventory consisted of the following (in millions): December 31, 2021 2020 Materials $ 174 $ 150 LNG in-transit 312 88 LNG 153 27 Natural gas 64 26 Other 3 1 Total inventory $ 706 $ 292

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	As of December 31, 2021 and 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): December 31, 2021 2020 LNG terminal LNG terminal and interconnecting pipeline facilities $ 30,660 $ 27,475 LNG site and related costs 441 324 LNG terminal construction-in-process 2,995 5,378 Accumulated depreciation (3,912) (2,935) Total LNG terminal, net of accumulated depreciation 30,184 30,242 Fixed assets and other Computer and office equipment 25 25 Furniture and fixtures 20 19 Computer software 120 117 Leasehold improvements 45 45 Land 1 59 Other 19 25 Accumulated depreciation (176) (164) Total fixed assets and other, net of accumulated depreciation 54 126 Assets under finance lease Tug vessels 60 60 Accumulated depreciation (10) (7) Total assets under finance lease, net of accumulated depreciation 50 53 Property, plant and equipment, net of accumulated depreciation $ 30,288 $ 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 years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 Depreciation expense $ 1,006 $ 926 $ 788 Offsets to LNG terminal costs (1) 319 19 301
Property Plant and Equipment Estimated Useful Lives Table	Our LNG terminals are depreciated using the straight-line depreciation method applied to groups of LNG terminal assets with varying useful lives. The identifiable components of our LNG terminals have depreciable lives between 6 and 50 years, as follows: Components Useful life (years) LNG storage tanks 50 Natural gas pipeline facilities 40 Marine berth, electrical, facility and roads 35 Water pipelines 30 Regasification processing equipment 30 Sendout pumps 20 Liquefaction processing equipment 6-50 Other 10-30

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
Derivative Instruments (Tables)	Dec. 31, 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 December 31, 2021 and 2020 (in millions): Fair Value Measurements as of December 31, 2021 December 31, 2020 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total CCH Interest Rate Derivatives liability $ — $ (40) $ — $ (40) $ — $ (140) $ — $ (140) Liquefaction Supply Derivatives asset (liability) 7 (9) (4,036) (4,038) 5 (6) 241 240 LNG Trading Derivatives liability (22) (378) — (400) (3) (131) — (134) FX Derivatives asset (liability) — 12 — 12 — (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 as of December 31, 2021: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(4,036) Market approach incorporating present value techniques Henry Hub basis spread $(1.368) - $0.628 / $(0.016) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 185% - 662% / 248% (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 years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 Balance, beginning of period $ 241 $ 138 $ (29) Realized and mark-to-market gains (losses): Included in cost of sales (4,305) 156 (77) Purchases and settlements: Purchases (1) 5 199 Settlements 29 (65) 44 Transfers into Level 3, net (1) — 7 1 Balance, end of period $ (4,036) $ 241 $ 138 Change in unrealized gain (loss) relating to instruments still held at end of period $ (4,305) $ 156 $ (77) (1) Transferred into Level 3 as a result of unobservable market, or out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.
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): December 31, 2021 CCH Interest Rate Derivatives Liquefaction Supply Derivatives (1) LNG Trading Derivatives (2) FX Derivatives Total Consolidated Balance Sheets Location Current derivative assets $ — $ 38 $ 2 $ 15 $ 55 Derivative assets — 69 — — 69 Total derivative assets — 107 2 15 124 Current derivative liabilities (40) (644) (402) (3) (1,089) Derivative liabilities — (3,501) — — (3,501) Total derivative liabilities (40) (4,145) (402) (3) (4,590) Derivative asset (liability), net $ (40) $ (4,038) $ (400) $ 12 $ (4,466) 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 $20 million and $9 million as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets. Includes derivative assets for natural gas supply contracts that SPL and CCL had with related parties as of December 31, 2020. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions . (2) Does not include collateral posted with counterparties by us of $745 million and $16 million, as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets.
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 December 31, 2021 Gross assets $ — $ 155 $ 10 $ 48 Offsetting amounts — (48) (8) (33) Net assets $ — $ 107 $ 2 $ 15 Gross liabilities $ (40) $ (4,382) $ (551) $ (10) Offsetting amounts — 237 149 7 Net liabilities $ (40) $ (4,145) $ (402) $ (3) 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 December 31, 2021, we had the following Interest Rate Derivatives outstanding: Notional Amounts December 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Year Ended December 31, 2021 2020 2019 CCH Interest Rate Derivatives Interest rate derivative loss, net $ (1) $ (138) $ (101) CCH Interest Rate Forward Start Derivatives Interest rate derivative loss, net — (95) (33)
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”): December 31, 2021 December 31, 2020 Liquefaction Supply Derivatives LNG Trading Derivatives Liquefaction Supply Derivatives LNG Trading Derivatives Notional amount, net (in TBtu) (1) 11,238 33 10,483 20 (1) The balances as of December 31, 2020 include notional amounts for natural gas supply contracts that SPL and CCL have with related parties. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—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 years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Year Ended December 31, 2021 2020 2019 LNG Trading Derivatives LNG revenues $ (1,812) $ (26) $ 402 LNG Trading Derivatives Cost of sales 91 (42) (89) Liquefaction Supply Derivatives (2) LNG revenues 3 (1) 2 Liquefaction Supply Derivatives (2) Cost of sales (4,303) 94 194 (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 years ended December 31, 2021, 2020 and 2019 (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Year Ended December 31, 2021 2020 2019 FX Derivatives LNG revenues $ 33 $ (3) $ 25

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	12 Months Ended
Other Non-Current Assets (Tables)	Dec. 31, 2021
Other Assets, Noncurrent [Abstract]
Schedule of Other Non-Current Assets	As of December 31, 2021 and 2020, other non-current assets, net consisted of the following (in millions): December 31, 2021 2020 Contract assets, net of current expected credit losses $ 135 $ 80 Advances made to municipalities for water system enhancements 81 84 Equity method investments 56 81 Advances and other asset conveyances to third parties to support LNG terminals 80 60 Debt issuance costs and debt discount, net of accumulated amortization 34 42 Advances made under EPC and non-EPC contracts 5 9 Advance tax-related payments and receivables 17 20 Other 54 30 Total other non-current assets, net $ 462 $ 406

Non-Controlling Interest and _2

Non-Controlling Interest and Variable Interest Entity (Tables)	12 Months Ended
	Dec. 31, 2021
CQP [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 CQP, our consolidated VIE, which are included in our Consolidated Balance Sheets as of December 31, 2021 and 2020. The assets in the table below may only be used to settle obligations of CQP. 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 CQP only and exclude intercompany balances that eliminate in consolidation. December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 876 $ 1,210 Restricted cash and cash equivalents 98 97 Accounts and other receivables, net of current expected credit losses 580 318 Other current assets 285 182 Total current assets 1,839 1,807 Property, plant and equipment, net of accumulated depreciation 16,830 16,723 Other non-current assets, net 316 287 Total assets $ 18,985 $ 18,817 LIABILITIES Current liabilities Accrued liabilities $ 1,077 $ 662 Other current liabilities 200 167 Total current liabilities 1,277 829 Long-term debt, net of premium, discount and debt issuance costs 17,177 17,580 Other non-current liabilities 100 126 Total liabilities $ 18,554 $ 18,535

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	12 Months Ended
Accrued Liabilities (Tables)	Dec. 31, 2021
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of December 31, 2021 and 2020, accrued liabilities consisted of the following (in millions): December 31, 2021 2020 Accrued natural gas purchases $ 1,323 $ 576 Accrued derivative settlements 329 — Interest costs and related debt fees 214 245 LNG terminals and related pipeline costs 144 147 Compensation and benefits 180 123 Accrued LNG inventory 34 4 Other accrued liabilities 75 80 Total accrued liabilities $ 2,299 $ 1,175

Debt (Tables)

Debt (Tables)	12 Months Ended
Debt (Tables)	Dec. 31, 2021
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of December 31, 2021 and 2020, our debt consisted of the following (in millions): December 31, 2021 2020 SPL: Senior Secured Notes: 6.25% due 2022 $ — $ 1,000 5.625% due 2023 1,500 1,500 5.75% due 2024 2,000 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.27% weighted average rate due 2037 1,282 800 Total SPL Senior Secured Notes 13,132 13,650 $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”) — — Total debt - SPL 13,132 13,650 CQP: Senior Notes: 5.250% due 2025 — 1,500 5.625% due 2026 — 1,100 4.500% due 2029 1,500 1,500 4.000% due 2031 1,500 — 3.25% due 2032 1,200 — Total CQP Senior Notes 4,200 4,100 CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”) — — Total debt - CQP 4,200 4,100 CCH: Senior Secured Notes: 7.000% due 2024 1,250 1,250 5.875% due 2025 1,500 1,500 5.125% due 2027 1,500 1,500 3.700% due 2029 1,500 1,500 3.72% weighted average rate due 2039 2,721 1,971 Total CCH Senior Secured Notes 8,471 7,721 CCH Credit Facility (1) 1,728 2,627 $1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) (2) 250 140 Total debt - CCH 10,449 10,488 Cheniere: 4.625% Senior Secured Notes due 2028 (“Cheniere Senior Secured Notes”) 2,000 2,000 4.875% Convertible Unsecured Notes due 2021 (“2021 Cheniere Convertible Unsecured Notes”) (1) — 476 2045 Cheniere Convertible Senior Notes (3) 625 625 $1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”) — — Cheniere’s term loan facility (“Cheniere Term Loan Facility”) — 148 Total debt - Cheniere 2,625 3,249 Cheniere Marketing: trade finance facilities and letter of credit facility (2) — — Total debt 30,406 31,487 Current portion of long-term debt (117) (232) Short-term debt (250) (140) Unamortized premium, discount and debt issuance costs, net (590) (644) Total long-term debt, net of premium, discount and debt issuance costs $ 29,449 $ 30,471 (1) A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt. (2) These debt instruments are classified as short-term debt. (3) The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption.
Schedule of Maturities of Long-term Debt	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2021 (in millions): Years Ending December 31, Principal Payments 2022 (1) $ 992 2023 1,567 2024 4,794 2025 3,537 2026 1,579 Thereafter 17,937 Total $ 30,406 (1) Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Consolidated Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. See Convertible Notes section below for further discussion of the redemption.
Schedule of Line of Credit Facilities and Delayed Draw Term Loan	Below is a summary of our committed credit facilities outstanding as of December 31, 2021 (in millions): 2020 SPL Working Capital Facility (1) 2019 CQP Credit Facilities (2) CCH Credit Facility (3) CCH Working Capital Facility (4) Cheniere Revolving Credit Facility (5) Original facility size $ 1,200 $ 1,500 $ 8,404 $ 350 $ 750 Incremental commitments — — 1,566 850 500 Less: Outstanding balance — — 1,729 250 — Commitments prepaid or terminated — 750 8,241 — — Letters of credit issued 395 — — 361 — Available commitment $ 805 $ 750 $ — $ 589 $ 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% (6) LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75% (6) LIBOR plus 1.250% - 2.375% or base rate plus 0.250% - 1.375% (6) Weighted average interest rate of outstanding balance n/a n/a 1.85% 3.50% n/a Commitment fees on undrawn balance 0.20% 0.49% n/a 0.50% 0.25% Maturity date March 19, 2025 May 29, 2024 June 30, 2024 June 29, 2023 October 28, 2026 (1) 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 Secured Notes. The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions (2) See CQP Senior Notes section above for discussion of the rights and privileges of the 2019 CQP Credit Facilities. (3) 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 of its limited liability company interests in CCH. (4) 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 Secured Notes and the CCH Credit Facility. (5) 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 (other than certain excluded subsidiaries). The Cheniere Revolving Credit Facility contains a financial covenant requiring us to maintain a non-consolidated leverage ratio not to exceed 5.50:1.00 as of the end of any fiscal quarter if (i) as of the last day of such fiscal quarter the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit is greater than 35% of the aggregate commitments under the Cheniere Revolving Credit Facility (a “Covenant Trigger Event”) or (ii) a Covenant Trigger Event had occurred and been continuing as of the last day of the immediately preceding fiscal quarter and as of the last day of such ending fiscal quarter such Covenant Trigger Event had not ceased for a period of at least thirty consecutive days. (6) These facilities were amended in 2021 to establish a SOFR-indexed replacement rate for LIBOR.
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): Year Ended December 31, 2021 2020 2019 Interest cost on convertible notes: Interest per contractual rate $ 36 $ 152 $ 256 Amortization of debt discount 10 45 40 Amortization of debt issuance costs — 8 12 Total interest cost related to convertible notes 46 205 308 Interest cost on debt and finance leases excluding convertible notes 1,558 1,568 1,538 Total interest cost 1,604 1,773 1,846 Capitalized interest (166) (248) (414) Total interest expense, net of capitalized interest $ 1,438 $ 1,525 $ 1,432
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): December 31, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 24,550 $ 26,725 $ 24,700 $ 27,897 Senior notes — Level 3 (2) 3,253 3,693 2,771 3,423 Credit facilities — Level 3 (3) 1,978 1,978 2,915 2,915 2021 Cheniere Convertible Unsecured Notes — Level 3 (2) — — 476 480 2045 Cheniere Convertible Senior Notes — Level 1 (4) 625 526 625 496 (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.

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 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): December 31, Consolidated Balance Sheets Location 2021 2020 Right-of-use assets—Operating Operating lease assets $ 2,102 $ 759 Right-of-use assets—Financing Property, plant and equipment, net of accumulated depreciation 50 53 Total right-of-use assets $ 2,152 $ 812 Current operating lease liabilities Current operating lease liabilities $ 535 $ 161 Current finance lease liabilities Other current liabilities 2 2 Non-current operating lease liabilities Operating lease liabilities 1,541 597 Non-current finance lease liabilities Finance lease liabilities 57 57 Total lease liabilities $ 2,135 $ 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 Year Ended December 31, 2021 2020 2019 Operating lease cost (a) Operating costs and expenses (1) $ 621 $ 432 $ 612 Finance lease cost: Amortization of right-of-use assets Depreciation and amortization expense 3 2 3 Interest on lease liabilities Interest expense, net of capitalized interest 9 7 10 Total lease cost $ 633 $ 441 $ 625 (a) Included in operating lease cost: Short-term lease costs $ 139 $ 93 $ 230 Variable lease costs 21 16 7
Schedule of Maturity of Lease Liabilities	Future annual minimum lease payments for operating and finance leases as of December 31, 2021 are as follows (in millions): Years Ending December 31, Operating Leases (1) Finance Leases 2022 $ 600 $ 11 2023 514 10 2024 456 10 2025 244 10 2026 218 10 Thereafter 294 117 Total lease payments 2,326 168 Less: Interest (250) (109) Present value of lease liabilities $ 2,076 $ 59 (1) Does not include approximately $1.2 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of December 31, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to 10 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: December 31, 2021 December 31, 2020 Operating Leases Finance Leases Operating Leases Finance Leases Weighted-average remaining lease term (in years) 5.6 16.7 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): Year Ended December 31, 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 483 $ 309 $ 389 Operating cash flows from finance leases 10 10 9 Right-of-use assets obtained in exchange for operating lease liabilities 1,736 615 235
Schedule of Sublease Income	The following table shows the sublease income recognized in other revenues on our Consolidated Statements of Operations (in millions): Year Ended December 31, 2021 2020 2019 Fixed income $ 72 $ 68 $ 122 Variable income 37 27 22 Total sublease income $ 109 $ 95 $ 144

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	12 Months Ended
Revenues from Contracts with Customers (Tables)	Dec. 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions): Year Ended December 31, 2021 2020 2019 LNG revenues (1) $ 17,171 $ 8,954 $ 8,817 Regasification revenues 269 269 266 Other revenues 91 70 74 Total revenues from customers 17,531 9,293 9,157 Net derivative gain (loss) (2) (1,776) (30) 429 Other (3) 109 95 144 Total revenues $ 15,864 $ 9,358 $ 9,730 (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 year ended December 31, 2020, we recognized $969 million in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $38 million would have been recognized during the year ended December 31, 2021 had the cargoes been 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 years ended December 31, 2021 and 2019. 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 7—Derivative Instruments for additional information about our derivatives. (3) Includes revenues from LNG vessel subcharters. See Note 12—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): December 31, 2021 2020 Contract assets, net of current expected credit losses $ 140 $ 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): Year Ended December 31, 2021 Deferred revenue, beginning of period $ 138 Cash received but not yet recognized in revenue 194 Revenue recognized from prior period deferral (138) Deferred revenue, end of period $ 194
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 December 31, 2021 and 2020: December 31, 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 $ 107.1 9 $ 102.3 10 Regasification revenues 1.9 4 2.1 5 Total revenues $ 109.0 $ 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.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2021
Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	The Liquefaction Supply Derivatives related to this agreement were recorded on our Consolidated Balance Sheets as follows (in millions, except notional amount): December 31, 2021 2020 Current derivative assets $ — $ 3 Derivative assets — 1 Notional amount (in TBtu) — 60 We recorded the following amounts on our Consolidated Statements of Operations during the years ended December 31, 2021, 2020 and 2019 related to these agreements (in millions): Year Ended December 31, 2021 2020 2019 Cost of sales (a) (1) $ 162 $ 114 $ 85 (a) Included in costs of sales: Liquefaction Supply Derivative gain (1) $ 13 $ (1) $ (1) (1) Includes amounts recorded related to natural gas supply contracts that SPL and CCL had with related parties. These agreements ceased to be considered related party agreements during 2021, as discussed above.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Income before Income Tax, Domestic and Foreign	The jurisdictional components of income before income taxes and non-controlling interest on our Consolidated Statements of Operations for the years ended December 31, 2021, 2020 and 2019 are as follows (in millions): Year Ended December 31, 2021 2020 2019 U.S. $ (2,317) $ 720 $ 289 International 39 (176) 426 Total income (loss) before income taxes and non-controlling interest $ (2,278) $ 544 $ 715
Schedule of Components of Income Tax Expense (Benefit)	Income tax provision (benefit) included in our reported net income consisted of the following (in millions): Year Ended December 31, 2021 2020 2019 Current: Federal $ — $ — $ — State 3 — — Foreign 5 — 4 Total current 8 — 4 Deferred: Federal (633) 41 (475) State (89) 2 (46) Foreign 1 — — Total deferred (721) 43 (521) Total income tax provision (benefit) $ (713) $ 43 $ (517)
Schedule of Effective Income Tax Rate Reconciliation	Our income tax rates do not bear a customary relationship to statutory income tax rates. A reconciliation of the federal statutory income tax rate of 21% to our effective income tax rate is as follows: Year Ended December 31, 2021 2020 2019 U.S. federal statutory tax rate 21.0 % 21.0 % 21.0 % Non-controlling interest 7.2 (22.6) (17.2) State tax, net of federal benefit (2.5) — (5.4) Executive compensation (0.5) 1.4 1.3 Nondeductible interest expense — 8.0 5.0 Foreign earnings taxed in the U.S. — 1.2 6.7 Foreign rate differential (0.1) (3.7) (11.4) Tax credits 0.6 (4.5) (5.2) Internal restructuring — 7.0 — Other — 1.0 1.4 Valuation allowance 5.6 (0.9) (68.5) Effective tax rate as reported 31.3 % 7.9 % (72.3) %
Schedule of Deferred Tax Assets and Liabilities	Significant components of our deferred tax assets and liabilities at December 31, 2021 and 2020 are as follows (in millions): December 31, 2021 2020 Deferred tax assets Net operating loss carryforwards and credits Federal $ 3,231 $ 3,084 Foreign 2 3 State 244 257 Federal and state tax credits 108 95 Derivative instruments 951 7 Other 584 283 Less: valuation allowance (63) (190) Total deferred tax assets 5,057 3,539 Deferred tax liabilities Investment in partnerships (716) (765) Property, plant and equipment (2,638) (2,089) Other (499) (196) Total deferred tax liabilities (3,853) (3,050) Net deferred tax assets $ 1,204 $ 489
Summary of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amounts of our unrecognized tax benefits for the years ended December 31, 2021 and 2020, is as follows (in millions): Year Ended December 31, 2021 2020 Balance at beginning of the year $ 62 $ 61 Additions based on tax positions related to current year 3 1 Additions for tax positions of prior years — — Reductions for tax positions of prior years — — Settlements — — U.S. tax reform rate change — — Balance at end of the year $ 65 $ 62

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
Share-Based Compensation (Tables)	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Schedule of Share-based Compensation Expense, Net	Total share-based compensation consisted of the following (in millions): Year Ended December 31, 2021 2020 2019 Share-based compensation costs, pre-tax: Equity awards $ 105 $ 114 $ 131 Liability awards (1) 40 2 9 Total share-based compensation 145 116 140 Capitalized share-based compensation (5) (6) (9) Total share-based compensation expense $ 140 $ 110 $ 131 Tax benefit associated with share-based compensation expense $ 33 $ 23 $ 14 (1) The amount of share-based compensation recognized in 2021 associated with liability awards includes 0.2 million of performance share units held by five employees that are scheduled to vest in 2022 that were reclassified from equity awards to liability awards during 2021 as a result of a modification to settle the awards in cash in lieu of shares. We recognized approximately $18 million in incremental expense as a result of the modification.
Share-based Payment Arrangement, Nonvested Award, Cost	The total unrecognized compensation cost at December 31, 2021 relating to non-vested share-based compensation arrangements consisted of the following: Unrecognized Compensation Cost Recognized over a weighted average period Restricted Stock Share Awards $ 1 0.3 Restricted Stock Unit and Performance Stock Unit Awards $ 140 1.5
Nonvested Restricted Stock Shares Activity	The table below provides a summary of our restricted stock outstanding (in millions, except for per share information): Shares Weighted Average Grant Date Fair Value Per Share Non-vested at January 1, 2021 0.1 $ 41.78 Granted 0.0 0.00 Vested (0.1) 45.10 Forfeited 0.0 0.00 Non-vested at December 31, 2021 0.0 $ 0.00
Schedule of Nonvested Share Activity	The table below provides a summary of our restricted share unit and performance stock unit awards outstanding assuming payout at target for awards containing performance conditions (in millions, except for per unit information): Units Weighted Average Grant Date Fair Value Per Unit Non-vested at January 1, 2021 3.7 $ 60.00 Granted (1) 2.2 70.99 Vested (2.1) 59.57 Forfeited (0.1) 64.31 Non-vested at December 31, 2021 (2) 3.7 $ 66.71 (1) This number includes 0.2 million incremental shares of our common stock that were issued based on performance results from previously-granted performance stock unit awards.
Share-based Compensation, Restricted Stock Units and Performance Shares Award	The table below provides a summary of restricted share unit and performance stock unit awards issued and fair value of units vested: Year Ended December 31, 2021 2020 2019 Units issued (in millions) 2.2 1.8 1.9 Weighted average grant date fair value per unit $ 70.99 $ 53.88 $ 67.47 Fair value of units vested (in millions) $ 123 $ 137 $ 45

Net Income (Loss) Per Share A_2

Net Income (Loss) Per Share Attributable to Common Stockholders (Tables)	12 Months Ended
	Dec. 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions, except per share data): Year Ended December 31, 2021 2020 2019 Net income (loss) attributable to common stockholders $ (2,343) $ (85) 648 Weighted average common shares outstanding: Basic 253.4 252.4 256.2 Dilutive unvested stock — — 1.9 Diluted 253.4 252.4 258.1 Net income (loss) per share attributable to common stockholders—basic $ (9.25) $ (0.34) $ 2.53 Net income (loss) per share attributable to common stockholders—diluted $ (9.25) $ (0.34) $ 2.51
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): Year Ended December 31, 2021 2020 2019 Unvested stock (1) 1.8 3.4 2.3 Convertible notes 2021 Cheniere Convertible Unsecured Notes (2) — — 13.7 11% Convertible Senior Secured Notes due 2025 (“2025 CCH HoldCo II Convertible Senior Notes”) (3) — — 25.5 2045 Cheniere Convertible Senior Notes (4) — 4.5 4.5 Total potentially dilutive common shares 1.8 7.9 46.0 (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. (2) In the second quarter of 2021, we repaid the remaining principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash; therefore, the 2021 Cheniere Convertible Unsecured Notes were not included in the computation of net income per share for the year ended December 31, 2021. Additionally, since we had the intent and ability to settle the remaining outstanding principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash and the excess conversion premium (the “conversion spread”) in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2020. However, since the average market price of our common stock did not exceed the conversion price of our 2021 Cheniere Convertible Unsecured Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2020. (3) In the third quarter of 2020, we redeemed the remaining principal amount of the 2025 CCH HoldCo II Convertible Senior Notes and the related premium in cash; therefore, the 2025 CCH HoldCo II Convertible Senior Notes were not included in the computation of net income per share for the year ended December 31, 2021 and 2020. (4) Since we had the intent and ability to settle the outstanding principal amount of the 2045 Cheniere Convertible Senior Notes in cash and the conversion spread in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2021. However, since the average market price of our common stock did not exceed the conversion price for our 2045 Cheniere Convertible Senior Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2021.

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
Stockholders' Equity (Tables)	Dec. 31, 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 years ended December 31, 2021, 2020 and 2019 (in millions, except per share data): Year Ended December 31, 2021 2020 2019 Aggregate common stock repurchased 0.1 2.9 4.0 Weighted average price paid per share $ 87.32 $ 53.88 $ 62.27 Total amount paid $ 9 $ 155 $ 249

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
Commitments and Contingencies (Tables)	Dec. 31, 2021
SPL, CCL, and CCL Stage III [Member] \| Natural Gas Supply, Transportation And Storage Service Agreements [Member]
Long-term Purchase Commitment [Line Items]
Contractual Obligation, Fiscal Year Maturity Schedule	As of December 31, 2021, the obligations of SPL, CCL and CCL Stage III under natural gas supply, transportation and storage service agreements for contracts in which conditions precedent were met were as follows (in billions): Years Ending December 31, Payments Due (1) 2022 $ 8.8 2023 6.3 2024 4.6 2025 3.3 2026 2.7 Thereafter 16.5 Total $ 42.2 (1) Pricing of natural gas supply contracts is variable based on market commodity basis prices adjusted for basis spread, and pricing of IPM agreements is variable based on global gas market prices less fixed liquefaction fees and certain costs by us .

Customer Concentration (Tables)

Customer Concentration (Tables)	12 Months Ended
Customer Concentration (Tables)	Dec. 31, 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 Year Ended December 31, December 31, 2021 2020 2019 2021 2020 Customer A 12% 14% 16% 10% 14% Customer B 12% 12% 10% * 12% Customer C 10% 10% 11% * * Customer D * 10% 11% * * * Less than 10%
Schedule of Revenue from External Customers by Country	The following table shows revenues from external customers attributable to the country in which the revenues were derived (in millions). We attribute revenues from external customers to the country in which the party to the applicable agreement has its principal place of business. Revenues from External Customers Year Ended December 31, 2021 2020 2019 Ireland $ 1,838 $ 1,130 $ 989 Singapore 1,740 646 533 South Korea 1,680 942 1,207 Spain 1,577 1,034 598 India 1,375 1,021 1,160 United States 1,340 2,466 2,807 United Kingdom 1,246 678 559 Other countries 5,068 1,441 1,877 Total $ 15,864 $ 9,358 $ 9,730

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
Supplemental Cash Flow Information (Tables)	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Year Ended December 31, 2021 2020 2019 Cash paid during the period for interest on debt, net of amounts capitalized $ 1,365 $ 1,395 $ 1,126 Cash paid for income taxes, net of refunds 4 2 24 Non-cash investing and financing activities: Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities 339 282 473

Schedule I - Condensed Financ_2

Schedule I - Condensed Financial Information of Registrant (Tables)	12 Months Ended
	Dec. 31, 2021
Condensed Financial Statements, Captions [Line Items]
Schedule of Debt	As of December 31, 2021 and 2020, our debt consisted of the following (in millions): December 31, 2021 2020 SPL: Senior Secured Notes: 6.25% due 2022 $ — $ 1,000 5.625% due 2023 1,500 1,500 5.75% due 2024 2,000 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.27% weighted average rate due 2037 1,282 800 Total SPL Senior Secured Notes 13,132 13,650 $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”) — — Total debt - SPL 13,132 13,650 CQP: Senior Notes: 5.250% due 2025 — 1,500 5.625% due 2026 — 1,100 4.500% due 2029 1,500 1,500 4.000% due 2031 1,500 — 3.25% due 2032 1,200 — Total CQP Senior Notes 4,200 4,100 CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”) — — Total debt - CQP 4,200 4,100 CCH: Senior Secured Notes: 7.000% due 2024 1,250 1,250 5.875% due 2025 1,500 1,500 5.125% due 2027 1,500 1,500 3.700% due 2029 1,500 1,500 3.72% weighted average rate due 2039 2,721 1,971 Total CCH Senior Secured Notes 8,471 7,721 CCH Credit Facility (1) 1,728 2,627 $1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”) (2) 250 140 Total debt - CCH 10,449 10,488 Cheniere: 4.625% Senior Secured Notes due 2028 (“Cheniere Senior Secured Notes”) 2,000 2,000 4.875% Convertible Unsecured Notes due 2021 (“2021 Cheniere Convertible Unsecured Notes”) (1) — 476 2045 Cheniere Convertible Senior Notes (3) 625 625 $1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”) — — Cheniere’s term loan facility (“Cheniere Term Loan Facility”) — 148 Total debt - Cheniere 2,625 3,249 Cheniere Marketing: trade finance facilities and letter of credit facility (2) — — Total debt 30,406 31,487 Current portion of long-term debt (117) (232) Short-term debt (250) (140) Unamortized premium, discount and debt issuance costs, net (590) (644) Total long-term debt, net of premium, discount and debt issuance costs $ 29,449 $ 30,471 (1) A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt. (2) These debt instruments are classified as short-term debt. (3) The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption.
Schedule of Maturities of Long-term Debt	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2021 (in millions): Years Ending December 31, Principal Payments 2022 (1) $ 992 2023 1,567 2024 4,794 2025 3,537 2026 1,579 Thereafter 17,937 Total $ 30,406 (1) Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Consolidated Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. See Convertible Notes section below for further discussion of the redemption.
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): December 31, Consolidated Balance Sheets Location 2021 2020 Right-of-use assets—Operating Operating lease assets $ 2,102 $ 759 Right-of-use assets—Financing Property, plant and equipment, net of accumulated depreciation 50 53 Total right-of-use assets $ 2,152 $ 812 Current operating lease liabilities Current operating lease liabilities $ 535 $ 161 Current finance lease liabilities Other current liabilities 2 2 Non-current operating lease liabilities Operating lease liabilities 1,541 597 Non-current finance lease liabilities Finance lease liabilities 57 57 Total lease liabilities $ 2,135 $ 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 Year Ended December 31, 2021 2020 2019 Operating lease cost (a) Operating costs and expenses (1) $ 621 $ 432 $ 612 Finance lease cost: Amortization of right-of-use assets Depreciation and amortization expense 3 2 3 Interest on lease liabilities Interest expense, net of capitalized interest 9 7 10 Total lease cost $ 633 $ 441 $ 625 (a) Included in operating lease cost: Short-term lease costs $ 139 $ 93 $ 230 Variable lease costs 21 16 7
Schedule of Maturity of Lease Liabilities	Future annual minimum lease payments for operating and finance leases as of December 31, 2021 are as follows (in millions): Years Ending December 31, Operating Leases (1) Finance Leases 2022 $ 600 $ 11 2023 514 10 2024 456 10 2025 244 10 2026 218 10 Thereafter 294 117 Total lease payments 2,326 168 Less: Interest (250) (109) Present value of lease liabilities $ 2,076 $ 59 (1) Does not include approximately $1.2 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of December 31, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to 10 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: December 31, 2021 December 31, 2020 Operating Leases Finance Leases Operating Leases Finance Leases Weighted-average remaining lease term (in years) 5.6 16.7 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): Year Ended December 31, 2021 2020 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 483 $ 309 $ 389 Operating cash flows from finance leases 10 10 9 Right-of-use assets obtained in exchange for operating lease liabilities 1,736 615 235
Schedule of Share Repurchases Under the Share Repurchase Program	The following table presents information with respect to repurchases of common stock during the years ended December 31, 2021, 2020 and 2019 (in millions, except per share data): Year Ended December 31, 2021 2020 2019 Aggregate common stock repurchased 0.1 2.9 4.0 Weighted average price paid per share $ 87.32 $ 53.88 $ 62.27 Total amount paid $ 9 $ 155 $ 249
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Year Ended December 31, 2021 2020 2019 Cash paid during the period for interest on debt, net of amounts capitalized $ 1,365 $ 1,395 $ 1,126 Cash paid for income taxes, net of refunds 4 2 24 Non-cash investing and financing activities: Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities 339 282 473
Cheniere [Member]
Condensed Financial Statements, Captions [Line Items]
Condensed Statements of Operations	CHENIERE ENERGY, INC. CONDENSED STATEMENTS OF OPERATIONS (in millions) Year Ended December 31, 2021 2020 2019 General and administrative expense $ 17 $ 20 $ 17 Depreciation expense 1 — — Total operating costs and expenses 18 20 17 Other income (expense) Interest expense, net of capitalized interest (151) (155) (141) Interest income — — 1 Loss on modification or extinguishment of debt (6) (50) — Equity in income (loss) of subsidiaries (2,584) 77 490 Total other income (expense) (2,741) (128) 350 Income (loss) before income taxes (2,759) (148) 333 Less: income tax benefit (416) (63) (315) Net income (loss) attributable to common stockholders $ (2,343) $ (85) $ 648
Condensed Balance Sheet	CHENIERE ENERGY, INC. CONDENSED BALANCE SHEETS (in millions) December 31, 2021 2020 ASSETS Current assets Cash and cash equivalents $ 17 $ — Restricted cash and cash equivalents — 1 Other current assets 1 1 Total current assets 18 2 Property, plant and equipment, net of accumulated depreciation 35 30 Operating lease assets 19 22 Debt issuance and deferred financing costs, net of accumulated amortization 16 15 Investments in subsidiaries — 2,324 Deferred tax assets 797 381 Total assets $ 885 $ 2,774 LIABILITIES AND STOCKHOLDERS’ DEFICIT Current liabilities Current operating lease liabilities $ 6 $ 5 Current debt — 103 Other current liabilities 30 37 Total current liabilities 36 145 Long-term debt, net of discount and debt issuance costs 2,285 2,790 Investments in subsidiaries 1,110 — Operating lease liabilities 24 30 Other non-current liabilities 1 — Stockholders’ deficit (2,571) (191) Total liabilities and stockholders’ deficit $ 885 $ 2,774
Condensed Statements of Cash Flows	CHENIERE ENERGY, INC. CONDENSED STATEMENTS OF CASH FLOWS (in millions) Year Ended December 31, 2021 2020 2019 Net cash provided by (used in) operating activities $ (232) $ (285) $ 74 Cash flows from investing activities Property, plant and equipment (6) (13) (2) Distribution from (investment in) subsidiaries 1,498 (481) 842 Net cash provided by (used in) investing activities 1,492 (494) 840 Cash flows from financing activities Proceeds from issuance of debt 1,579 4,778 — Redemptions and repayments of debt (2,022) (3,143) — Debt issuance and other financing costs (9) (57) — Debt modification or extinguishment costs (1) (29) — Cash dividends to shareholders (85) — — Distributions to non-controlling interest (649) (626) (591) Payments related to tax withholdings for share-based compensation (48) (43) (19) Repurchase of common stock (9) (155) (249) Net cash provided by (used in) financing activities (1,244) 725 (859) Net increase (decrease) in cash, cash equivalents and restricted cash and cash equivalents 16 (54) 55 Cash, cash equivalents and restricted cash and cash equivalents—beginning of period 1 55 — Cash, cash equivalents and restricted cash and cash equivalents—end of period $ 17 $ 1 $ 55 Balances per Condensed Balance Sheets: December 31, 2021 2020 Cash and cash equivalents $ 17 $ — Restricted cash and cash equivalents — 1 Total cash, cash equivalents and restricted cash and cash equivalents $ 17 $ 1
Schedule of Debt	As of December 31, 2021 and 2020, our debt consisted of the following (in millions): December 31, 2021 2020 4.625% Senior Secured Notes due 2028 2,000 2,000 4.875% Convertible Unsecured Notes due 2021 (1) — 476 4.25% Convertible Senior Notes due 2045 (2) 625 625 Cheniere Revolving Credit Facility — — Cheniere Term Loan Facility — 148 Total debt 2,625 3,249 Current portion of long-term debt — (104) Unamortized discount and debt issuance costs, net (340) (355) Total long-term debt, net of discount and debt issuance costs $ 2,285 $ 2,790 (1) A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
Schedule of Maturities of Long-term Debt	Below is a schedule of future principal payments that we are obligated to make on our outstanding debt at December 31, 2021 (in millions): Years Ending December 31, Principal Payments 2022 (1) $ 625 2023 — 2024 — 2025 — 2026 — Thereafter 2,000 Total $ 2,625 (1) Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date.
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 Condensed Balance Sheets (in millions): December 31, Condensed Balance Sheet Location 2021 2020 Right-of-use assets—Operating Operating lease assets $ 19 $ 22 Total right-of-use assets $ 19 $ 22 Current operating lease liabilities Current operating lease liabilities $ 6 $ 5 Non-current operating lease liabilities Operating lease liabilities 24 30 Total lease liabilities $ 30 $ 35
Schedule of Lease Cost, Income Statement Location	The following table shows the classification and location of our lease cost on our Condensed Statements of Operations (in millions): Year Ended December 31, Condensed Statements of Operations Location 2021 2020 Operating lease cost (1) General and administrative expense $ 9 $ 10
Schedule of Maturity of Lease Liabilities	Future annual minimum lease payments for operating leases as of December 31, 2021 are as follows (in millions): Years Ending December 31, Operating Leases (1) 2022 $ 8 2023 8 2024 7 2025 6 2026 6 Thereafter 1 Total lease payments 36 Less: Interest (6) Present value of lease liabilities $ 30
Lease, Other Quantitative Information	The following table shows the weighted-average remaining lease term (in years) and the weighted-average discount rate for our operating leases: December 31, 2021 2020 Weighted-average remaining lease term (in years) 4.8 5.7 Weighted-average discount rate 6.6% 6.6% The following table includes other quantitative information for our operating leases (in millions): Year Ended December 31, 2021 2020 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 7 $ 7 Right-of-use assets obtained in exchange for new operating lease liabilities — 5
Schedule of Share Repurchases Under the Share Repurchase Program	The following table presents information with respect to repurchases of common stock during the years ended December 31, 2021 and 2020 (in millions, except per share data): Year Ended December 31, 2021 2020 2019 Aggregate common stock repurchased 0.1 2.9 4.0 Weighted average price paid per share $ 87.32 $ 53.88 $ 62.27 Total amount paid (in millions) $ 9 $ 155 $ 249
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Year Ended December 31, 2021 2020 2019 Cash paid during the period for interest, net of amounts capitalized $ 130 $ 45 $ 36 Non-cash investing and financing activities: Non-cash capital distributions (1) — 79 490 (1) Amounts represent undistributed equity income of affiliates.

Organization and Nature of Op_2

Organization and Nature of Operations (Details)	12 Months Ended
Organization and Nature of Operations (Details)	Dec. 31, 2021itemmilliontonnes / yrunitmitrains
Organization and Nature of Operations [Line Items]
Number Of Natural Gas Liquefaction And Export Facilities \| unit	2
Sabine Pass LNG Terminal [Member]
Organization and Nature of Operations [Line Items]
Number of Liquefaction LNG Trains Operating \| trains	6
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]
Organization and Nature of Operations [Line Items]
Length of Natural Gas Pipeline \| mi	94
Corpus Christi LNG Terminal [Member]
Organization and Nature of Operations [Line Items]
Number of Liquefaction LNG Trains Operating \| trains	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]
Organization and Nature of Operations [Line Items]
Length of Natural Gas Pipeline \| mi	21.5
Corpus Christi LNG Terminal Expansion [Member]
Organization and Nature of Operations [Line Items]
Total Production Capability \| milliontonnes / yr	10
Corpus Christi LNG Terminal Expansion [Member] \| Maximum [Member]
Organization and Nature of Operations [Line Items]
Number of Liquefaction LNG Trains \| trains	7
CQP [Member]
Organization and Nature of Operations [Line Items]
General Partner ownership percentage	100.00%
Limited Partner ownership percentage	48.60%

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)unit	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Accounts Receivable, Allowance for Credit Loss, Current	$ 5	$ 5
Impairment expense related to property, plant and equipment	8	0	$ 0
Derivative instruments designated as cash flow hedges	0	$ 0	$ 0
Goodwill Impairment	$ 0
Number of reportable segments \| unit	1
2045 Cheniere Convertible Senior Notes [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Equity component	$ 194
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Aggregate principal amount	$ 625
Accounting Standards Update 2020-06 \| 2045 Cheniere Convertible Senior Notes [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Equity component	194
IncreaseDecreaseDebtInstrumentConvertibleCarryingAmount	$ 190
SPA Customers [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
SPA, Term of Agreement	17 years
Sabine Pass LNG Terminal [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligation	$ 0
Creole Trail Pipeline [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligation	0
Corpus Christi Pipeline [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Asset Retirement Obligation	$ 0
Maximum [Member] \| Sabine Pass LNG Terminal [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Property lease term	90 years
SPLNG [Member] \| Customer Concentration Risk [Member] \| TUA Customers [Member]
Basis of Presentation and Summary of Significant Accounting Policies [Line Items]
Concentration Risk, Number of Significant Customers \| unit	2

Restricted Cash and Cash Equi_3

Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 413	[1]	$ 449
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	98		97
CCL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	44		70
Cash held by our subsidiaries restricted to Cheniere [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 271		$ 282

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Accounts and Other Receivable_3

Accounts and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accounts and Other Receivables [Line Items]
Other accounts receivable	$ 64	$ 52
Total accounts and other receivables, net of current expected credit losses	1,506	647
SPL and CCL
Accounts and Other Receivables [Line Items]
Trade receivables	802	482
Cheniere Marketing
Accounts and Other Receivables [Line Items]
Trade receivables	$ 640	$ 113

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Inventory [Line Items]
Inventory	$ 706	$ 292
Materials [Member]
Inventory [Line Items]
Inventory	174	150
LNG in-transit [Member]
Inventory [Line Items]
Inventory	312	88
LNG [Member]
Inventory [Line Items]
Inventory	153	27
Natural gas [Member]
Inventory [Line Items]
Inventory	64	26
Other [Member]
Inventory [Line Items]
Inventory	$ 3	$ 1

Property, Plant and Equipment_3

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Property, Plant and Equipment, Net of Accumulated Depreciation (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 30,288	$ 30,421
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(3,912)	(2,935)
Property, plant and equipment, net of accumulated depreciation	30,184	30,242
LNG terminal and interconnecting pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	30,660	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	2,995	5,378
Fixed assets and other [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(176)	(164)
Property, plant and equipment, net of accumulated depreciation	54	126
Computer and office equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	25	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	120	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	19	25
Tug vessels under finance lease [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	60	60
Accumulated depreciation	(10)	(7)
Property, plant and equipment, net of accumulated depreciation	$ 50	$ 53

Property, Plant and Equipment_4

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Depreciation and Offsets to LNG Terminal Costs (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 1,006	$ 926	$ 788
Offsets to LNG terminal costs	[1]	$ 319	$ 19	$ 301

[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.

Property, Plant and Equipment_5

Property, Plant and Equipment, Net of Accumulated Depreciation - Estimated Useful Lives (Details)	12 Months Ended
	Dec. 31, 2021
Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	6 years
Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
LNG storage tanks [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Natural gas pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	40 years
Marine berth, electrical, facility and roads [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	35 years
Water pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Regasification processing equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Sendout pumps [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	20 years
Liquefaction processing equipment [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	6 years
Liquefaction processing equipment [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	50 years
Other [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	10 years
Other [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 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	1 year
FX Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount	$ 762	$ 786
FX Derivatives [Member] \| Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	1 year

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 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	$ (40)	$ (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	(40)	(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	(4,038)	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	7	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	(9)	(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	(4,036)	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	(400)	(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	(22)	(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	(378)	(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	0	0
FX Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	12	(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	12	(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

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member]	12 Months Ended
	Dec. 31, 2021USD ($)
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Net Fair Value Liabilities	$ (4,036,000,000)
Valuation, Market Approach [Member] \| Minimum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	(1.368)
Valuation, Market Approach [Member] \| Maximum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	0.628
Valuation, Market Approach [Member] \| Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread	$ (0.016)	[1]
Valuation Technique, Option Pricing Model [Member] \| Minimum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	185.00%	[2]
Valuation Technique, Option Pricing Model [Member] \| Maximum [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	662.00%	[2]
Valuation Technique, Option Pricing Model [Member] \| Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Tecniques [Line Items]
Fair Value Inputs Basis Spread Percentage	248.00%	[1],[2]

[1]	Unobservable inputs were weighted by the relative fair value of the instruments.
[2]	Spread contemplates U.S. dollar-denominated pricing.

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Derivatives Activity (Details) - Physical Liquefaction Supply Derivatives and Physical LNG Trading Derivative - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ 241	$ 138	$ (29)
Realized and mark-to-market gains (losses):
Included in cost of sales		(4,305)	156	(77)
Purchases and settlements:
Purchases		(1)	5	199
Settlements		29	(65)	44
Transfers into Level 3, net	[1]	0	7	1
Balance, end of period		(4,036)	241	138
Change in unrealized gains (losses) relating to instruments still held at end of period		$ (4,305)	$ 156	$ (77)

[1]	Transferred into Level 3 as a result of unobservable market, or out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.

Derivative Instruments - Sche_2

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) $ in Billions		12 Months Ended
		Dec. 31, 2021USD ($)tbtu	Dec. 31, 2020USD ($)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]	11,238	10,483
LNG Trading Derivatives [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	[1]	33	20

[1]	The balances as of December 31, 2020 include notional amounts for natural gas supply contracts that SPL and CCL have with related parties. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions .

Derivative Instruments - Deriva

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CCH Interest Rate Derivatives [Member] \| Interest rate derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ (1)	$ (138)	$ (101)
CCH Interest Rate Forward Start Derivatives [Member] \| Interest rate derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		0	(95)	(33)
LNG Trading Derivatives [Member] \| LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	(1,812)	(26)	402
LNG Trading Derivatives [Member] \| Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	91	(42)	(89)
Liquefaction Supply Derivatives [Member] \| LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1],[2]	3	(1)	2
Liquefaction Supply Derivatives [Member] \| Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1],[2]	(4,303)	94	194
FX Derivatives [Member] \| LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ 33	$ (3)	$ 25

[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.

Derivative Instruments - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 55	$ 32
Derivative assets		69	376
Total derivative assets		124	408
Current derivative liabilities		(1,089)	(313)
Derivative liabilities		(3,501)	(151)
Total derivative liabilities		(4,590)	(464)
Derivative asset (liability), net		(4,466)	(56)
Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets		55	32
Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		69	376
Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities		(1,089)	(313)
Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(3,501)	(151)
CCH Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		0	0
Total derivative liabilities		(40)	(140)
Derivative asset (liability), net		(40)	(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		(40)	(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]	107	403
Total derivative liabilities	[1]	(4,145)	(163)
Derivative asset (liability), net	[1]	(4,038)	240
Derivative, collateral posted by us		20	9
Liquefaction Supply Derivatives [Member] \| Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	38	27
Liquefaction Supply Derivatives [Member] \| Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	69	376
Liquefaction Supply Derivatives [Member] \| Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(644)	(54)
Liquefaction Supply Derivatives [Member] \| Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	(3,501)	(109)
LNG Trading Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[2]	2	0
Total derivative liabilities	[2]	(402)	(134)
Derivative asset (liability), net	[2]	(400)	(134)
Derivative, collateral posted by us		745	16
LNG Trading Derivatives [Member] \| Current Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[2]	2	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]	(402)	(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		(3)	(27)
Derivative asset (liability), net		12	(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		(3)	(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 $20 million and $9 million as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets. Includes derivative assets for natural gas supply contracts that SPL and CCL had with related parties as of December 31, 2020. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions .
[2]	Does not include collateral posted with counterparties by us of $745 million and $16 million, as of December 31, 2021 and 2020, respectively, which are included in margin deposits in our Consolidated Balance Sheets.

Derivative Instruments - Deri_2

Derivative Instruments - Derivative Net Presentation on Consolidated Balance Sheets (Details) - USD ($) $ in Millions	Dec. 31, 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	(40)	(140)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(40)	(140)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	155	452
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(48)	(49)
Derivative Assets (Liabilities), at Fair Value, Net	107	403
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(4,382)	(184)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	237	21
Derivative Assets (Liabilities), at Fair Value, Net	(4,145)	(163)
LNG Trading Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	10	0
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(8)	0
Derivative Assets (Liabilities), at Fair Value, Net	2	0
LNG Trading Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(551)	(163)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	149	29
Derivative Assets (Liabilities), at Fair Value, Net	(402)	(134)
FX Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	48	6
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(33)	(1)
Derivative Assets (Liabilities), at Fair Value, Net	15	5
FX Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(10)	(62)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	7	35
Derivative Assets (Liabilities), at Fair Value, Net	$ (3)	$ (27)

Other Non-Current Assets - Sche

Other Non-Current Assets - Schedule of Non-Current Assets (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Other Assets, Noncurrent [Abstract]
Contract assets, net of current expected credit losses	$ 135	$ 80
Advances made to municipalities for water system enhancements	81	84
Equity method investments	56	81
Advances and other asset conveyances to third parties to support LNG terminals	80	60
Debt issuance costs and debt discount, net of accumulated amortization	34	42
Advances made under EPC and non-EPC contracts	5	9
Advance tax-related payments and receivables	17	20
Other	54	30
Total other non-current assets, net	$ 462	$ 406

Other Non-Current Assets - Equi

Other Non-Current Assets - Equity Method Investments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)mi	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 56	$ 81
Midship Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Length of Natural Gas Pipeline \| mi	200
Equity Method Investment, Other than Temporary Impairment	$ 37	129	$ 87
Equity method investments	$ 56	$ 80

Non-Controlling Interest and _3

Non-Controlling Interest and Variable Interest Entity (Details) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)unitshares		Dec. 31, 2012shares	Dec. 31, 2020USD ($)
Noncontrolling Interest and Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 1,404	[1]		$ 1,628
Accounts and other receivables, net of current expected credit losses	1,506			647
Other current assets	207			96
Total current assets	5,056			3,169
Property, plant and equipment, net of accumulated depreciation	30,288			30,421
Other non-current assets, net	462			406
Total assets	39,258	[1]		35,697
Accrued liabilities	2,299			1,175
Other current liabilities	94			2
Total current liabilities	4,693			2,196
Long-term debt, net of premium, discount and debt issuance costs	29,449			30,471
Other non-current liabilities	$ 50			7
CQP [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Limited Partner ownership percentage	48.60%
General Partner ownership percentage	100.00%
CQP [Member] \| Common Units [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Partners Capital Account, Units, Units Held \| shares	239.9
Blackstone CQP Holdco [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Number Of Members Of The Board Of Directors \| unit	1
CQP [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 876			1,210
Restricted cash and cash equivalents	98			97
Accounts and other receivables, net of current expected credit losses	580			318
Other current assets	285			182
Total current assets	1,839			1,807
Property, plant and equipment, net of accumulated depreciation	16,830			16,723
Other non-current assets, net	316			287
Total assets	18,985			18,817
Accrued liabilities	1,077			662
Other current liabilities	200			167
Total current liabilities	1,277			829
Long-term debt, net of premium, discount and debt issuance costs	17,177			17,580
Other non-current liabilities	100			126
Total liabilities	$ 18,554			$ 18,535
CQP [Member] \| Blackstone CQP Holdco [Member] \| Director Appointment Entitlement, Minimum [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Limited Partner ownership percentage	20.00%
CQP [Member] \| Blackstone CQP Holdco [Member] \| Class B Units [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Partners Capital Account, Units Sold In Private Placement \| shares			100
Cheniere Energy Partners GP, LLC [Member] \| Blackstone CQP Holdco [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Number Of Members Of The Board Of Directors \| unit	3
Minimum Number Of Members Of The Board Of Directors Required For Quorum \| unit	2
Cheniere Energy Partners GP, LLC [Member] \| Cheniere [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Number Of Members Of The Board Of Directors \| unit	4
Minimum Number Of Members Of The Board Of Directors Required For Quorum \| unit	2
Cheniere Energy Partners GP, LLC [Member] \| Blackstone CQP Holdco LP and Cheniere [Member]
Noncontrolling Interest and Variable Interest Entity [Line Items]
Number Of Members Of The Board Of Directors \| unit	4
Minimum Number Of Members Of The Board Of Directors Required For Quorum \| unit	2

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Accrued Liabilities, Current [Abstract]
Accrued natural gas purchases	$ 1,323	$ 576
Accrued derivative settlements	329	0
Interest costs and related debt fees	214	245
LNG terminals and related pipeline costs	144	147
Compensation and benefits	180	123
Accrued LNG inventory	34	4
Other accrued liabilities	75	80
Total accrued liabilities	$ 2,299	$ 1,175

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 30,406		$ 31,487
Current portion of long-term debt		(117)		(232)
Short-term Debt		(250)		(140)
Unamortized premium, discount and debt issuance costs, net		(590)		(644)
Total Long-Term Debt, Net of Premium, Discount and Debt Issuance Costs		29,449		30,471
SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		13,132		13,650
2022 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		1,000
Debt Instrument, Interest Rate, Stated Percentage		6.25%
2023 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2024 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2026 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.875%
2027 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.00%
2028 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,350		1,350
Debt Instrument, Interest Rate, Stated Percentage		4.20%
2030 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage		4.50%
2037 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,282		800
2037 SPL Senior Notes [Member] \| Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.27%
2020 SPL Working Capital Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		0
Line of Credit Facility, Maximum Borrowing Capacity		1,200
CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		4,200		4,100
2025 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.25%
2026 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		1,100
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2029 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		4.50%
2031 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		0
Debt Instrument, Interest Rate, Stated Percentage		4.00%
2032 CQP Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,200		0
Debt Instrument, Interest Rate, Stated Percentage		3.25%
2019 CQP Credit Facilities [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		0
CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		8,471		7,721
2024 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,250		1,250
Debt Instrument, Interest Rate, Stated Percentage		7.00%
2025 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.875%
2027 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		5.125%
2029 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage		3.70%
2039 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 2,721		1,971
2039 CCH Senior Notes [Member] \| Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.72%
CCH Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[1]	$ 1,728		2,627
CCH Working Capital Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[2]	250		140
Short-term Debt	[3]	(250)
Line of Credit Facility, Maximum Borrowing Capacity		1,200
2028 Cheniere Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage		4.625%
2021 Convertible Unsecured Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0	[4]	476	[1]
Debt Instrument, Interest Rate, Stated Percentage		4.875%
2045 Cheniere Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[5]	$ 625		625	[6]
Unamortized premium, discount and debt issuance costs, net		$ (304)
Debt Instrument, Interest Rate, Stated Percentage		4.25%
Cheniere Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		$ 0		0
Line of Credit Facility, Maximum Borrowing Capacity		1,250
Cheniere Term Loan Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		0		148
Cheniere Marketing Trade Finance Facilities [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[2]	0		0
SPL [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		13,132		13,650
CQP [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		4,200		4,100
CCH [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		10,449		10,488
Cheniere [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount		2,625		3,249
Current portion of long-term debt		0		(104)
Short-term Debt		0		(103)
Unamortized premium, discount and debt issuance costs, net		(340)		(355)
Total Long-Term Debt, Net of Premium, Discount and Debt Issuance Costs		$ 2,285		$ 2,790

[1]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[2]	These debt instruments are classified as short-term debt.
[3]	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 Secured Notes and the CCH Credit Facility.
[4]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[5]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 4.25% Convertible Senior Notes due 2045 were classified as long-term debt as of December 31, 2021.
[6]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption.

Debt - Senior Notes (Details)

Debt - Senior Notes (Details) - CQP [Member]	12 Months Ended
Debt - Senior Notes (Details) - CQP [Member]	Dec. 31, 2021USD ($)
Debt Instrument [Line Items]
Debt Instrument, Secured Debt Condition, Secured Indebtedness and Attributable Indebtedness Threshold, Monetary Amount	$ 1,500,000,000
Debt Instrument, Secured Debt Condition, Secured Indebtedness and Attributable Indebtedness Threshold, Percentage of Net Tangible Assets	10.00%

Debt - Schedule of Maturities (

Debt - Schedule of Maturities (Details) $ in Millions	Dec. 31, 2021USD ($)
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	$ 992	[1]
2023	1,567
2024	4,794
2025	3,537
2026	1,579
Thereafter	17,937
Total	30,406
2045 Cheniere Convertible Senior Notes [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Aggregate principal amount	$ 625

[1]	Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Consolidated Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. See Convertible Notes section below for further discussion of the redemption.

Debt - Credit Facilities Table

Debt - Credit Facilities Table (Details) $ in Millions		12 Months Ended
Debt - Credit Facilities Table (Details) $ in Millions		Dec. 31, 2021USD ($)unitRate	Dec. 31, 2020USD ($)
Line of Credit Facility [Line Items]
Outstanding balance - current		$ 250	$ 140
Quarterly Non-Consolidated Leverage Ratio Covenant, Maximum \| unit		5.50
Debt Instrument, Liquidity Covenant Threshold, Sum Of Outstanding Loans And Unreimbursed Letters Of Credit, Percentage of Commitments, Minimum		35.00%
2020 SPL Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	[1]	$ 1,200
Incremental commitments	[1]	0
Outstanding balance	[1]	0
Commitments prepaid or terminated	[1]	0
Letters of credit issued	[1]	395
Available commitment	[1]	$ 805
Line of Credit Facility, Commitment Fee Percentage		0.20%
Maturity date		Mar. 19, 2025
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	[2]	$ 1,500
Incremental commitments	[2]	0
Outstanding balance	[2]	0
Commitments prepaid or terminated	[2]	750
Letters of credit issued	[2]	0
Available commitment	[2]	$ 750
Line of Credit Facility, Commitment Fee Percentage		0.49%
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	[3]	$ 8,404
Incremental commitments	[3]	1,566
Outstanding balance	[3]	1,729
Commitments prepaid or terminated	[3]	8,241
Letters of credit issued	[3]	0
Available commitment	[3]	$ 0
Weighted average interest rate on current debt		1.85%
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	[4]	1.75%
CCH Credit Facility [Member] \| Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate \| Rate	[4]	0.75%
CCH Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	[5]	$ 350
Incremental commitments	[5]	850
Outstanding balance - current	[5]	250
Commitments prepaid or terminated	[5]	0
Letters of credit issued	[5]	361
Available commitment	[5]	$ 589
Weighted average interest rate on current debt		3.50%
Line of Credit Facility, Commitment Fee Percentage		0.50%
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	[4]	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	[4]	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	[4]	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	[4]	0.75%
Cheniere Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	[6]	$ 750
Incremental commitments	[6]	500
Outstanding balance	[6]	0
Commitments prepaid or terminated	[6]	0
Letters of credit issued	[6]	0
Available commitment	[6]	$ 1,250
Line of Credit Facility, Commitment Fee Percentage		0.25%
Maturity date		Oct. 28, 2026
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	[4]	1.25%
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	[4]	2.375%
Cheniere Revolving Credit Facility [Member] \| Base Rate [Member] \| Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate \| Rate	[4]	0.25%
Cheniere Revolving Credit Facility [Member] \| Base Rate [Member] \| Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate \| Rate	[4]	1.375%

[1]	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 Secured Notes. The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions
[2]	See CQP Senior Notes
[3]	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 of its limited liability company interests in CCH.
[4]	These facilities were amended in 2021 to establish a SOFR-indexed replacement rate for LIBOR.
[5]	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 Secured Notes and the CCH Credit Facility.
[6]	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 (other than certain excluded subsidiaries). The Cheniere Revolving Credit Facility contains a financial covenant requiring us to maintain a non-consolidated leverage ratio not to exceed 5.50:1.00 as of the end of any fiscal quarter if (i) as of the last day of such fiscal quarter the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit is greater than 35% of the aggregate commitments under the Cheniere Revolving Credit Facility (a “Covenant Trigger Event”) or (ii) a Covenant Trigger Event had occurred and been continuing as of the last day of the immediately preceding fiscal quarter and as of the last day of such ending fiscal quarter such Covenant Trigger Event had not ceased for a period of at least thirty consecutive days.

Debt - Convertible Notes (Detai

Debt - Convertible Notes (Details) $ in Millions	12 Months Ended
Debt - Convertible Notes (Details) $ in Millions	Dec. 31, 2021USD ($)unit	Dec. 31, 2020USD ($)
Debt Instrument [Line Items]
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	$ 590	$ 644
Debt, Minimum Historical Debt Service Coverage Ratio And Projected Debt Service Coverage Ratio \| unit	1.25
Amount of Restricted Net Assets for Consolidated and Unconsolidated Subsidiaries	$ 1,500
2045 Cheniere Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Aggregate original principal	625
Debt component, net of discount and debt issuance costs	321
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net	304
Equity component	$ 194
Effective interest rate	9.40%
Debt Instrument, Convertible, Conversion Ratio	7.2265

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	12 Months Ended
Debt - Interest Expense (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Total interest cost	$ 1,604	$ 1,773	$ 1,846
Capitalized interest	(166)	(248)	(414)
Total interest expense, net of capitalized interest	1,438	1,525	1,432
Convertible Debt [Member]
Debt Instrument [Line Items]
Interest per contractual rate	36	152	256
Amortization of debt discount	10	45	40
Amortization of debt issuance costs	0	8	12
Total interest cost	46	205	308
Debt and Finance Leases Excluding Convertible Debt [Member]
Debt Instrument [Line Items]
Total interest cost	$ 1,558	$ 1,568	$ 1,538

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt		$ 30,406		$ 31,487
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]	24,550		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]	3,253		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]	26,725		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]	3,693		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]	1,978		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]	1,978		2,915
2021 Convertible Unsecured Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt		0	[4]	476	[5]
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]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Debt	[6]	625		625	[7]
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	[8]	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	[8]	$ 526		$ 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]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[5]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[6]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 4.25% Convertible Senior Notes due 2045 were classified as long-term debt as of December 31, 2021.
[7]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption.
[8]	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.

Leases - Balance Sheet Location

Leases - Balance Sheet Location Table (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Right-of-use assets—Operating	$ 2,102	$ 759
Total right-of-use assets	2,152	812
Current operating lease liabilities	535	161
Non-current operating lease liabilities	1,541	597
Non-current finance lease liabilities	57	57
Total lease liabilities	2,135	817
Operating lease assets, net [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets—Operating	2,102	759
Property, plant and equipment, net of accumulated depreciation [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets—Financing	50	53
Current operating lease liabilities [Member]
Lessee, Lease, Description [Line Items]
Current operating lease liabilities	535	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	1,541	597
Finance lease liabilities [Member]
Lessee, Lease, Description [Line Items]
Non-current finance lease liabilities	$ 57	$ 57

Leases - Income Statement Locat

Leases - Income Statement Location Table (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finance lease cost:
Total lease cost		$ 633	$ 441	$ 625
Operating costs and expenses [Member]
Lessee, Lease, Description [Line Items]
Operating lease cost	[1]	621	432	612
Finance lease cost:
Short-term lease costs		139	93	230
Variable lease costs		21	16	7
Depreciation and amortization expense [Member]
Finance lease cost:
Amortization of right-of-use assets		3	2	3
Interest expense, net of capitalized interest [Member]
Finance lease cost:
Interest on lease liabilities		$ 9	$ 7	$ 10

[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.

Leases - Future Minimum Payment

Leases - Future Minimum Payments Table (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Operating Leases, Future Minimum Payments
2022	$ 600	[1]
2023	514	[1]
2024	456	[1]
2025	244	[1]
2026	218	[1]
Thereafter	294	[1]
Total lease payments	2,326	[1]
Less: Interest	(250)	[1]
Present value of lease liabilities	2,076	[1]
Finance Leases, Future Minimum Payments
2022	11
2023	10
2024	10
2025	10
2026	10
Thereafter	117
Total lease payments	168
Less: Interest	(109)
Present value of lease liabilities	59
Operating Lease, Lease Not yet Commenced, Payments Due	$ 1,200
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	10 years

[1]	Does not include approximately $1.2 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of December 31, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to 10 years.

Leases - Other Quantitative Inf

Leases - Other Quantitative Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Leases
Weighted-average remaining lease term		5 years 7 months 6 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 8 months 12 days	17 years 8 months 12 days
Weighted-average discount rate	[1]	16.20%	16.20%
Operating cash flows from operating leases		$ 483	$ 309	$ 389
Operating cash flows from finance leases		10	10	9
Right-of-use assets obtained in exchange for operating lease liabilities		$ 1,736	$ 615	$ 235

[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.

Leases - Subleases (Details)

Leases - Subleases (Details) - USD ($) $ in Millions	12 Months Ended
Leases - Subleases (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Sublease payments to be received	$ 15	$ 0
Sublease Income, Fixed	72	68	$ 122
Sublease Income, Variable	37	27	22
Sublease Income, Total	$ 109	$ 95	$ 144

Revenues from Contracts with _3

Revenues from Contracts with Customers - Narrative (Details) $ in Millions		12 Months Ended
		Dec. 31, 2021USD ($)unit	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Disaggregation of Revenue [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub		115.00%
Revenues from contracts with customers		$ 17,531	$ 9,293	$ 9,157
Regasification Capacity \| unit		4
Operating and maintenance expense		$ 1,444	1,320	1,154
Terminal Use Agreement Regasification Capacity Partial [Member]
Disaggregation of Revenue [Line Items]
Operating and maintenance expense		$ 129	129	104
TUA Customers [Member]
Disaggregation of Revenue [Line Items]
Regasification Capacity \| unit		2
Each TUA Customer [Member]
Disaggregation of Revenue [Line Items]
Regasification Capacity \| unit		1
Revenue Performance Obligation Fixed Consideration		$ 125
Long-term Purchase Commitment, Period		20 years
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	[1]	$ 17,171	$ 8,954	8,817
Revenue, Variable Consideration Received From Customers, Percentage		60.00%	40.00%
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 269	$ 269	266
Number of Fixed Price Contracts \| unit		2
Revenue, Variable Consideration Received From Customers, Percentage		5.00%	5.00%
Liquefied Natural Gas Procured From Third Parties [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 499	$ 414	$ 268

[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 year ended December 31, 2020, we recognized $969 million in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $38 million would have been recognized during the year ended December 31, 2021 had the cargoes been 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 years ended December 31, 2021 and 2019. 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.

Revenues from Contracts with _4

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 17,531	$ 9,293	$ 9,157
Net derivative gain (loss)	[1]	(1,776)	(30)	429
Other revenues	[2]	109	95	144
Total revenues		15,864	9,358	9,730
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	[3]	17,171	8,954	8,817
Total revenues		15,395	8,924	9,246
Regasification [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		269	269	266
Other [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		91	70	74
Total revenues		200	165	218
Suspension Fees and LNG Cover Damages Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 0	969	$ 0
Suspension Fees and LNG Cover Damages Revenue [Member] \| Subsequent Period
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			$ 38

[1]	See Note 7—Derivative Instruments for additional information about our derivatives.
[2]	Includes revenues from LNG vessel subcharters. See Note 12—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 year ended December 31, 2020, we recognized $969 million in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $38 million would have been recognized during the year ended December 31, 2021 had the cargoes been 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 years ended December 31, 2021 and 2019. 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.

Revenues from Contracts with _5

Revenues from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 140	$ 80
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	138
Cash received but not yet recognized in revenue	194
Revenue recognized from prior period deferral	(138)
Deferred revenue, end of period	$ 194

Revenues from Contracts with _6

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		Dec. 31, 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]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 109
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]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 107.1
Weighted Average Recognition Timing	[1]	9 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]: 2022-01-01
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.

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Related Party Transaction [Line Items]
Revenues	$ 15,864	$ 9,358	$ 9,730
Operating and maintenance expense	1,444	1,320	1,154
Cost of sales (excluding items shown separately below)	13,773	4,161	5,079
Accrued liabilities	2,299	1,175
Accounts and other receivables, net of current expected credit losses	1,506	647
Other [Member]
Related Party Transaction [Line Items]
Revenues	$ 200	165	218
CCL [Member] \| Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term	10 years
Operating and maintenance expense	$ 9	6
Accrued liabilities	1	1
Sabine Pass Liquefaction LLC and Cheniere Creole Trail Pipeline LP [Member] \| Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Revenues	1	0
Operating and maintenance expense	46	13
Cost of sales (excluding items shown separately below)	1	0
Accrued liabilities	$ 4	4
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	$ 2	2
Cheniere LNG O&M Services, LLC [Member] \| Operation and Maintenance Agreement [Member] \| Other [Member]
Related Party Transaction [Line Items]
Revenues	$ 7	$ 9	$ 12

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) $ in Millions		12 Months Ended
		Dec. 31, 2021USD ($)tbtu	Dec. 31, 2020USD ($)tbtu	Dec. 31, 2019USD ($)
Related Party Transaction [Line Items]
Current derivative assets		$ 55	$ 32
Derivative assets		69	376
Cost of sales		$ 13,773	$ 4,161	$ 5,079
Liquefaction Supply Derivatives [Member]
Related Party Transaction [Line Items]
Derivative, Nonmonetary Notional Amount \| tbtu	[1]	11,238	10,483
CCL [Member] \| Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales	[2]	$ 162	$ 114	85
CCL [Member] \| Natural Gas Supply Agreement [Member] \| Liquefaction Supply Derivatives [Member]
Related Party Transaction [Line Items]
Current derivative assets		0	3
Derivative assets		$ 0	$ 1
Derivative, Nonmonetary Notional Amount \| tbtu		0	60
Liquefaction Supply Derivative gain	[2]	$ 13	$ (1)	$ (1)

[1]	The balances as of December 31, 2020 include notional amounts for natural gas supply contracts that SPL and CCL have with related parties. These agreements are not considered related party as of December 31, 2021 as discussed in Note 14—Related Party Transactions .
[2]	Includes amounts recorded related to natural gas supply contracts that SPL and CCL had with related parties. These agreements ceased to be considered related party agreements during 2021, as discussed above.

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
Income Taxes - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Valuation Allowance	$ 63	$ 190
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	(127)
Deferred Tax Assets, Operating Loss Carryforwards, Not Subject to Expiration	13,800
Deferred Tax Assets, Tax Credit Carryforwards	108	95
Unrecognized Tax Benefits	65	$ 62	$ 61
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	56
Federal Tax [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	15,700
Deferred Tax Assets, Tax Credit Carryforwards	107
Federal Tax [Member] \| Investment Tax Credit Carryforward [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Tax Credit Carryforwards	60
State Tax [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	2,400
Deferred Tax Assets, Tax Credit Carryforwards	1
Foreign Tax Authority
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	10
Deferred Tax Assets, Tax Credit Carryforwards	$ 44

Income Taxes - Components of In

Income Taxes - Components of Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income (loss) before income taxes and non-controlling interest, U.S.	$ (2,317)	$ 720	$ 289
Income (loss) before income taxes and non-controlling interest, International	39	(176)	426
Income (loss) before income taxes and non-controlling interest	$ (2,278)	$ 544	$ 715

Income Taxes - Provision for In

Income Taxes - Provision for Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current
Federal	$ 0	$ 0	$ 0
State	3	0	0
Foreign	5	0	4
Total current	8	0	4
Deferred
Federal	(633)	41	(475)
State	(89)	2	(46)
Foreign	1	0	0
Total deferred	(721)	43	(521)
Total income tax provision (benefit)	$ (713)	$ 43	$ (517)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Effective Income Tax Rate (Details)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
U.S. federal statutory tax rate	21.00%	21.00%	21.00%
Non-controlling interest	7.20%	(22.60%)	(17.20%)
State tax, net of federal benefit	(2.50%)	0.00%	(5.40%)
Executive compensation	(0.50%)	1.40%	1.30%
Nondeductible interest expense	0.00%	8.00%	5.00%
Foreign earnings taxed in the U.S.	0.00%	1.20%	6.70%
Foreign rate differential	(0.10%)	(3.70%)	(11.40%)
Tax credits	0.60%	(4.50%)	(5.20%)
Internal restructuring	0.00%	7.00%	0.00%
Other	0.00%	1.00%	1.40%
Valuation allowance	5.60%	(0.90%)	(68.50%)
Effective tax rate as reported	31.30%	7.90%	(72.30%)

Income Taxes - Components of De

Income Taxes - Components of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Net operating loss carryforwards and credits
Federal	$ 3,231	$ 3,084
Foreign	2	3
State	244	257
Federal and state tax credits	108	95
Derivative instruments	951	7
Other	584	283
Less: valuation allowance	(63)	(190)
Total deferred tax assets	5,057	3,539
Deferred tax liabilities
Investment in partnerships	(716)	(765)
Property, plant and equipment	(2,638)	(2,089)
Other	(499)	(196)
Total deferred tax liabilities	(3,853)	(3,050)
Net deferred tax assets	$ 1,204	$ 489

Income Taxes - Changes in Gross

Income Taxes - Changes in Gross Amounts of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of year	$ 62	$ 61
Additions based on tax positions related to current year	3	1
Additions for tax positions of prior years	0	0
Reductions for tax positions of prior years	0	0
Settlements	0	0
U.S. tax reform rate change	0	0
Balance at end of year	$ 65	$ 62

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
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	3 years
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award Vesting Period, Cliff Vesting	3 years
Share-based compensation that may be settled in cash	$ 3
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%
Restricted Stock Share Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Units Granted	0
Fair value of units vested	$ 2	$ 3	$ 3
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	1 year
Vesting Period - Service Years, Option 2	2 years
Vesting Period - Serivce Years, Option 3	3 years
Vesting Period - Service Years, Option 4	4 years
Phantom Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Units Granted	0
Fair value of units vested	$ 1	$ 4	$ 11
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	2 years
Vesting Period - Service Years, Option 2	3 years
Vesting Period - Serivce Years, Option 3	4 years
2020 Incentive Plan [Member] \| Common Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	8,000
2011 Incentive Plan \| Common Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	35,000

Share-Based Compensation - Sche

Share-Based Compensation - Schedule of Share-Based Compensation (Details) shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2021USD ($)unitshares	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation		$ 145	$ 116	$ 140
Capitalized share-based compensation		(5)	(6)	(9)
Total share-based compensation expense		140	110	131
Tax benefit associated with share-based compensation expense		33	23	14
Equity Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation		105	114	131
Liability Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total share-based compensation	[1]	40	$ 2	$ 9
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Goods and Nonemployee Services Transaction, Modification of Terms, Incremental Compensation Cost		$ 18
Share-based Payment Arrangement, Plan Modification, Number of Grantees Affected \| unit		5
Share-based Payment Arrangement, Plan Modification, Number of Shares Affected \| shares		0.2

[1]	The amount of share-based compensation recognized in 2021 associated with liability awards includes 0.2 million of performance share units held by five employees that are scheduled to vest in 2022 that were reclassified from equity awards to liability awards during 2021 as a result of a modification to settle the awards in cash in lieu of shares. We recognized approximately $18 million in incremental expense as a result of the modification.

Share-Based Compensation - Sc_2

Share-Based Compensation - Schedule of Unrecognized Compensation Cost (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)
Restricted Stock Share Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost	$ 1
Recognized over a weighted average period	3 months 18 days
Restricted Share Unit And Performance Stock Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost	$ 140
Recognized over a weighted average period	1 year 6 months

Share-Based Compensation - Sc_3

Share-Based Compensation - Schedule of Non-vested Awards (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Restricted Stock Share Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested at January 1, 2021, Shares	100
Non-vested at January 1, 2021, Weighted Average Grant Date Fair Value Per Share	$ 41.78
Granted, Shares	0
Granted, Weighted Average Grant Date Fair Value Per Share	$ 0
Vested, Shares	(100)
Vested, Weighted Average Grant Date Fair Value Per Share	$ 45.10
Forfeited, Shares	0
Forfeited, Weighted Average Grant Date Fair Value Per Share	$ 0
Non-vested at December 31, 2021, Shares	0		100
Non-vested at December 31, 2021, Weighted Average Grant Date Fair Value Per Share	$ 0		$ 41.78
Restricted Share Unit And Performance Stock Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested at January 1, 2021, Shares	3,700
Non-vested at January 1, 2021, Weighted Average Grant Date Fair Value Per Share	$ 60
Granted, Shares	2,200	[1]	1,800	1,900
Granted, Weighted Average Grant Date Fair Value Per Share	$ 70.99	[1]	$ 53.88	$ 67.47
Vested, Shares	(2,100)
Vested, Weighted Average Grant Date Fair Value Per Share	$ 59.57
Forfeited, Shares	(100)
Forfeited, Weighted Average Grant Date Fair Value Per Share	$ 64.31
Non-vested at December 31, 2021, Shares	3,700	[2]	3,700
Non-vested at December 31, 2021, Weighted Average Grant Date Fair Value Per Share	$ 66.71	[2]	$ 60
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Payment Award, Shares To Be Issued On Maximum Achievement Of Performance Under Target Awards, Maximum	1,300
Phantom Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, Shares	0
Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, shares granted from previously granted awards	200

[1]	This number includes 0.2 million incremental shares of our common stock that were issued based on performance results from previously-granted performance stock unit awards.
[2]	This number excludes 1.3 million performance stock units, which represent the incremental number of common units that would be issued if the maximum level of performance under the target awards amount is achieved.

Share-Based Compensation - Sc_4

Share-Based Compensation - Schedule of Restricted Share Unit and Performance Stock Units Awards (Details) - Restricted Share Unit And Performance Stock Unit Awards [Member] - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units issued	2.2	[1]	1.8	1.9
Weighted average grant date fair value per unit	$ 70.99	[1]	$ 53.88	$ 67.47
Fair value of units vested	$ 123		$ 137	$ 45

[1]	This number includes 0.2 million incremental shares of our common stock that were issued based on performance results from previously-granted performance stock unit awards.

Employee Benefit Plan (Details)

Employee Benefit Plan (Details) - USD ($) $ in Millions	12 Months Ended
Employee Benefit Plan (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Retirement Benefits [Abstract]
Defined Contribution Plan, Maximum Annual Contributions Per Employee, Percent	75.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay	6.00%
Defined Contribution Plan, Contributions	$ 15	$ 15	$ 15
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0

Net Income (Loss) Per Share A_3

Net Income (Loss) Per Share Attributable to Common Stockholders (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net income (loss) attributable to common stockholders		$ (2,343)	$ (85)	$ 648
Weighted average number of common shares outstanding, basic		253.4	252.4	256.2
Dilutive Unvested Stock		0	0	1.9
Weighted Average Number of Shares Outstanding, Diluted		253.4	252.4	258.1
Net income (loss) per share attributable to common stockholders—basic		$ (9.25)	$ (0.34)	$ 2.53
Net income (loss) per share attributable to common stockholders—diluted		$ (9.25)	$ (0.34)	$ 2.51
Antidilutive securities excluded from computation of earnings per share		1.8	7.9	46
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	3.4	2.3
2021 Cheniere Convertible Notes [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	[2]	0	0	13.7
2025 CCH HoldCo II Convertible Notes [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of earnings per share	[3]	0	0	25.5
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]	0	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.
[2]	In the second quarter of 2021, we repaid the remaining principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash; therefore, the 2021 Cheniere Convertible Unsecured Notes were not included in the computation of net income per share for the year ended December 31, 2021. Additionally, since we had the intent and ability to settle the remaining outstanding principal amount of the 2021 Cheniere Convertible Unsecured Notes in cash and the excess conversion premium (the “conversion spread”) in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2020. However, since the average market price of our common stock did not exceed the conversion price of our 2021 Cheniere Convertible Unsecured Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2020.
[3]	In the third quarter of 2020, we redeemed the remaining principal amount of the 2025 CCH HoldCo II Convertible Senior Notes and the related premium in cash; therefore, the 2025 CCH HoldCo II Convertible Senior Notes were not included in the computation of net income per share for the year ended December 31, 2021 and 2020.
[4]	Since we had the intent and ability to settle the outstanding principal amount of the 2045 Cheniere Convertible Senior Notes in cash and the conversion spread in either cash or shares, the treasury stock method was applied for calculating any potential dilutive effect of the conversion spread on net income per share for the year ended December 31, 2021. However, since the average market price of our common stock did not exceed the conversion price for our 2045 Cheniere Convertible Senior Notes, the conversion spread was excluded from the computation of diluted net income per share for the year ended December 31, 2021.

Stockholders' Equity - Narrativ

Stockholders' Equity - Narrative (Details) $ in Billions	12 Months Ended
Stockholders' Equity - Narrative (Details) $ in Billions	Dec. 31, 2021USD ($)
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
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

Stockholders' Equity - Schedule

Stockholders' Equity - Schedule of Share Repurchases (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Equity [Abstract]
Total amount paid	$ 9	$ 155	$ 249

Commitments and Contingencies -

Commitments and Contingencies - Narrative (Details) $ in Billions	12 Months Ended
	Dec. 31, 2021USD ($)
SPL, CCL, and CCL Stage III [Member] \| Natural Gas Supply Agreements [Member] \| Maximum [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Period	15 years
SPL and CCL \| Natural Gas Transportation Agreements [Member] \| Maximum [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Period	20 years
SPL [Member] \| EPC Contract, Train Six [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Amount	$ 2.5
Purchase Commitment, Remaining Minimum Amount Committed	$ 0.2
SPL [Member] \| Natural Gas Storage Service Agreements [Member] \| Maximum [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Period	10 years
CCL [Member] \| Natural Gas Storage Service Agreements [Member] \| Maximum [Member]
Commitments and Contingencies [Line Items]
Long-term Purchase Commitment, Period	5 years

Commitments and Contingencies_2

Commitments and Contingencies - Purchase Obligations Table (Details) $ in Billions	12 Months Ended
	Dec. 31, 2021USD ($)tbtu
EOG Resources, Inc. \| 2022 EOG IPM Agreement
Long-term Purchase Commitment [Line Items]
Incremental Contract Volumes \| tbtu	1,790
EOG Resources, Inc. \| 2022 EOG Gas Supply Agreement
Long-term Purchase Commitment [Line Items]
Incremental Contract Volumes \| tbtu	548
SPL, CCL, and CCL Stage III [Member] \| Natural Gas Supply, Transportation And Storage Service Agreements [Member]
Long-term Purchase Commitment [Line Items]
2022	$ 8.8	[1]
2023	6.3	[1]
2024	4.6	[1]
2025	3.3	[1]
2026	2.7	[1]
Thereafter	16.5	[1]
Total	$ 42.2	[1]

[1]	Pricing of natural gas supply contracts is variable based on market commodity basis prices adjusted for basis spread, and pricing of IPM agreements is variable based on global gas market prices less fixed liquefaction fees and certain costs by us .

Customer Concentration - Schedu

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Customer A [Member] \| Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12.00%	14.00%	16.00%
Customer A [Member] \| Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	10.00%	14.00%
Customer B [Member] \| Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12.00%	12.00%	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	10.00%	10.00%	11.00%
Customer D [Member] \| Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage		10.00%	11.00%

Customer Concentration - Sche_2

Customer Concentration - Schedule of Revenue from External Customers by Country (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Concentration Risk [Line Items]
Revenues from External Customers	$ 15,864	$ 9,358	$ 9,730
Geographic Concentration Risk [Member] \| Ireland
Concentration Risk [Line Items]
Revenues from External Customers	1,838	1,130	989
Geographic Concentration Risk [Member] \| Singapore
Concentration Risk [Line Items]
Revenues from External Customers	1,740	646	533
Geographic Concentration Risk [Member] \| South Korea
Concentration Risk [Line Items]
Revenues from External Customers	1,680	942	1,207
Geographic Concentration Risk [Member] \| Spain
Concentration Risk [Line Items]
Revenues from External Customers	1,577	1,034	598
Geographic Concentration Risk [Member] \| India
Concentration Risk [Line Items]
Revenues from External Customers	1,375	1,021	1,160
Geographic Concentration Risk [Member] \| United States
Concentration Risk [Line Items]
Revenues from External Customers	1,340	2,466	2,807
Geographic Concentration Risk [Member] \| United Kingdom
Concentration Risk [Line Items]
Revenues from External Customers	1,246	678	559
Geographic Concentration Risk [Member] \| Other countries
Concentration Risk [Line Items]
Revenues from External Customers	$ 5,068	$ 1,441	$ 1,877

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized	$ 1,365	$ 1,395	$ 1,126
Cash paid for income taxes, net of refunds	4	2	24
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities	$ 339	$ 282	$ 473

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information of Registrant - Condensed Statements of Operations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Income Statements, Captions [Line Items]
Depreciation expense	$ 1,006	$ 926	$ 788
Total operating costs and expenses	16,565	6,727	7,369
Other income (expense)
Interest expense, net of capitalized interest	(1,438)	(1,525)	(1,432)
Loss on modification or extinguishment of debt	(116)	(217)	(55)
Equity in income (loss) of subsidiaries	(24)	(126)	(88)
Total other expense	(1,577)	(2,087)	(1,646)
Income (Loss) before income taxes	(2,278)	544	715
Less: income tax provision (benefit)	(713)	43	(517)
Net income (loss) attributable to common stockholders	(2,343)	(85)	648
Cheniere [Member]
Condensed Income Statements, Captions [Line Items]
General and Administrative Expense	17	20	17
Depreciation expense	1	0	0
Total operating costs and expenses	18	20	17
Other income (expense)
Interest expense, net of capitalized interest	(151)	(155)	(141)
Interest Income	0	0	1
Loss on modification or extinguishment of debt	(6)	(50)	0
Equity in income (loss) of subsidiaries	(2,584)	77	490
Total other expense	(2,741)	(128)	350
Income (Loss) before income taxes	(2,759)	(148)	333
Less: income tax provision (benefit)	(416)	(63)	(315)
Net income (loss) attributable to common stockholders	$ (2,343)	$ (85)	$ 648

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information of Registrant - Condensed Balance Sheets (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 1,404	[1]	$ 1,628
Other current assets	207		96
Total current assets	5,056		3,169
Property, plant and equipment, net of accumulated depreciation	30,288		30,421
Operating lease assets	2,102		759
Investments in subsidiaries	56		81
Deferred tax assets	1,204		489
Total assets	39,258	[1]	35,697
Current liabilities
Current operating lease liabilities	535		161
Current debt	250		140
Other current liabilities	94		2
Total current liabilities	4,693		2,196
Long-term debt, net of premium, discount and debt issuance costs	29,449		30,471
Non-current operating lease liabilities	1,541		597
Other non-current liabilities	50		7
Stockholders' deficit	(2,571)		(191)
Total liabilities and stockholders’ equity (deficit)	39,258	[1]	35,697
Cheniere [Member]
Current assets
Cash and cash equivalents	17		0
Restricted cash and cash equivalents	0		1
Other current assets	1		1
Total current assets	18		2
Property, plant and equipment, net of accumulated depreciation	35		30
Operating lease assets	19		22
Debt issuance and deferred financing costs, net of accumulated amortization	16		15
Investments in subsidiaries	0		2,324
Deferred tax assets	797		381
Total assets	885		2,774
Current liabilities
Current operating lease liabilities	6		5
Current debt	0		103
Other current liabilities	30		37
Total current liabilities	36		145
Long-term debt, net of premium, discount and debt issuance costs	2,285		2,790
Investments in subsidiaries	1,110		0
Non-current operating lease liabilities	24		30
Other non-current liabilities	1		0
Stockholders' deficit	(2,571)		(191)
Total liabilities and stockholders’ equity (deficit)	$ 885		$ 2,774

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Schedule I - Condensed Financ_5

Schedule I - Condensed Financial Information of Registrant - Condensed Statements of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	$ 2,469		$ 1,265	$ 1,833
Cash flows from investing activities
Property, plant and equipment	(966)		(1,839)	(3,056)
Net cash used in investing activities	(912)		(1,947)	(3,163)
Cash flows from financing activities
Proceeds from issuances of debt	5,911		7,823	6,434
Redemptions and repayments of debt	(6,810)		(6,940)	(4,346)
Debt issuance and other financing costs	(53)		(125)	(51)
Debt modification or extinguishment costs	(82)		(172)	(15)
Cash dividends to shareholders	(85)		0	0
Distributions to non-controlling interest	(649)		(626)	(590)
Payments related to tax withholdings for share-based compensation	(48)		(43)	(19)
Repurchase of common stock	(9)		(155)	(249)
Net cash provided by (used in) financing activities	(1,817)		(235)	1,168
Net decrease in cash, cash equivalents and restricted cash and cash equivalents	(260)		(917)	(162)
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	2,077		2,994	3,156
Cash, cash equivalents and restricted cash and cash equivalents—end of period	1,817		2,077	2,994
Condensed Cash Flow Statement - Balances per Condensed Balance Sheet [Line Items]
Cash and cash equivalents	1,404	[1]	1,628
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	1,817		2,077	2,994
Cheniere [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(232)		(285)	74
Cash flows from investing activities
Property, plant and equipment	(6)		(13)	(2)
Distribution from (investment in) subsidiaries	1,498		(481)	842
Net cash used in investing activities	1,492		(494)	840
Cash flows from financing activities
Proceeds from issuances of debt	1,579		4,778	0
Redemptions and repayments of debt	(2,022)		(3,143)	0
Debt issuance and other financing costs	(9)		(57)	0
Debt modification or extinguishment costs	(1)		(29)	0
Cash dividends to shareholders	(85)		0	0
Distributions to non-controlling interest	(649)		(626)	(591)
Payments related to tax withholdings for share-based compensation	(48)		(43)	(19)
Repurchase of common stock	(9)		(155)	(249)
Net cash provided by (used in) financing activities	(1,244)		725	(859)
Net decrease in cash, cash equivalents and restricted cash and cash equivalents	16		(54)	55
Cash, cash equivalents and restricted cash and cash equivalents—beginning of period	1		55	0
Cash, cash equivalents and restricted cash and cash equivalents—end of period	17		1	55
Condensed Cash Flow Statement - Balances per Condensed Balance Sheet [Line Items]
Cash and cash equivalents	17		0
Restricted cash and cash equivalents	0		1
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents	$ 17		$ 1	$ 55

[1]	Amounts presented include balances held by our consolidated variable interest entity (“VIE”), CQP, as further discussed in Note 9 — Non-controlling Interest and Variable Interest Entity. As of December 31, 2021, total assets and liabilities of CQP, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.6 billion, respectively, including $0.9 billion of cash and cash equivalents and $0.1 billion of restricted cash and cash equivalents.

Schedule I - Condensed Financ_6

Schedule I - Condensed Financial Information of Registrant - Footnotes (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		Jan. 25, 2022	Jun. 03, 2019	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019	Sep. 07, 2021
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				$ 30,406		$ 31,487
Current portion of long-term debt				(117)		(232)
Unamortized premium, discount and debt issuance costs, net				(590)		(644)
Total Long-Term Debt, Net of Discount and Debt Issuance Costs				29,449		30,471
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	[1]			992
2023				1,567
2024				4,794
2025				3,537
2026				1,579
Thereafter				17,937
Total				30,406
Operating lease assets				2,102		759
Current operating lease liabilities				535		161
Non-current operating lease liabilities				1,541		$ 597
Operating Lease, Liability	[2]			2,076
Operating Leases, Future Minimum Payments
2022	[2]			600
2023	[2]			514
2024	[2]			456
2025	[2]			244
2026	[2]			218
Thereafter	[2]			294
Total lease payments	[2]			2,326
Less: Interest	[2]			$ (250)
Weighted-average remaining lease term				5 years 7 months 6 days		8 years 2 months 12 days
Weighted-average discount rate	[3]			3.60%		5.40%
Operating cash flows from operating leases				$ 483		$ 309		$ 389
Right-of-use assets obtained in exchange for operating lease liabilities				1,736		615		235
Total amount paid				9		155		249
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized				$ 1,365		1,395		$ 1,126
Initial Board Approval [Member]
Operating Leases, Future Minimum Payments
Stock Repurchase Program, Period in Force				3 years
Stock Repurchase Program, Authorized Amount				$ 1,000
Subsequent Board Approved Increase [Member]
Operating Leases, Future Minimum Payments
Stock Repurchase Program, Period in Force				3 years
Stock Repurchase Program, Authorized Amount				$ 1,000
Operating lease assets, net [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Operating lease assets				2,102		759
Current operating lease liabilities [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Current operating lease liabilities				535		161
Operating lease liabilities [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Non-current operating lease liabilities				1,541		597
2028 Cheniere Senior Secured Notes [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage				4.625%
2021 Convertible Unsecured Notes [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				$ 0	[4]	476	[5]
Debt Instrument, Interest Rate, Stated Percentage				4.875%
2045 Cheniere Convertible Senior Notes [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount	[6]			$ 625		625	[7]
Unamortized premium, discount and debt issuance costs, net				$ (304)
Debt Instrument, Interest Rate, Stated Percentage				4.25%
Aggregate principal amount				$ 625
Cheniere Revolving Credit Facility [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				0		0
Cheniere Term Loan Facility [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				0		148
Cheniere [Member]
Condensed Financial Statements, Captions [Line Items]
Debt, Long-term and Short-term, Combined Amount				2,625		3,249
Current portion of long-term debt				0		(104)
Unamortized premium, discount and debt issuance costs, net				(340)		(355)
Total Long-Term Debt, Net of Discount and Debt Issuance Costs				2,285		2,790
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	[8]			625
2023				0
2024				0
2025				0
2026				0
Thereafter				2,000
Total				2,625
Guarantor Obligations, Maximum Exposure				472
Guarantor Obligations, Current Carrying Value				0
Operating lease assets				19		22
Current operating lease liabilities				6		5
Non-current operating lease liabilities				24		30
Operating Lease, Liability				30		35
Variable lease costs				4		$ 4
Operating Leases, Future Minimum Payments
2022				8
2023				8
2024				7
2025				6
2026				6
Thereafter				1
Total lease payments				36
Less: Interest				$ (6)
Weighted-average remaining lease term				4 years 9 months 18 days		5 years 8 months 12 days
Weighted-average discount rate				6.60%		6.60%
Operating cash flows from operating leases				$ 7		$ 7
Right-of-use assets obtained in exchange for operating lease liabilities				$ 0		$ 5
Aggregate common stock repurchased				0.1		2.9		4
Weighted average price paid per share				$ 87.32		$ 53.88		$ 62.27
Total amount paid				$ 9		$ 155		$ 249
Stock Repurchase Program, Remaining Authorized Repurchase Amount				$ 998
Common Stock, Dividends, Per Share, Declared				$ 0.33
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized				$ 130		45		36
Non-cash investing and financing activities:
Non-cash capital distribution (contributions)	[9]			$ 0		79		$ 490
Cheniere [Member] \| Subsequent Event [Member]
Operating Leases, Future Minimum Payments
Common Stock, Dividends, Per Share, Declared		$ 0.33
Cheniere [Member] \| Initial Board Approval [Member]
Operating Leases, Future Minimum Payments
Stock Repurchase Program, Period in Force			3 years
Stock Repurchase Program, Authorized Amount			$ 1,000
Cheniere [Member] \| Subsequent Board Approved Increase [Member]
Operating Leases, Future Minimum Payments
Stock Repurchase Program, Period in Force				3 years
Stock Repurchase Program, Authorized Amount									$ 1,000
Cheniere [Member] \| General and Administrative Expense [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Operating lease cost	[10]			$ 9		10
Cheniere [Member] \| Operating lease assets, net [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Operating lease assets				19		22
Cheniere [Member] \| Current operating lease liabilities [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Current operating lease liabilities				6		5
Cheniere [Member] \| Operating lease liabilities [Member]
Long-term Debt, Fiscal Year Maturity [Abstract]
Non-current operating lease liabilities				$ 24		$ 30

[1]	Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Consolidated Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date. See Convertible Notes section below for further discussion of the redemption.
[2]	Does not include approximately $1.2 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of December 31, 2021 but will commence in future periods primarily in the next year and have fixed minimum lease terms of up to 10 years.
[3]	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.
[4]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[5]	A portion of the outstanding balance that is due within one year is classified as current portion of long-term debt.
[6]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 4.25% Convertible Senior Notes due 2045 were classified as long-term debt as of December 31, 2021.
[7]	The redemption of these notes was financed with borrowings under the Cheniere Revolving Credit Facility, which is a long-term debt instrument. Therefore, the 2045 Cheniere Convertible Senior Notes were classified as long-term debt as of December 31, 2021. See Convertible Notes section below for further discussion of the redemption.
[8]	Includes $625 million aggregate principal amount outstanding of the 2045 Cheniere Convertible Senior Notes as we issued a notice of redemption on December 6, 2021 for all amounts outstanding. As discussed above, the balance is classified as long-term debt in our Balance Sheets as the redemption was financed with long-term borrowings subsequent to the balance sheet date.
[9]	Amounts represent undistributed equity income of affiliates.
[10]	Includes $4 million of variable lease costs paid to the lessor during each of the years ended December 31, 2021 and 2020.

Schedule II - Valuation and Q_2

Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current expected credit losses on receivables and contract assets[Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at beginning of period	$ 7	$ 0	$ 30
Charged to cost and expenses	2	7	16
Charged to other accounts	0	0	0
Deductions	0	0	(46)
Balance at end of period	9	7	0
Deferred tax asset valuation allowance [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at beginning of period	190	196	686
Charged to cost and expenses	(127)	(6)	(490)
Charged to other accounts	0	0	0
Deductions	0	0	0
Balance at end of period	$ 63	$ 190	$ 196