Sabine Pass Liquefaction 10-Q 3 May 22 2022 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2022shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	333-192373
Entity Registrant Name	Sabine Pass Liquefaction, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	27-3235920
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	None
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001499200
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
No Trading Symbol Flag	true
Entity Common Stock, Shares Outstanding	0

Statements of Income

Statements of Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Revenues
Revenues	$ 3,245	$ 1,883
Operating costs and expenses
Cost of sales (excluding items shown separately below)	2,561	948
Cost of sales—affiliate	18	52
Operating and maintenance expense	148	130
Operating and maintenance expense—affiliate	117	113
Operating and maintenance expense—related party	12	10
General and administrative expense	1	1
General and administrative expense—affiliate	17	15
Depreciation and amortization expense	130	117
Total operating costs and expenses	3,004	1,386
Income from operations	241	497
Other expense
Interest expense, net of capitalized interest	(156)	(160)
Total other expense	(156)	(160)
Net income	85	337
LNG [Member]
Revenues
Revenues	2,488	1,669
Revenues from contracts with customers	2,488	1,669
LNG—affiliate
Revenues
Revenues from contracts with customers	$ 757	$ 214

Balance Sheets

Balance Sheets - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current assets
Restricted cash and cash equivalents	$ 136	$ 98
Trade and other receivables, net of current expected credit losses	430	571
Accounts receivable—affiliate	289	232
Accounts receivable—related party	0	1
Advances to affiliate	132	127
Inventory	132	159
Current derivative assets	24	21
Other current assets	64	60
Other current assets—affiliate	23	21
Total current assets	1,230	1,290
Property, plant and equipment, net of accumulated depreciation	14,540	14,433
Debt issuance costs, net of accumulated amortization	7	7
Derivative assets	30	33
Other non-current assets, net	172	171
Total assets	15,979	15,934
Current liabilities
Accounts payable	23	18
Accrued liabilities	1,082	1,012
Accrued liabilities—related party	5	4
Due to affiliates	35	73
Deferred revenue	94	132
Current derivative liabilities	256	16
Total current liabilities	1,495	1,255
Long-term debt, net of premium, discount and debt issuance costs	13,029	13,023
Derivative liabilities	2,999	11
Other non-current liabilities	7	7
Other non-current liabilities—affiliate	18	17
Member's equity (deficit)	(1,569)	1,621
Total liabilities and member's equity (deficit)	$ 15,979	$ 15,934

Statements of Member's Equity

Statements of Member's Equity - USD ($) $ in Millions	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2020	$ 958	$ 958
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(310)	(310)
Net income	337	337
Member's equity, end of period at Mar. 31, 2021	985	985
Members' equity, beginning of period at Dec. 31, 2021	1,621	1,621
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-cash distribution	(2,712)	(2,712)
Distributions	(563)	(563)
Net income	85	85
Member's equity, end of period at Mar. 31, 2022	$ (1,569)	$ (1,569)

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cash flows from operating activities
Net income	$ 85	$ 337
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	130	117
Amortization of debt issuance costs, premium and discount	5	6
Total losses on derivatives instruments, net	525	2
Net cash provided by (used for) settlement of derivative instruments	(9)	20
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	83	(60)
Accounts receivable—affiliate	(73)	86
Advances to affiliate	(5)	15
Inventory	26	4
Accounts payable and accrued liabilities	(5)	5
Accrued liabilities—related party	1	(1)
Due to affiliates	(21)	(22)
Deferred revenue	(38)	(35)
Deferred revenue—affiliate	0	5
Other, net	(19)	(4)
Other, net—affiliate	1	0
Net cash provided by operating activities	686	475
Cash flows from investing activities
Property, plant and equipment	(85)	(138)
Net cash used in investing activities	(85)	(138)
Cash flows from financing activities
Debt issuance and other financing costs	0	(1)
Distributions	(563)	(310)
Net cash used in financing activities	(563)	(311)
Net increase in restricted cash and cash equivalents	38	26
Restricted cash and cash equivalents—beginning of period	98	97
Restricted cash and cash equivalents—end of period	$ 136	$ 123

Organization and Nature of Oper

Organization and Nature of Operations	3 Months Ended
	Mar. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We are a Delaware limited liability company formed by CQP. We are a Houston-based company with one member, Sabine Pass LNG-LP, LLC, an indirect wholly owned subsidiary of CQP. We and SPLNG are each indirect wholly owned subsidiaries of Cheniere Investments, which is a wholly owned subsidiary of CQP, a publicly traded limited partnership (NYSE MKT: CQP). CQP is a 48.6% owned subsidiary of Cheniere, a Houston-based energy company primarily engaged in LNG-related businesses. Cheniere also owns 100% of the general partner interest in CQP through ownership in Cheniere Energy Partners GP, LLC. The natural gas liquefaction and export facility in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal”) has six operational Trains, with Train 6 achieving substantial completion on February 4, 2022, for a total production capacity of approximately 30 mtpa of LNG (the “Liquefaction Project”). The Sabine Pass LNG Terminal is located in Cameron Parish, Louisiana, adjacent to the existing regasification facilities owned by SPLNG. Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2021 . Reclassifications that are not material to our Financial Statements, if any, are made to prior period financial information to conform to the current year presentation. We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss is included in the federal income tax return of CQP, a publicly traded partnership which indirectly owns us. CQP is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of CQP’s taxable income. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. Results of operations for the three months ended March 31, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022. Recent Accounting Standards ASU 2020-04 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 debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time the optional expedients are no longer available.

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	3 Months Ended
	Mar. 31, 2022
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTSRestricted cash and cash equivalents consist of funds that are contractually or legally restricted as to usage or withdrawal. As of March 31, 2022 and December 31, 2021, we had $136 million and $98 million of restricted cash and cash equivalents, respectively.Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments.

Trade and Other Receivables, Ne

Trade and Other Receivables, Net of Current Expected Credit Losses	3 Months Ended
	Mar. 31, 2022
Receivables [Abstract]
Trade and Other Receivables, Net of Current Expected Credit Losses	TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES Trade and other receivables, net of current expected credit losses consisted of the following (in millions): March 31, December 31, 2022 2021 Trade receivables $ 411 $ 546 Other receivables 19 25 Total trade and other receivables, net of current expected credit losses $ 430 $ 571

Inventory

Inventory	3 Months Ended
	Mar. 31, 2022
Inventory Disclosure [Abstract]
Inventory	INVENTORY Inventory consisted of the following (in millions): March 31, December 31, 2022 2021 Materials $ 74 $ 71 LNG 32 44 Natural gas 25 43 Other 1 1 Total inventory $ 132 $ 159

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	3 Months Ended
	Mar. 31, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): March 31, December 31, 2022 2021 LNG terminal LNG terminal $ 16,195 $ 13,751 LNG terminal construction-in-process 492 2,699 Accumulated depreciation (2,149) (2,021) Total LNG terminal, net of accumulated depreciation 14,538 14,429 Fixed assets Fixed assets 18 19 Accumulated depreciation (16) (15) Total fixed assets, net of accumulated depreciation 2 4 Property, plant and equipment, net of accumulated depreciation $ 14,540 $ 14,433 The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended March 31, 2022 2021 Depreciation expense $ 129 $ 116 Offsets to LNG terminal costs (1) 148 —

Derivative Instruments

Derivative Instruments	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTSWe have entered into commodity derivatives consisting of natural gas supply contracts, including those under our assigned IPM agreement, for the commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”). 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 Statements of Income 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 (in millions): Fair Value Measurements as of March 31, 2022 December 31, 2021 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 Liquefaction Supply Derivatives asset (liability) $ (26) $ (13) $ (3,162) $ (3,201) $ 2 $ (13) $ 38 $ 27 We value our Liquefaction Supply Derivatives using a market-based approach or option-based approach incorporating present value techniques, as needed, using observable commodity price curves, when available, and other relevant data. The fair value of our Physical Liquefaction Supply Derivatives is 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 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 and volatility. The Level 3 fair value measurements of 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 March 31, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(3,162) Market approach incorporating present value techniques Henry Hub basis spread $(1.578) - $0.215 / $(0.004) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 104% - 459% / 206% (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 Liquefaction Supply Derivatives. The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives (in millions): Three Months Ended March 31, 2022 2021 Balance, beginning of period $ 38 $ (21) Realized and mark-to-market gains losses: Included in cost of sales (53) (12) Purchases and settlements: Purchases (1) (3,141) 1 Settlements (6) (4) Balance, end of period $ (3,162) $ (36) Change in unrealized losses relating to instruments still held at end of period $ (53) $ (12) (1) Includes any assignments during the period. 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. Liquefaction Supply Derivatives We have entered into primarily index-based Liquefaction Supply Derivatives. The remaining minimum terms of the physical natural gas supply contracts range up to 15 years, some of which commence upon the satisfaction of certain conditions precedent. The terms of the Financial Liquefaction Supply Derivatives range up to approximately two years. The forward notional amount for our Liquefaction Supply Derivatives was approximately 5,550 TBtu and 5,194 TBtu as of March 31, 2022 and December 31, 2021, respectively, excluding notional amounts associated with extension options that were uncertain to be taken as of March 31, 2022. Fair Value and Location of Derivative Assets and Liabilities on the Balance Sheets The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheets Location March 31, 2022 December 31, 2021 Current derivative assets $ 24 $ 21 Derivative assets 30 33 Total derivative assets 54 54 Current derivative liabilities (256) (16) Derivative liabilities (2,999) (11) Total derivative liabilities (3,255) (27) Derivative asset (liability), net $ (3,201) $ 27 (1) Does not include collateral posted with counterparties by us of $32 million and $7 million, which are included in other current assets in our Balance Sheets as of March 31, 2022 and December 31, 2021, respectively. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Income (in millions): Loss Recognized in Statements of Income Statements of Income Location (1) Three Months Ended March 31, 2022 2021 Cost of sales $ (525) $ (2) (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. 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. Balance Sheets Presentation Our derivative instruments are presented on a net basis on our Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions): Liquefaction Supply Derivatives As of March 31, 2022 Gross assets $ 74 Offsetting amounts (20) Net assets $ 54 Gross liabilities $ (3,266) Offsetting amounts 11 Net liabilities $ (3,255) As of December 31, 2021 Gross assets $ 79 Offsetting amounts (25) Net assets $ 54 Gross liabilities $ (33) Offsetting amounts 6 Net liabilities $ (27)

Accrued Liabilities

Accrued Liabilities	3 Months Ended
	Mar. 31, 2022
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of the following (in millions): March 31, December 31, 2022 2021 Accrued natural gas purchases $ 692 $ 786 Interest costs and related debt fees 156 133 Liquefaction Project costs 230 89 Other accrued liabilities 4 4 Total accrued liabilities $ 1,082 $ 1,012

Debt

Debt	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Debt	DEBT Our debt consisted of the following (in millions): March 31, December 31, 2022 2021 Senior Secured Notes: 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 1,282 Total Senior Secured Notes 13,132 13,132 $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 Working Capital Facility”) — — Total debt 13,132 13,132 Unamortized premium, discount and debt issuance costs, net (103) (109) Total debt, net of premium, discount and debt issuance costs $ 13,029 $ 13,023 2020 Working Capital Facility Below is a summary of our 2020 Working Capital Facility as of March 31, 2022 (in millions): 2020 Working Capital Facility Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 368 Available commitment $ 832 Priority ranking Senior secured Interest rate on available balance LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% Weighted average interest rate of outstanding balance n/a Commitment fees on undrawn balance 0.20% Maturity date March 19, 2025 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 our ability to make certain investments or pay dividends or distributions. We are restricted from making distributions under agreements governing our 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. As of March 31, 2022, we were in compliance with all covenants related to our debt agreements. Interest Expense Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended March 31, 2022 2021 Total interest cost $ 177 $ 190 Capitalized interest (21) (30) Total interest expense, net of capitalized interest $ 156 $ 160 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): March 31, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 11,850 $ 12,447 $ 11,850 $ 13,128 Senior notes — Level 3 (2) 1,282 1,297 1,282 1,466 (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 interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. The estimated fair value of our 2020 Working Capital Facility approximates the principal amount outstanding 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.

Revenues from Contracts with Cu

Revenues from Contracts with Customers	3 Months Ended
	Mar. 31, 2022
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 (in millions): Three Months Ended March 31, 2022 2021 LNG revenues $ 2,488 $ 1,669 LNG revenues—affiliate 757 214 Total revenues $ 3,245 $ 1,883 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 Balance Sheets (in millions): March 31, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 1 $ 1 The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Balance Sheets (in millions): Three Months Ended March 31, 2022 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 94 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 94 The following table reflects the changes in our contract liabilities, which we classify as other non-current liabilities—affiliate on our Balance Sheets (in millions): Three Months Ended March 31, 2022 Deferred revenue—affiliate, beginning of period $ 2 Cash received but not yet recognized in revenue 3 Revenue recognized from prior period deferral (2) Deferred revenue—affiliate, end of period $ 3 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 March 31, 2022 and December 31, 2021: March 31, 2022 December 31, 2021 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.2 8 $ 49.3 9 LNG revenues—affiliate 2.0 3 2.1 3 Total revenues $ 53.2 $ 51.4 (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. 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 67% and 51% of our LNG revenues from contracts included in the table above during the three months ended March 31, 2022 and 2021, respectively, were related to variable consideration received from customers. 100% of our LNG revenues—affiliate from contracts included in the table above during both the three months ended March 31, 2022 and 2021 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 a final investment decision 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	3 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Statements of Income (in millions): Three Months Ended March 31, 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 745 $ 210 Contracts for Sale and Purchase of Natural Gas and LNG 12 4 Total LNG revenues—affiliate 757 214 Cost of sales—affiliate Cheniere Marketing Agreements — 34 Cargo loading fees under TUA 13 11 Contracts for Sale and Purchase of Natural Gas and LNG 5 7 Total cost of sales—affiliate 18 52 Operating and maintenance expense—affiliate TUA 66 66 Natural Gas Transportation Agreement 20 20 Services Agreements 31 27 Total operating and maintenance expense—affiliate 117 113 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 12 10 General and administrative expense—affiliate Services Agreements 17 15 As of March 31, 2022 and December 31, 2021, we had $289 million and $232 million, respectively, of accounts receivable—affiliate under the agreements described below. LNG Terminal-Related Agreements Terminal Use Agreements We have a TUA with SPLNG to provide berthing for LNG vessels and for the unloading, loading, storage and regasification of LNG. We have reserved approximately 2 Bcf/d of regasification capacity and we are obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million per year (the “TUA Fees”), continuing until at least May 2036. We obtained this reserved capacity as a result of an assignment in July 2012 by Cheniere Investments of its rights, title and interest under its TUA. CQP has guaranteed our obligations under our TUA. Cargo loading fees incurred under the TUA are recorded as cost of sales—affiliate, except for the portion related to commissioning activities which is capitalized as LNG terminal construction-in-process. Cheniere Marketing Agreements Cheniere Marketing SPA Cheniere Marketing has an SPA (“Base SPA”) with us to purchase, at Cheniere Marketing’s option, any LNG produced by us in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG. In May 2019, we and Cheniere Marketing entered into an amendment to the Base SPA to remove certain conditions related to the sale of LNG from Trains 5 and 6 of the Liquefaction Project and provide that cargoes rejected by Cheniere Marketing under the Base SPA can be sold by us to Cheniere Marketing at a contract price equal to a portion of the estimated net profits from the sale of such cargo. Cheniere Marketing Master SPA We have an agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. Cheniere Marketing Letter Agreements Cheniere Marketing has letter agreements with us to purchase up to 306 cargoes to be delivered between 2022 and 2027 at a weighted average price of $1.95 plus 115% of Henry Hub. In December 2020, we and Cheniere Marketing entered into a letter agreement for the sale of up to 30 cargoes that were delivered in 2021 at a price of 115% of Henry Hub plus $0.728 per MMBtu. Facility Swap Agreement In August 2020, we entered into an arrangement with subsidiaries of Cheniere to provide the ability, in limited circumstances, to potentially fulfill commitments to LNG buyers in the event operational conditions impact operations at either the Sabine Pass or Corpus Christi liquefaction facilities. The purchase price for such cargoes would be (i) 115% of the applicable natural gas feedstock purchase price or (ii) a free-on-board U.S. Gulf Coast LNG market price, whichever is greater. Natural Gas Transportation and Storage Agreements To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG Terminal, we have transportation agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of CQP, and third party pipeline companies. These agreements with CTPL have a primary term that continues until 20 years from May 2016 and thereafter continue in effect from year to year until terminated by either party upon written notice of one year or the term of the agreements, whichever is less. In addition, we have the right to elect to extend the term of the agreements for up to two consecutive terms of 10 years. Maximum rates, charges and fees shall be applicable for the entitlements and quantities delivered pursuant to the agreements unless CTPL has advised us that it has agreed otherwise. As of both March 31, 2022 and December 31, 2021, we recorded due to affiliates of $8 million related to this agreement. We are also party to various natural gas transportation and storage agreements with a related party in the ordinary course of business for the operation of the Liquefaction Project, with initial primary terms of up to 10 years with extension rights. This related party is partially owned by the investment management company that indirectly acquired a portion of CQP’s limited partner interests in September 2020. In addition to the amounts recorded on our Statements of Income in the table above, we recorded accrued liabilities—related party of $5 million and $4 million as of March 31, 2022 and December 31, 2021, respectively, with this related party. Services Agreements As of March 31, 2022 and December 31, 2021, we had $132 million and $127 million of advances to affiliates, respectively, under the services agreements described below. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate. Cheniere Investments Information Technology Services Agreement Cheniere Investments has an information technology services agreement with Cheniere, pursuant to which Cheniere Investments’ subsidiaries, including us, receive certain information technology services. On a quarterly basis, the various entities receiving the benefit are invoiced by Cheniere Investments according to the cost allocation percentages set forth in the agreement. In addition, Cheniere is entitled to reimbursement for all costs incurred by Cheniere that are necessary to perform the services under the agreement. Liquefaction O&M Agreement We have an operation and maintenance agreement (the “Liquefaction O&M Agreement”) with Cheniere Investments, a wholly owned subsidiary of CQP, pursuant to which we receive all of the necessary services required to construct, operate and maintain the Liquefaction Project. Before each Train of the Liquefaction Project is operational, the services to be provided include, among other services, obtaining governmental approvals on our behalf, preparing an operating plan for certain periods, obtaining insurance, preparing staffing plans and preparing status reports. After each Train is operational, the services include all necessary services required to operate and maintain the Train. Prior to the substantial completion of each Train of the Liquefaction Project, in addition to reimbursement of operating expenses, we are required to pay a monthly fee equal to 0.6% of the capital expenditures incurred in the previous month. After substantial completion of each Train, for services performed while the Train is operational, we will pay, in addition to the reimbursement of operating expenses, a fixed monthly fee of $83,333 (indexed for inflation) for services with respect to the Train. Liquefaction MSA We have a management services agreement (the “Liquefaction MSA”) with Cheniere Terminals pursuant to which Cheniere Terminals manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the Liquefaction O&M Agreement. The services include, among other services, exercising the day-to-day management of our affairs and business, managing our regulatory matters, managing bank and brokerage accounts and financial books and records of our business and operations, entering into financial derivatives on our behalf and providing contract administration services for all contracts associated with the Liquefaction Project. Prior to the substantial completion of each Train of the Liquefaction Project, we pay a monthly fee equal to 2.4% of the capital expenditures incurred in the previous month. After substantial completion of each Train, we will pay a fixed monthly fee of $541,667 (indexed for inflation) for services with respect to such Train. LNG Site Sublease Agreement We have agreements with SPLNG to sublease a portion of the Sabine Pass LNG Terminal site for the Liquefaction Project. The aggregate annual sublease payment is $1 million. The initial terms of the subleases expire on December 31, 2034, with options to renew for multiple periods of 10 years with similar terms as the initial terms. The annual sublease payments will be adjusted for inflation every five years based on a consumer price index, as defined in the sublease agreements. Cooperation Agreement We have a cooperation agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project. In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. We did not convey any assets to SPLNG under this agreement during the three months ended March 31, 2022 and 2021. Contracts for Sale and Purchase of Natural Gas and LNG We have agreements with SPLNG, CTPL and Corpus Christi Liquefaction, LLC (“CCL”) that allow us to sell and purchase natural gas and LNG with each party. Natural gas purchased under these agreements is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. Natural gas sold under these agreements is recorded as LNG revenues—affiliate. State Tax Sharing Agreement We have a state tax sharing agreement with Cheniere. Under this agreement, Cheniere has agreed to prepare and file all state and local tax returns which we and Cheniere are required to file on a combined basis and to timely pay the combined state and local tax liability. If Cheniere, in its sole discretion, demands payment, we will pay to Cheniere an amount equal to the state and local tax that we would be required to pay if our state and local tax liability were calculated on a separate company

Customer Concentration

Customer Concentration	3 Months Ended
	Mar. 31, 2022
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 trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, 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 Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended March 31, March 31, December 31, 2022 2021 2022 2021 Customer A 29% 28% 32% 29% Customer B 14% 15% 15% * Customer C 18% 19% 15% 14% Customer D 15% 15% 17% 17% Customer E 10% * * 13% Customer F * * * 12% * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2022
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): Three Months Ended March 31, 2022 2021 Cash paid during the period for interest, net of amounts capitalized $ 130 $ 148 Non-cash investing and financing activities: Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate) 386 222 Novation of IPM agreement from Cheniere Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”) (2,712) — Novation of IPM Agreement from CCL Stage III In March 2022, in connection with a prior commitment from Cheniere to collateralize financing for Train 6 of the Liquefaction Project, we and CCL Stage III, a wholly owned subsidiary of Cheniere, entered into an agreement to assign to us an IPM agreement to purchase 140,000 MMBtu per day of natural gas at a price based on the Platts Japan Korea Marker (“JKM”), for a term of approximately 15 years beginning in early 2023. The transaction has been accounted for as a transfer between entities under common control, which required us to recognize the obligations assumed at the historical basis of Cheniere. Upon the transfer, which occurred on March 15, 2022, we recognized $2.7 billion in distributions within our Statements of Member’s Equity (Deficit) based on our assumption of current derivative liabilities and derivative liabilities of $0.1 billion and $2.6 billion, respectively.

Nature of Operations and Basis

Nature of Operations and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2021 . Reclassifications that are not material to our Financial Statements, if any, are made to prior period financial information to conform to the current year presentation.
Income Taxes, Policy	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss is included in the federal income tax return of CQP, a publicly traded partnership which indirectly owns us. CQP is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of CQP’s taxable income. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.
Recent Accounting Standards	Recent Accounting Standards ASU 2020-04 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 debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent applicable contract modifications until December 31, 2022, at which time the optional expedients are no longer available.

Trade and Other Receivables, _2

Trade and Other Receivables, Net of Current Expected Credit Losses (Tables)	3 Months Ended
	Mar. 31, 2022
Receivables [Abstract]
Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses	Trade and other receivables, net of current expected credit losses consisted of the following (in millions): March 31, December 31, 2022 2021 Trade receivables $ 411 $ 546 Other receivables 19 25 Total trade and other receivables, net of current expected credit losses $ 430 $ 571

Inventory (Tables)

Inventory (Tables)	3 Months Ended
	Mar. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consisted of the following (in millions): March 31, December 31, 2022 2021 Materials $ 74 $ 71 LNG 32 44 Natural gas 25 43 Other 1 1 Total inventory $ 132 $ 159

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	3 Months Ended
	Mar. 31, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): March 31, December 31, 2022 2021 LNG terminal LNG terminal $ 16,195 $ 13,751 LNG terminal construction-in-process 492 2,699 Accumulated depreciation (2,149) (2,021) Total LNG terminal, net of accumulated depreciation 14,538 14,429 Fixed assets Fixed assets 18 19 Accumulated depreciation (16) (15) Total fixed assets, net of accumulated depreciation 2 4 Property, plant and equipment, net of accumulated depreciation $ 14,540 $ 14,433
Schedule of Depreciation and Offsets to LNG Terminal Costs	The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended March 31, 2022 2021 Depreciation expense $ 129 $ 116 Offsets to LNG terminal costs (1) 148 —

Derivative Instruments (Tables)

Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 (in millions): Fair Value Measurements as of March 31, 2022 December 31, 2021 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 Liquefaction Supply Derivatives asset (liability) $ (26) $ (13) $ (3,162) $ (3,201) $ 2 $ (13) $ 38 $ 27
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 March 31, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(3,162) Market approach incorporating present value techniques Henry Hub basis spread $(1.578) - $0.215 / $(0.004) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 104% - 459% / 206% (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 Liquefaction Supply Derivatives (in millions): Three Months Ended March 31, 2022 2021 Balance, beginning of period $ 38 $ (21) Realized and mark-to-market gains losses: Included in cost of sales (53) (12) Purchases and settlements: Purchases (1) (3,141) 1 Settlements (6) (4) Balance, end of period $ (3,162) $ (36) Change in unrealized losses relating to instruments still held at end of period $ (53) $ (12) (1) Includes any assignments during the period.
Fair Value of Derivative Instruments by Balance Sheet Location	The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheets Location March 31, 2022 December 31, 2021 Current derivative assets $ 24 $ 21 Derivative assets 30 33 Total derivative assets 54 54 Current derivative liabilities (256) (16) Derivative liabilities (2,999) (11) Total derivative liabilities (3,255) (27) Derivative asset (liability), net $ (3,201) $ 27
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Income (in millions): Loss Recognized in Statements of Income Statements of Income Location (1) Three Months Ended March 31, 2022 2021 Cost of sales $ (525) $ (2)
Derivative Net Presentation on Balance Sheets	The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions): Liquefaction Supply Derivatives As of March 31, 2022 Gross assets $ 74 Offsetting amounts (20) Net assets $ 54 Gross liabilities $ (3,266) Offsetting amounts 11 Net liabilities $ (3,255) As of December 31, 2021 Gross assets $ 79 Offsetting amounts (25) Net assets $ 54 Gross liabilities $ (33) Offsetting amounts 6 Net liabilities $ (27)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2022
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following (in millions): March 31, December 31, 2022 2021 Accrued natural gas purchases $ 692 $ 786 Interest costs and related debt fees 156 133 Liquefaction Project costs 230 89 Other accrued liabilities 4 4 Total accrued liabilities $ 1,082 $ 1,012

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2022
Debt Disclosure [Abstract]
Schedule of Debt Instruments	Our debt consisted of the following (in millions): March 31, December 31, 2022 2021 Senior Secured Notes: 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 1,282 Total Senior Secured Notes 13,132 13,132 $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 Working Capital Facility”) — — Total debt 13,132 13,132 Unamortized premium, discount and debt issuance costs, net (103) (109) Total debt, net of premium, discount and debt issuance costs $ 13,029 $ 13,023
Schedule of Line of Credit Facilities	Below is a summary of our 2020 Working Capital Facility as of March 31, 2022 (in millions): 2020 Working Capital Facility Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 368 Available commitment $ 832 Priority ranking Senior secured Interest rate on available balance LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% Weighted average interest rate of outstanding balance n/a Commitment fees on undrawn balance 0.20% Maturity date March 19, 2025
Schedule of Interest Expense	Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended March 31, 2022 2021 Total interest cost $ 177 $ 190 Capitalized interest (21) (30) Total interest expense, net of capitalized interest $ 156 $ 160
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): March 31, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 11,850 $ 12,447 $ 11,850 $ 13,128 Senior notes — Level 3 (2) 1,282 1,297 1,282 1,466 (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.

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	3 Months Ended
	Mar. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned from contracts with customers (in millions): Three Months Ended March 31, 2022 2021 LNG revenues $ 2,488 $ 1,669 LNG revenues—affiliate 757 214 Total revenues $ 3,245 $ 1,883
Contract with Customer, Asset	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 Balance Sheets (in millions): March 31, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 1 $ 1
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Balance Sheets (in millions): Three Months Ended March 31, 2022 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 94 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 94 The following table reflects the changes in our contract liabilities, which we classify as other non-current liabilities—affiliate on our Balance Sheets (in millions): Three Months Ended March 31, 2022 Deferred revenue—affiliate, beginning of period $ 2 Cash received but not yet recognized in revenue 3 Revenue recognized from prior period deferral (2) Deferred revenue—affiliate, end of period $ 3
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 March 31, 2022 and December 31, 2021: March 31, 2022 December 31, 2021 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.2 8 $ 49.3 9 LNG revenues—affiliate 2.0 3 2.1 3 Total revenues $ 53.2 $ 51.4 (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)	3 Months Ended
	Mar. 31, 2022
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Income (in millions): Three Months Ended March 31, 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 745 $ 210 Contracts for Sale and Purchase of Natural Gas and LNG 12 4 Total LNG revenues—affiliate 757 214 Cost of sales—affiliate Cheniere Marketing Agreements — 34 Cargo loading fees under TUA 13 11 Contracts for Sale and Purchase of Natural Gas and LNG 5 7 Total cost of sales—affiliate 18 52 Operating and maintenance expense—affiliate TUA 66 66 Natural Gas Transportation Agreement 20 20 Services Agreements 31 27 Total operating and maintenance expense—affiliate 117 113 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 12 10 General and administrative expense—affiliate Services Agreements 17 15

Customer Concentration (Tables)

Customer Concentration (Tables)	3 Months Ended
	Mar. 31, 2022
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 trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, 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 Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended March 31, March 31, December 31, 2022 2021 2022 2021 Customer A 29% 28% 32% 29% Customer B 14% 15% 15% * Customer C 18% 19% 15% 14% Customer D 15% 15% 17% 17% Customer E 10% * * 13% Customer F * * * 12% * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2022
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Three Months Ended March 31, 2022 2021 Cash paid during the period for interest, net of amounts capitalized $ 130 $ 148 Non-cash investing and financing activities: Property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate) 386 222 Novation of IPM agreement from Cheniere Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”) (2,712) —

Organization and Nature of Op_2

Organization and Nature of Operations (Details)	3 Months Ended
	Mar. 31, 2022milliontonnes / yrmemberstrains
Nature of Operations and Basis of Presentation [Line Items]
Limited Liability Company (LLC) Number Of Members | members	1
Cheniere Energy Partners, LP | Cheniere [Member]
Nature of Operations and Basis of Presentation [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest	48.60%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	100.00%
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating | trains	6
Total Production Capability | milliontonnes / yr	30

Restricted Cash and Cash Equi_2

Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 136	$ 98
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 136	$ 98

Trade and Other Receivables, _3

Trade and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Receivables [Abstract]
Trade receivables	$ 411	$ 546
Other receivables	19	25
Total trade and other receivables, net of current expected credit losses	$ 430	$ 571

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Inventory [Line Items]
Inventory	$ 132	$ 159
Materials [Member]
Inventory [Line Items]
Inventory	74	71
LNG [Member]
Inventory [Line Items]
Inventory	32	44
Natural gas [Member]
Inventory [Line Items]
Inventory	25	43
Other [Member]
Inventory [Line Items]
Inventory	$ 1	$ 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	Mar. 31, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 14,540	$ 14,433
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(2,149)	(2,021)
Property, plant and equipment, net of accumulated depreciation	14,538	14,429
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16,195	13,751
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	492	2,699
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	18	19
Accumulated depreciation	(16)	(15)
Property, plant and equipment, net of accumulated depreciation	$ 2	$ 4

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		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 129	$ 116
Offsets to LNG terminal costs	[1]	$ 148	$ 0
[1]	We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Project during the testing phase for its construction.

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - tbtu	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	5,550	5,194
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 | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	2 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (3,201)	$ 27
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	(26)	2
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	(13)	(13)
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	$ (3,162)	$ 38

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - USD ($)		3 Months Ended
		Mar. 31, 2022	Dec. 31, 2021
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		$ (3,201,000,000)	$ 27,000,000
Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		(3,162,000,000)	$ 38,000,000
Physical Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		(3,162,000,000)
Physical Liquefaction Supply Derivatives [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	$ (1.578)
Physical Liquefaction Supply Derivatives [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	104.00%
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	$ 0.215
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	459.00%
Physical Liquefaction Supply Derivatives [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation, Market Approach
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	$ (0.004)
Physical Liquefaction Supply Derivatives [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member] | Valuation Technique, Option Pricing Model
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	206.00%
[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 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ 38	$ (21)
Realized and mark-to-market losses:
Included in cost of sales		(53)	(12)
Purchases and settlements:
Purchases	[1]	(3,141)	1
Settlements		(6)	(4)
Balance, end of period		(3,162)	(36)
Change in unrealized losses relating to instruments still held at end of period		$ (53)	$ (12)
[1]	Includes any assignments during the period.

Derivative Instruments - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Mar. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 24	$ 21
Derivative assets		30	33
Total derivative assets	[1]	54	54
Current derivative liabilities		(256)	(16)
Derivative liabilities		(2,999)	(11)
Total derivative liabilities	[1]	(3,255)	(27)
Derivative asset (liability), net	[1]	(3,201)	27
Derivative, collateral posted by us		32	7
Current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	24	21
Derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	30	33
Current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(256)	(16)
Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	$ (2,999)	$ (11)
[1]	Does not include collateral posted with counterparties by us of $32 million and $7 million, which are included in other current assets in our Balance Sheets as of March 31, 2022 and December 31, 2021, respectively.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative loss, net	[1]	$ (525)	$ (2)
[1]	Does not include the realized value associated with derivative instruments that settle through physical delivery. 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.

Derivative Instruments - Deri_2

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Net Amounts Presented in our Balance Sheets	$ (3,201)	$ 27
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	74	79
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(20)	(25)
Net Amounts Presented in our Balance Sheets	54	54
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(3,266)	(33)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	11	6
Net Amounts Presented in our Balance Sheets	$ (3,255)	$ (27)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Accrued Liabilities, Current [Abstract]
Accrued natural gas purchases	$ 692	$ 786
Interest costs and related debt fees	156	133
Liquefaction Project costs	230	89
Other accrued liabilities	4	4
Total accrued liabilities	$ 1,082	$ 1,012

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 13,132	$ 13,132
Unamortized premium, discount and debt issuance costs, net	(103)	(109)
Total debt, net of premium, discount and debt issuance costs	13,029	13,023
Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	13,132	13,132
2023 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage	5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage	5.00%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,350	1,350
Debt Instrument, Interest Rate, Stated Percentage	4.20%
2030 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 1,282	1,282
2037 Senior Notes [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.27%
2020 Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$ 0	$ 0
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,200

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022USD ($)unitRate	Dec. 31, 2021USD ($)
Line of Credit Facility [Line Items]
Outstanding balance	$ 13,132	$ 13,132
Debt, Minimum Historical Debt Service Coverage Ratio And Projected Debt Service Coverage Ratio | unit	1.25
2020 Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	$ 1,200
Outstanding balance	0	$ 0
Letters of credit issued	368
Available commitment	$ 832
Debt Instrument, Description of Variable Rate Basis	LIBOR or base rate
Line of Credit Facility, Commitment Fee Percentage	0.20%
Debt Instrument, Maturity Date	Mar. 19, 2025
2020 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 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 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 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%

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Debt Disclosure [Abstract]
Total interest cost	$ 177	$ 190
Capitalized interest	(21)	(30)
Total interest expense, net of capitalized interest	$ 156	$ 160

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - Senior Notes [Member] - USD ($) $ in Millions		Mar. 31, 2022	Dec. 31, 2021
Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	$ 11,850	$ 11,850
Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	1,282	1,282
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]	12,447	13,128
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]	$ 1,297	$ 1,466
[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 interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.

Revenues from Contracts with _3

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Revenues	$ 3,245	$ 1,883
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,488	1,669
Revenues	2,488	1,669
LNG—affiliate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 757	$ 214

Revenues from Contracts with _4

Revenues from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 1	$ 1
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	132
Cash received but not yet recognized in revenue	94
Revenue recognized from prior period deferral	(132)
Deferred revenue, end of period	94
Deferred revenue, beginning of period	2
Cash received but not yet recognized in revenue	3
Revenue recognized from prior period deferral	(2)
Deferred revenue, end of period	$ 3

Revenues from Contracts with _5

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		3 Months Ended
		Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
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				$ 51.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 53.2
LNG [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		67.00%	51.00%
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				$ 49.3
Weighted Average Recognition Timing	[1]			9 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 51.2
Weighted Average Recognition Timing	[1]	8 years
LNG—affiliate
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		100.00%	100.00%
LNG—affiliate | 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				$ 2.1
Weighted Average Recognition Timing	[1]			3 years
LNG—affiliate | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 2
Weighted Average Recognition Timing	[1]	3 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 - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 757	$ 214
Cost of sales—affiliate	18	52
Operating and maintenance expense—affiliate	117	113
Operating and maintenance expense—related party	12	10
General and administrative expense—affiliate	17	15
Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	745	210
Cost of sales—affiliate	0	34
Contracts for Sale and Purchase of Natural Gas And LNG [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	12	4
Cost of sales—affiliate	5	7
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	13	11
Operating and maintenance expense—affiliate	66	66
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	20	20
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—related party	12	10
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	31	27
General and administrative expense—affiliate	$ 17	$ 15

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	3 Months Ended
	Mar. 31, 2022USD ($)bcf / dCargoitem	Dec. 31, 2021USD ($)
Related Party Transaction [Line Items]
Accounts receivable—affiliate	$ 289,000,000	$ 232,000,000
Due to affiliates	35,000,000	73,000,000
Accrued liabilities—related party	5,000,000	4,000,000
Advances to affiliate	$ 132,000,000	127,000,000
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term	10 years
Accrued liabilities—related party	$ 5,000,000	4,000,000
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate	$ 132,000,000	127,000,000
Affiliated Entity [Member] | Facility Swap Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
SPLNG [Member] | Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d	2
Related Party Transaction, Committed Annual Fee	$ 250,000,000
SPLNG [Member] | LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment	$ 1,000,000
Term of available extension	10 years
Review Period for Inflation Adjustment	5 years
SPLNG [Member] | Cooperation Agreement [Member]
Related Party Transaction [Line Items]
Assets conveyed under the agreement	$ 0
Cheniere Investments [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	0.60%
Related Party Transaction, Committed Monthly Fee	$ 83,333
Cheniere Marketing [Member] | Cheniere Marketing SPA [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
LNG Volume, Purchase Price	$ 3
Cheniere Marketing [Member] | 2022-2027 Letter Agreement
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
LNG Volume, Weighted Average Purchase Price Per MMBtu	$ 1.95
Cheniere Marketing [Member] | 2022-2027 Letter Agreement | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	306
Cheniere Marketing [Member] | 2021 Letter Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115.00%
LNG Volume, Purchase Price	$ 0.728
Cheniere Marketing [Member] | 2021 Letter Agreement [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	30
Cheniere Terminals [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Monthly fee as a percentage of capital expenditures incurred in the previous month	2.40%
Related Party Transaction, Committed Monthly Fee	$ 541,667
Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net	$ 0
CTPL [Member] | Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term	20 years
Related Party Agreement, Termination Notice Period	1 year
Related Party Agreement, Number Of Available Extensions | item	2
Related Party Agreement, Term Of Available Extension	10 years
Due to affiliates	$ 8,000,000	$ 8,000,000

Customer Concentration - Schedu

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	3 Months Ended		12 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	29.00%	28.00%
Customer A [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	32.00%		29.00%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	14.00%	15.00%
Customer B [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15.00%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	18.00%	19.00%
Customer C [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15.00%		14.00%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15.00%	15.00%
Customer D [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	17.00%		17.00%
Customer E [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	10.00%
Customer E [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			13.00%
Customer F [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			12.00%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($)	Mar. 15, 2022	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized		$ 130,000,000	$ 148,000,000
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate)		386,000,000	222,000,000
Novation of IPM agreement from Cheniere Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”)		(2,712,000,000)	$ 0
Nonmonetary Transaction [Line Items]
Partners Capital Account Distributions, Non-Cash		2,712,000,000
Current derivative liabilities		256,000,000		$ 16,000,000
Derivative liabilities		$ 2,999,000,000		$ 11,000,000
Novation of IPM Agreement | Cheniere Corpus Christi Liquefaction Stage III
Nonmonetary Transaction [Line Items]
Contract Volume		140,000
IPM Agreement, Term of Agreement		15 years
Partners Capital Account Distributions, Non-Cash	$ 2,700,000,000
Current derivative liabilities	100,000,000
Derivative liabilities	$ 2,600,000,000