Sabine Pass Liquefaction 10-Q 4 Nov 21 2021 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2021shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
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	2021
Document Fiscal Period Focus	Q3
No Trading Symbol Flag	true
Entity Common Stock, Shares Outstanding	0

Statements of Income

Statements of Income - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenues
Revenues		$ 2,244	$ 910	$ 5,935	$ 3,940
Revenues from contracts with customers		2,244	903	5,935	3,937
Operating costs and expenses
Cost of sales (excluding items shown separately below)		1,342	454	3,178	1,551
Cost of sales—affiliate		17	37	93	60
Cost of sales—related party		0	0	1	0
Operating and maintenance expense		130	124	404	405
Operating and maintenance expense—affiliate		113	114	341	352
Operating and maintenance expense—related party		12	0	34	0
General and administrative expense		1	1	3	8
General and administrative expense—affiliate		16	17	45	54
Depreciation and amortization expense		118	115	351	348
Impairment expense and loss on disposal of assets		0	0	2	0
Total operating costs and expenses		1,749	862	4,452	2,778
Income from operations		495	48	1,483	1,162
Other income (expense)
Interest expense, net of capitalized interest		(155)	(164)	(473)	(523)
Loss on modification of debt		0	0	0	(43)
Other income, net		0	0	0	1
Total other expense		(155)	(164)	(473)	(565)
Net income (loss)		340	(116)	1,010	597
LNG [Member]
Revenues
Revenues		1,791	807	5,057	3,588
Revenues from contracts with customers	[1]	1,791	800	5,057	3,585
LNG—affiliate [Member]
Revenues
Revenues from contracts with customers		$ 453	$ 103	$ 878	$ 352
[1]	LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $109 million and $513 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $21 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $244 million that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

Balance Sheets

Balance Sheets - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Current assets
Restricted cash	$ 133	$ 97
Accounts and other receivables, net of current expected credit losses	352	309
Accounts receivable—affiliate	198	185
Advances to affiliate	114	122
Inventory	118	93
Current derivative assets	44	14
Other current assets	73	41
Other current assets—affiliate	22	21
Total current assets	1,054	882
Property, plant and equipment, net of accumulated depreciation	14,404	14,255
Debt issuance costs, net of accumulated amortization	8	10
Derivative assets	25	11
Other non-current assets, net	168	165
Total assets	15,659	15,323
Current liabilities
Accounts payable	10	8
Accrued liabilities	761	591
Accrued liabilities—related party	5	4
Current debt, net of discount and debt issuance costs	203	0
Due to affiliates	48	59
Deferred revenue	144	114
Deferred revenue—affiliate	4	0
Current derivative liabilities	23	11
Total current liabilities	1,198	787
Long-term debt, net of premium, discount and debt issuance costs	13,336	13,520
Derivative liabilities	13	35
Other non-current liabilities	8	8
Other non-current liabilities—affiliate	15	15
Member’s equity	1,089	958
Total liabilities and member’s equity	$ 15,659	$ 15,323

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, 2019	$ 534	$ 534
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions	226	226
Distributions	(376)	(376)
Net income (loss)	360	360
Member's equity, end of period at Mar. 31, 2020	744	744
Members' equity, beginning of period at Dec. 31, 2019	534	534
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	597
Member's equity, end of period at Sep. 30, 2020	907	907
Members' equity, beginning of period at Mar. 31, 2020	744	744
Increase (Decrease) in Partners' Capital [Roll Forward]
Capital contributions	261	261
Distributions	(200)	(200)
Net income (loss)	353	353
Member's equity, end of period at Jun. 30, 2020	1,158	1,158
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(135)	(135)
Net income (loss)	(116)	(116)
Member's equity, end of period at Sep. 30, 2020	907	907
Members' equity, beginning of period at Dec. 31, 2020	958	958
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(310)	(310)
Net income (loss)	337	337
Member's equity, end of period at Mar. 31, 2021	985	985
Members' equity, beginning of period at Dec. 31, 2020	958	958
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	1,010
Member's equity, end of period at Sep. 30, 2021	1,089	1,089
Members' equity, beginning of period at Mar. 31, 2021	985	985
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(328)	(328)
Net income (loss)	333	333
Member's equity, end of period at Jun. 30, 2021	990	990
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(241)	(241)
Net income (loss)	340	340
Member's equity, end of period at Sep. 30, 2021	$ 1,089	$ 1,089

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Cash flows from operating activities
Net income	$ 1,010	$ 597
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	351	348
Amortization of debt issuance costs, premium and discount	17	19
Loss on modification of debt	0	43
Total losses (gains) on derivatives, net	(64)	38
Net cash provided by (used for) settlement of derivative instruments	10	(2)
Impairment expense and loss on disposal of assets	2	0
Changes in operating assets and liabilities:
Accounts and other receivables, net of current expected credit losses	(42)	95
Accounts receivable—affiliate	(14)	22
Advances to affiliate	6	28
Inventory	(25)	2
Accounts payable and accrued liabilities	147	(166)
Accrued liabilities—related party	1	2
Due to affiliates	(10)	(3)
Deferred revenue	30	26
Deferred revenue—affiliate	4	0
Other, net	(42)	(29)
Net cash provided by operating activities	1,381	1,020
Cash flows from investing activities
Property, plant and equipment	(465)	(747)
Net cash used in investing activities	(465)	(747)
Cash flows from financing activities
Proceeds from issuances of debt	0	1,995
Repayments of Debt	0	(2,000)
Debt issuance and other financing costs	(1)	(34)
Debt extinguishment costs	0	(39)
Capital contributions	0	487
Distributions	(879)	(706)
Net cash used in financing activities	(880)	(297)
Net increase (decrease) in restricted cash	36	(24)
Restricted cash—beginning of period	97	181
Restricted cash—end of period	$ 133	$ 157

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION The Sabine Pass LNG terminal currently has five operational natural gas liquefaction Trains and one additional Train that is undergoing commissioning and expected to be substantially completed in the first quarter of 2022, for a total production capacity of approximately 30 mtpa of LNG (the “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 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, 2020 . 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 Cheniere Partners, a publicly traded partnership which indirectly owns us. Cheniere Partners is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of Cheniere Partners 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 and nine months ended September 30, 2021 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2021. Recent Accounting Standards In March 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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

Restricted Cash	9 Months Ended
	Sep. 30, 2021
Restricted Cash [Abstract]
Restricted Cash	RESTRICTED CASHRestricted cash consists of funds that are contractually or legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Balance Sheets. As of September 30, 2021 and December 31, 2020, we had $133 million and $97 million of restricted cash, 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.

Accounts and Other Receivables,

Accounts and Other Receivables, Net of Current Expected Credit Losses	9 Months Ended
	Sep. 30, 2021
Receivables [Abstract]
Accounts and Other Receivables, Net of Current Expected Credit Losses	ACCOUNTS AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES As of September 30, 2021 and December 31, 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2021 2020 Trade receivable $ 338 $ 300 Other accounts receivable 14 9 Total accounts and other receivables, net of current expected credit losses $ 352 $ 309

Inventory

Inventory	9 Months Ended
	Sep. 30, 2021
Inventory Disclosure [Abstract]
Inventory	INVENTORY As of September 30, 2021 and December 31, 2020, inventory consisted of the following (in millions): September 30, December 31, 2021 2020 Materials $ 68 $ 68 LNG 33 8 Natural gas 16 17 Other 1 — Total inventory $ 118 $ 93

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	9 Months Ended
	Sep. 30, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION As of September 30, 2021 and December 31, 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2021 2020 LNG terminal LNG terminal $ 13,742 $ 13,711 LNG terminal construction-in-process 2,564 2,100 Accumulated depreciation (1,906) (1,561) Total LNG terminal, net of accumulated depreciation 14,400 14,250 Fixed assets Fixed assets 19 19 Accumulated depreciation (15) (14) Total fixed assets, net of accumulated depreciation 4 5 Property, plant and equipment, net of accumulated depreciation $ 14,404 $ 14,255 The following table shows depreciation expense during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Depreciation expense $ 116 $ 114 $ 347 $ 345

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into commodity derivatives consisting of natural gas supply contracts 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 Operations to the extent not utilized for the commissioning process, in which case it is capitalized. The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 (in millions): Fair Value Measurements as of September 30, 2021 December 31, 2020 Quoted Prices in Active Markets 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) $ (18) $ (8) $ 59 $ 33 $ 1 $ (1) $ (21) $ (21) We value our Liquefaction Supply Derivatives using a market-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 evaluating whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of September 30, 2021 and December 31, 2020, some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow. We include 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 natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2021: Net Fair Value Asset Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $59 Market approach incorporating present value techniques Henry Hub basis spread $(1.333) - $0.415 / $0.015 (1) Unobservable inputs were weighted by the relative fair value of the instruments. Increases or decreases in basis, 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 during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Balance, beginning of period $ 33 $ 51 $ (21) $ 24 Realized and mark-to-market gains (losses): Included in cost of sales 25 (47) 79 (22) Purchases and settlements: Purchases 4 5 6 4 Settlements (3) (8) (5) (6) Transfers out of Level 3, net (1) — (1) — — Balance, end of period $ 59 $ — $ 59 $ — Change in unrealized gains (losses) relating to instruments still held at end of period $ 25 $ (47) $ 79 $ (22) (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. Liquefaction Supply Derivatives We have entered into primarily index-based physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the Liquefaction Project. The remaining terms of the physical natural gas supply contracts range up to 10 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. The notional natural gas position of our Liquefaction Supply Derivatives was approximately 5,135 TBtu and 4,970 TBtu as of September 30, 2021 and December 31, 2020, respectively, of which 99 TBtu and 91 TBtu, respectively, were for a natural gas supply contract that we have with a related party. 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 September 30, 2021 December 31, 2020 Current derivative assets $ 44 $ 14 Derivative assets 25 11 Total derivative assets 69 25 Current derivative liabilities (23) (11) Derivative liabilities (13) (35) Total derivative liabilities (36) (46) Derivative asset (liability), net $ 33 $ (21) (1) Does not include collateral posted with counterparties by us of $29 million and $4 million, which are included in other current assets in our Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes a natural gas supply contract that we have with a related party, which had a fair value of zero as of both September 30, 2021 and December 31, 2020. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions): Gain (Loss) Recognized in Statements of Operations Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues $ — $ 7 $ — $ 3 Cost of sales 10 (74) 64 (41) (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 September 30, 2021 Gross assets $ 76 Offsetting amounts (7) Net assets $ 69 Gross liabilities $ (43) Offsetting amounts 7 Net liabilities $ (36) As of December 31, 2020 Gross assets $ 69 Offsetting amounts (44) Net assets $ 25 Gross liabilities $ (48) Offsetting amounts 2 Net liabilities $ (46)

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2021
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES As of September 30, 2021 and December 31, 2020, accrued liabilities consisted of the following (in millions): September 30, December 31, 2021 2020 Interest costs and related debt fees $ 158 $ 150 Accrued natural gas purchases 523 374 Liquefaction Project costs 77 64 Other accrued liabilities 3 3 Total accrued liabilities $ 761 $ 591

Debt

Debt	9 Months Ended
	Sep. 30, 2021
Debt Disclosure [Abstract]
Debt	DEBT As of September 30, 2021 and December 31, 2020, our debt consisted of the following (in millions): September 30, December 31, 2021 2020 Long-term debt: 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 Working Capital Facility”) (1) $ 13,446 $ 13,650 Unamortized premium, discount and debt issuance costs, net of accumulated amortization (110) (130) Total long-term debt, net of premium, discount and debt issuance costs 13,336 13,520 Current debt: Current portion of 6.25% senior secured notes due March 2022 (the “2022 Senior Notes”) (1) 204 — Unamortized discount and debt issuance costs, net of accumulated amortization (1) — Total current debt, net of discount and debt issuance costs 203 — Total debt, net of premium, discount and debt issuance costs $ 13,539 $ 13,520 (1) A portion of the 2022 Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 Senior Notes and pay related fees, costs and expenses. An additional $318 million of the 2022 Senior Notes was redeemed in October 2021 with capital contributions received from Cheniere Partners subsequent to the balance sheet date, and thus is also categorized as long-term debt. 2020 Working Capital Facility Below is a summary of our 2020 Working Capital Facility as of September 30, 2021 (in millions): 2020 Working Capital Facility (1) Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 396 Available commitment $ 804 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 Maturity date March 19, 2025 (1) The 2020 Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. We pay a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on our then-current rating), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans. 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. As of September 30, 2021, 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 September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Total interest cost $ 189 $ 189 $ 569 $ 589 Capitalized interest (34) (25) (96) (66) Total interest expense, net of capitalized interest $ 155 $ 164 $ 473 $ 523 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 12,850 $ 14,409 $ 12,850 $ 14,834 Senior notes — Level 3 (2) 800 997 800 1,036 Working capital facility — Level 3 (3) — — — — (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 Cu

Revenues from Contracts with Customers	9 Months Ended
	Sep. 30, 2021
Revenue from Contract with Customer [Abstract]
Revenues from Contracts with Customers	REVENUES FROM CONTRACTS WITH CUSTOMERS The following table represents a disaggregation of revenue earned from contracts with customers during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues (1) $ 1,791 $ 800 $ 5,057 $ 3,585 LNG revenues—affiliate 453 103 878 352 Total revenues from customers 2,244 903 5,935 3,937 Net derivative loss (2) — 7 — 3 Total revenues $ 2,244 $ 910 $ 5,935 $ 3,940 (1) LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $109 million and $513 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $21 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $244 million that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied. (2) See Note 6—Derivative Instruments for additional information about our derivatives. 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 Balance Sheets (in millions): September 30, December 31, 2021 2020 Contract assets, net of current expected credit losses $ 1 $ — Contract assets represent our right to consideration for transferring goods or services to the customer under the terms of a sales contract when the associated consideration is not yet due. Changes in contract assets during the nine months ended September 30, 2021 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due. Deferred Revenue Reconciliation The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Balance Sheets (in millions): Nine Months Ended September 30, 2021 Deferred revenue, beginning of period $ 114 Cash received but not yet recognized in revenue 144 Revenue recognized from prior period deferral (114) Deferred revenue, end of period $ 144 The following table reflects the changes in our contract liabilities to affiliate, which we classify as deferred revenue—affiliate on our Balance Sheets (in millions): Nine Months Ended September 30, 2021 Deferred revenue—affiliate, beginning of period $ — Cash received but not yet recognized in revenue 4 Deferred revenue—affiliate, end of period $ 4 Transaction Price Allocated to Future Performance Obligations Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of September 30, 2021 and December 31, 2020: September 30, 2021 December 31, 2020 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 50.1 9 $ 52.1 9 LNG revenues—affiliate 0.7 3 0.1 1 Total revenues $ 50.8 $ 52.2 (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 63% and 39% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2021 and 2020, respectively, and approximately 56% and 37% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2021 and 2020, respectively, were related to variable consideration received from customers. Approximately 96% and 94% of our LNG revenues—affiliate from contracts included in the table above during the three and nine months ended September 30, 2021, respectively, and 100% of our LNG revenues—affiliate from contracts included in the table above during each of the three and nine months ended September 30, 2020 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	9 Months Ended
	Sep. 30, 2021
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 Operations during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues—affiliate Cheniere Marketing Agreements $ 441 $ 87 $ 860 $ 328 Contracts for Sale and Purchase of Natural Gas and LNG 12 16 18 24 Total LNG revenues—affiliate 453 103 878 352 Cost of sales—affiliate Cheniere Marketing Agreements — 32 34 32 Cargo loading fees under TUA 10 5 32 23 Contracts for Sale and Purchase of Natural Gas and LNG 7 — 27 5 Total cost of sales—affiliate 17 37 93 60 Cost of sales—related party Natural Gas Transportation and Storage Agreements — — 1 — Operating and maintenance expense—affiliate TUA 66 67 199 200 Natural Gas Transportation Agreement 21 20 61 61 Services Agreements 26 27 80 90 LNG Site Sublease Agreement — — 1 1 Total operating and maintenance expense—affiliate 113 114 341 352 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 12 — 34 — General and administrative expense—affiliate Services Agreements 16 17 45 54 As of September 30, 2021 and December 31, 2020, we had $198 million and $185 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. Cheniere Partners 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. We executed a confirmation with Cheniere Marketing that obligated Cheniere Marketing in certain circumstances to buy LNG cargoes produced during the period while Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) had control of, and was commissioning, Train 5 of the Liquefaction Project. Cheniere Marketing Letter Agreements In August 2021, we and Cheniere Marketing entered into a letter agreement (amending and restating the previous letter agreement between the parties from February 2021) for the sale of up to 81 cargoes to be delivered between 2021 and 2027 at a price equal to 115% of Henry Hub plus $1.96 per MMBtu. Additionally, we and Cheniere Marketing entered into a letter agreement for the sale of (1) up to six cargoes to be delivered in 2022 and up to six cargoes to be delivered in 2023 at a price equal to 115% of Henry Hub plus $1.768 per MMBtu; and (2) up to six cargoes to be delivered in 2022 at a price equal to 115% of Henry Hub plus $1.952 per MMBtu. In December 2020, we and Cheniere Marketing entered into a letter agreement for the sale of up to 30 cargoes scheduled for delivery in 2021 at a price of 115% of Henry Hub plus $0.728 per MMBtu. In December 2019, we and Cheniere Marketing entered into a letter agreement for the sale of up to 43 cargoes that were delivered in 2020 at a price of 115% of Henry Hub plus $1.67 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 Cheniere Partners, 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 September 30, 2021 and December 31, 2020, we recorded due to affiliates of $7 million and $6 million, respectively, 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 Cheniere Partners’ limited partner interests in September 2020. We recorded operating and maintenance expense—related party of $12 million and $34 million and cost of sales—related party of zero and $1 million during the three and nine months ended September 30, 2021, respectively, and accrued liabilities—related party of $5 million and $4 million as of September 30, 2021 and December 31, 2020, respectively, with this related party. Services Agreements As of September 30, 2021 and December 31, 2020, we had $114 million and $122 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 Cheniere Partners, 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. Natural Gas Supply Agreement We are a 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 Liquefaction Project. This related party is partially owned by Blackstone, who also partially owns Cheniere Partners’ limited partner interests. The term of the agreement is for five years, which can commence no earlier than November 1, 2021 and no later than November 1, 2022, following the achievement of contractually-defined conditions precedent. 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 conveyed $5 million in assets to SPLNG under this agreement during the nine months ended September 30, 2020. We did not convey any assets to SPLNG under this agreement during the three and nine months ended September 30, 2021 and the three months ended September 30, 2020. Contracts for Sale and Purchase of Natural Gas and LNG We have agreements with SPLNG, CTPL and 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 basis. There have been no state and local taxes paid by Cheniere and Cheniere has not demanded any such payments from us under the agreement. The agreement is effective for tax returns due on or after August 2012.

Customer Concentration

Customer Concentration	9 Months Ended
	Sep. 30, 2021
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with accounts receivable, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total accounts receivable, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2021 2020 2021 2020 2021 2020 Customer A 21% * 25% 23% 27% 32% Customer B 17% 15% 16% 16% 18% 21% Customer C 19% 28% 18% 19% 18% * Customer D 20% 24% 18% 19% 17% 22% Customer E * * * 10% * * * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2021
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table provides supplemental disclosure of cash flow information (in millions): Nine Months Ended September 30, 2021 2020 Cash paid during the period for interest, net of amounts capitalized $ 451 $ 527 Non-cash distributions to affiliates for conveyance of assets — 5 The balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate) was $228 million and $217 million as of September 30, 2021 and 2020, respectively.

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2020 .
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 Cheniere Partners, a publicly traded partnership which indirectly owns us. Cheniere Partners is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of Cheniere Partners 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 In March 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“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.

Accounts and Other Receivable_2

Accounts and Other Receivables, Net of Current Expected Credit Losses (Tables)	9 Months Ended
	Sep. 30, 2021
Receivables [Abstract]
Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses	As of September 30, 2021 and December 31, 2020, accounts and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2021 2020 Trade receivable $ 338 $ 300 Other accounts receivable 14 9 Total accounts and other receivables, net of current expected credit losses $ 352 $ 309

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2021
Inventory Disclosure [Abstract]
Schedule of Inventory	As of September 30, 2021 and December 31, 2020, inventory consisted of the following (in millions): September 30, December 31, 2021 2020 Materials $ 68 $ 68 LNG 33 8 Natural gas 16 17 Other 1 — Total inventory $ 118 $ 93

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	9 Months Ended
	Sep. 30, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	As of September 30, 2021 and December 31, 2020, property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2021 2020 LNG terminal LNG terminal $ 13,742 $ 13,711 LNG terminal construction-in-process 2,564 2,100 Accumulated depreciation (1,906) (1,561) Total LNG terminal, net of accumulated depreciation 14,400 14,250 Fixed assets Fixed assets 19 19 Accumulated depreciation (15) (14) Total fixed assets, net of accumulated depreciation 4 5 Property, plant and equipment, net of accumulated depreciation $ 14,404 $ 14,255
Schedule of Depreciation and Offsets to LNG Terminal Costs	The following table shows depreciation expense during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Depreciation expense $ 116 $ 114 $ 347 $ 345

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2021
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 as of September 30, 2021 and December 31, 2020 (in millions): Fair Value Measurements as of September 30, 2021 December 31, 2020 Quoted Prices in Active Markets 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) $ (18) $ (8) $ 59 $ 33 $ 1 $ (1) $ (21) $ (21)
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 September 30, 2021: Net Fair Value Asset Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $59 Market approach incorporating present value techniques Henry Hub basis spread $(1.333) - $0.415 / $0.015 (1) Unobservable inputs were weighted by the relative fair value of the instruments.
Fair Value, Assets 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 during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Balance, beginning of period $ 33 $ 51 $ (21) $ 24 Realized and mark-to-market gains (losses): Included in cost of sales 25 (47) 79 (22) Purchases and settlements: Purchases 4 5 6 4 Settlements (3) (8) (5) (6) Transfers out of Level 3, net (1) — (1) — — Balance, end of period $ 59 $ — $ 59 $ — Change in unrealized gains (losses) relating to instruments still held at end of period $ 25 $ (47) $ 79 $ (22) (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 Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheets Location September 30, 2021 December 31, 2020 Current derivative assets $ 44 $ 14 Derivative assets 25 11 Total derivative assets 69 25 Current derivative liabilities (23) (11) Derivative liabilities (13) (35) Total derivative liabilities (36) (46) Derivative asset (liability), net $ 33 $ (21) (1) Does not include collateral posted with counterparties by us of $29 million and $4 million, which are included in other current assets in our Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes a natural gas supply contract that we have with a related party, which had a fair value of zero as of both September 30, 2021 and December 31, 2020.
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions): Gain (Loss) Recognized in Statements of Operations Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues $ — $ 7 $ — $ 3 Cost of sales 10 (74) 64 (41)
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 September 30, 2021 Gross assets $ 76 Offsetting amounts (7) Net assets $ 69 Gross liabilities $ (43) Offsetting amounts 7 Net liabilities $ (36) As of December 31, 2020 Gross assets $ 69 Offsetting amounts (44) Net assets $ 25 Gross liabilities $ (48) Offsetting amounts 2 Net liabilities $ (46)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2021
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	As of September 30, 2021 and December 31, 2020, accrued liabilities consisted of the following (in millions): September 30, December 31, 2021 2020 Interest costs and related debt fees $ 158 $ 150 Accrued natural gas purchases 523 374 Liquefaction Project costs 77 64 Other accrued liabilities 3 3 Total accrued liabilities $ 761 $ 591

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2021
Debt Disclosure [Abstract]
Schedule of Debt Instruments	As of September 30, 2021 and December 31, 2020, our debt consisted of the following (in millions): September 30, December 31, 2021 2020 Long-term debt: 4.200% to 6.25% senior secured notes due between March 2022 and September 2037 and working capital facility (“2020 Working Capital Facility”) (1) $ 13,446 $ 13,650 Unamortized premium, discount and debt issuance costs, net of accumulated amortization (110) (130) Total long-term debt, net of premium, discount and debt issuance costs 13,336 13,520 Current debt: Current portion of 6.25% senior secured notes due March 2022 (the “2022 Senior Notes”) (1) 204 — Unamortized discount and debt issuance costs, net of accumulated amortization (1) — Total current debt, net of discount and debt issuance costs 203 — Total debt, net of premium, discount and debt issuance costs $ 13,539 $ 13,520 (1) A portion of the 2022 Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 Senior Notes and pay related fees, costs and expenses. An additional $318 million of the 2022 Senior Notes was redeemed in October 2021 with capital contributions received from Cheniere Partners subsequent to the balance sheet date, and thus is also categorized as long-term debt.
Schedule of Line of Credit Facilities	Below is a summary of our 2020 Working Capital Facility as of September 30, 2021 (in millions): 2020 Working Capital Facility (1) Original facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 396 Available commitment $ 804 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 Maturity date March 19, 2025 (1) The 2020 Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. We pay a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on our then-current rating), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.
Schedule of Interest Expense	Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 Total interest cost $ 189 $ 189 $ 569 $ 589 Capitalized interest (34) (25) (96) (66) Total interest expense, net of capitalized interest $ 155 $ 164 $ 473 $ 523
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2021 December 31, 2020 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 12,850 $ 14,409 $ 12,850 $ 14,834 Senior notes — Level 3 (2) 800 997 800 1,036 Working capital facility — Level 3 (3) — — — — (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 _2

Revenues from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2021
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned from contracts with customers during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues (1) $ 1,791 $ 800 $ 5,057 $ 3,585 LNG revenues—affiliate 453 103 878 352 Total revenues from customers 2,244 903 5,935 3,937 Net derivative loss (2) — 7 — 3 Total revenues $ 2,244 $ 910 $ 5,935 $ 3,940 (1) LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $109 million and $513 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $21 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $244 million that would (2) See Note 6—Derivative Instruments
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): September 30, December 31, 2021 2020 Contract assets, net of current expected credit losses $ 1 $ —
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Balance Sheets (in millions): Nine Months Ended September 30, 2021 Deferred revenue, beginning of period $ 114 Cash received but not yet recognized in revenue 144 Revenue recognized from prior period deferral (114) Deferred revenue, end of period $ 144 The following table reflects the changes in our contract liabilities to affiliate, which we classify as deferred revenue—affiliate on our Balance Sheets (in millions): Nine Months Ended September 30, 2021 Deferred revenue—affiliate, beginning of period $ — Cash received but not yet recognized in revenue 4 Deferred revenue—affiliate, end of period $ 4
Transaction Price Allocated to Future Performance Obligations	The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of September 30, 2021 and December 31, 2020: September 30, 2021 December 31, 2020 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 50.1 9 $ 52.1 9 LNG revenues—affiliate 0.7 3 0.1 1 Total revenues $ 50.8 $ 52.2 (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)	9 Months Ended
	Sep. 30, 2021
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Operations during the three and nine months ended September 30, 2021 and 2020 (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 LNG revenues—affiliate Cheniere Marketing Agreements $ 441 $ 87 $ 860 $ 328 Contracts for Sale and Purchase of Natural Gas and LNG 12 16 18 24 Total LNG revenues—affiliate 453 103 878 352 Cost of sales—affiliate Cheniere Marketing Agreements — 32 34 32 Cargo loading fees under TUA 10 5 32 23 Contracts for Sale and Purchase of Natural Gas and LNG 7 — 27 5 Total cost of sales—affiliate 17 37 93 60 Cost of sales—related party Natural Gas Transportation and Storage Agreements — — 1 — Operating and maintenance expense—affiliate TUA 66 67 199 200 Natural Gas Transportation Agreement 21 20 61 61 Services Agreements 26 27 80 90 LNG Site Sublease Agreement — — 1 1 Total operating and maintenance expense—affiliate 113 114 341 352 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements 12 — 34 — General and administrative expense—affiliate Services Agreements 16 17 45 54

Customer Concentration (Tables)

Customer Concentration (Tables)	9 Months Ended
	Sep. 30, 2021
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with accounts receivable, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total accounts receivable, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Accounts Receivable, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2021 2020 2021 2020 2021 2020 Customer A 21% * 25% 23% 27% 32% Customer B 17% 15% 16% 16% 18% 21% Customer C 19% 28% 18% 19% 18% * Customer D 20% 24% 18% 19% 17% 22% Customer E * * * 10% * * * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2021
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Nine Months Ended September 30, 2021 2020 Cash paid during the period for interest, net of amounts capitalized $ 451 $ 527 Non-cash distributions to affiliates for conveyance of assets — 5

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)milliontonnes / yrtrains	Sep. 30, 2020USD ($)
Nature of Operations and Basis of Presentation [Line Items]
Income Tax Expense (Benefit) | $	$ 0	$ 0
Sabine Pass LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating	5
Number of Liquefaction LNG Trains Commissioning	1
Total Production Capability | milliontonnes / yr	30

Restricted Cash (Details)

Restricted Cash (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 133	$ 97
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 133	$ 97

Accounts and Other Receivable_3

Accounts and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Receivables [Abstract]
Trade receivable	$ 338	$ 300
Other accounts receivable	14	9
Total accounts and other receivables, net of current expected credit losses	$ 352	$ 309

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Inventory [Line Items]
Inventory	$ 118	$ 93
Materials [Member]
Inventory [Line Items]
Inventory	68	68
LNG [Member]
Inventory [Line Items]
Inventory	33	8
Natural gas [Member]
Inventory [Line Items]
Inventory	16	17
Other [Member]
Inventory [Line Items]
Inventory	$ 1	$ 0

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	Sep. 30, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 14,404	$ 14,255
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(1,906)	(1,561)
Property, plant and equipment, net of accumulated depreciation	14,400	14,250
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,742	13,711
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,564	2,100
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	19	19
Accumulated depreciation	(15)	(14)
Property, plant and equipment, net of accumulated depreciation	$ 4	$ 5

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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
Depreciation expense	$ 116	$ 114	$ 347	$ 345

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - tbtu	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	5,135	4,970
Natural Gas Supply Agreement [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	99	91
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	10 years
Financial Liquefaction Supply Derivatives | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	3 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 33	$ (21)
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	(18)	1
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	(8)	(1)
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	$ 59	$ (21)

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - USD ($)		9 Months Ended
		Sep. 30, 2021	Dec. 31, 2020
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		$ 33,000,000	$ (21,000,000)
Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		59,000,000	$ (21,000,000)
Physical Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Asset		59,000,000
Physical Liquefaction Supply Derivatives [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	(1.333)
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	0.415
Physical Liquefaction Supply Derivatives [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	$ 0.015
[1]	Unobservable inputs were weighted by the relative fair value of the instruments.

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ 33	$ 51	$ (21)	$ 24
Realized and mark-to-market gains (losses):
Included in cost of sales		25	(47)	79	(22)
Purchases and settlements:
Purchases		4	5	6	4
Settlements		(3)	(8)	(5)	(6)
Transfers out of Level 3, net	[1]	0	(1)	0	0
Balance, end of period		59	0	59	0
Change in unrealized gains (losses) relating to instruments still held at end of period		$ 25	$ (47)	$ 79	$ (22)
[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 - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 44	$ 14
Derivative assets		25	11
Total derivative assets	[1]	69	25
Current derivative liabilities		(23)	(11)
Derivative liabilities		(13)	(35)
Total derivative liabilities	[1]	(36)	(46)
Derivative asset (liability), net	[1]	33	(21)
Derivative, collateral posted by us		29	4
Natural Gas Supply Agreement [Member]
Derivatives, Fair Value [Line Items]
Derivative asset (liability), net		0	0
Current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	44	14
Derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	25	11
Current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(23)	(11)
Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	$ (13)	$ (35)
[1]	Does not include collateral posted with counterparties by us of $29 million and $4 million, which are included in other current assets in our Balance Sheets as of September 30, 2021 and December 31, 2020, respectively. Includes a natural gas supply contract that we have with a related party, which had a fair value of zero as of both September 30, 2021 and December 31, 2020.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
LNG revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 0	$ 7	$ 0	$ 3
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 10	$ (74)	$ 64	$ (41)
[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	Sep. 30, 2021	Dec. 31, 2020
Derivative [Line Items]
Net Amounts Presented in our Balance Sheets	$ 33	$ (21)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	76	69
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(7)	(44)
Net Amounts Presented in our Balance Sheets	69	25
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(43)	(48)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	7	2
Net Amounts Presented in our Balance Sheets	$ (36)	$ (46)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Accrued Liabilities, Current [Abstract]
Interest costs and related debt fees	$ 158	$ 150
Accrued natural gas purchases	523	374
Liquefaction Project costs	77	64
Other accrued liabilities	3	3
Total accrued liabilities	$ 761	$ 591

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		1 Months Ended
		Oct. 31, 2021	Sep. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Long-term Debt, Gross	[1]		$ 13,446	$ 13,650
Long-term Debt, Net of Premium, Discount and Debt Issuance Costs			13,336	13,520
Total current debt, net of discount and debt issuance costs			203	0
Total Debt, Net of Premium, Discount and Debt Issuance Costs			13,539	13,520
Long-term Debt [Member]
Debt Instrument [Line Items]
Unamortized premium, discount and debt issuance costs, net of accumulated amortization			(110)	(130)
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Current portion of senior secured notes	[1]		$ 204	0
Debt Instrument, Interest Rate, Stated Percentage			6.25%
2022 Senior Notes [Member] | Subsequent Event
Debt Instrument [Line Items]
Repayments of Long-term Debt		$ 318
Short-term Debt [Member]
Debt Instrument [Line Items]
Unamortized premium, discount and debt issuance costs, net of accumulated amortization			$ (1)	$ 0
2037 Private Placement Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 482
Minimum [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			4.20%
Maximum [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			6.25%
[1]	A portion of the 2022 Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 Senior Notes and pay related fees, costs and expenses. An additional $318 million of the 2022 Senior Notes was redeemed in October 2021 with capital contributions received from Cheniere Partners subsequent to the balance sheet date, and thus is also categorized as long-term debt.

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2021	Dec. 31, 2020
Line of Credit Facility [Line Items]
Outstanding balance	[1]	$ 13,446	$ 13,650
2020 Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Original facility size	[2]	1,200
Outstanding balance	[2]	0
Letters of credit issued	[2]	396
Available commitment	[2]	$ 804
Debt Instrument, Description of Variable Rate Basis		LIBOR or base rate
Debt Instrument, Maturity Date	[2]	Mar. 19, 2025
2020 Working Capital Facility [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage		0.10%
2020 Working Capital Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage		0.30%
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	[2]	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	[2]	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	[2]	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	[2]	0.75%
[1]	A portion of the 2022 Senior Notes is categorized as long-term debt because the proceeds from the expected series of sales of approximately $482 million aggregate principal amount of senior secured notes due 2037 pursuant to executed note purchase agreements, expected to be issued in the fourth quarter of 2021, subject to customary closing conditions, will be used to strategically refinance a portion of the 2022 Senior Notes and pay related fees, costs and expenses. An additional $318 million of the 2022 Senior Notes was redeemed in October 2021 with capital contributions received from Cheniere Partners subsequent to the balance sheet date, and thus is also categorized as long-term debt.
[2]	The 2020 Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. We pay a commitment fee equal to an annual rate of 0.1% to 0.3% (depending on our then-current rating), which accrues on the daily amount of the total commitment less the sum of (1) the outstanding principal amount of loans, (2) letters of credit issued and (3) the outstanding principal amount of swing line loans.

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Debt Disclosure [Abstract]
Total interest cost	$ 189	$ 189	$ 569	$ 589
Capitalized interest	(34)	(25)	(96)	(66)
Total interest expense, net of capitalized interest	$ 155	$ 164	$ 473	$ 523

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Sep. 30, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 13,539	$ 13,520
Senior Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	12,850	12,850
Senior Notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	800	800
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]	14,409	14,834
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]	997	1,036
Working Capital Facility [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[3]	0	0
Working Capital Facility [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]	$ 0	$ 0
[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.
[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.

Revenues from Contracts with _3

Revenues from Contracts with Customers - Narrative (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	63.00%	39.00%	56.00%	37.00%
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	96.00%	100.00%	94.00%	100.00%

Revenues from Contracts with _4

Revenues from Contracts with Customers - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 2,244	$ 903	$ 5,935	$ 3,937
Net derivative loss	[1]	0	7	0	3
Revenues		2,244	910	5,935	3,940
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	[2]	1,791	800	5,057	3,585
Revenues		1,791	807	5,057	3,588
Suspension Fees and LNG Cover Damages Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	109	0	513
Suspension Fees and LNG Cover Damages Revenue [Member] | Subsequent Period
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			21		21
Suspension Fees and LNG Cover Damages Revenue [Member] | Current Period
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			244
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 453	$ 103	$ 878	$ 352
[1]	See Note 6—Derivative Instruments
[2]	LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. During the three and nine months ended September 30, 2020, we recognized $109 million and $513 million, respectively, in LNG revenues associated with LNG cargoes for which customers notified us that they would not take delivery, of which $21 million would have been recognized subsequent to September 30, 2020 had the cargoes been lifted pursuant to the delivery schedules with the customers. LNG revenues during the three months ended September 30, 2020 excluded $244 million that would have otherwise been recognized during the period if the cargoes were lifted pursuant to the delivery schedules with the customers. We did not have revenues associated with LNG cargoes for which customers notified us that they would not take delivery during the three and nine months ended September 30, 2021. Revenue is generally recognized upon receipt of irrevocable notice that a customer will not take delivery because our customers have no contractual right to take delivery of such LNG cargo in future periods and our performance obligations with respect to such LNG cargo have been satisfied.

Revenues from Contracts with _5

Revenues from Contracts with Customers - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 1	$ 0
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	114
Cash received but not yet recognized in revenue	144
Revenue recognized from prior period deferral	(114)
Deferred revenue, end of period	144
Deferred revenue—affiliate, beginning of period	0
Cash received but not yet recognized in revenue	4
Deferred revenue—affiliate, end of period	$ 4

Revenues from Contracts with _6

Revenues from Contracts with Customers - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		Sep. 30, 2021	Dec. 31, 2020
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 52.2
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 50.8
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			$ 52.1
Weighted Average Recognition Timing	[1]		9 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 50.1
Weighted Average Recognition Timing	[1]	9 years
LNG—affiliate [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			$ 0.1
Weighted Average Recognition Timing	[1]		1 year
LNG—affiliate [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 0.7
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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Related Party Transaction [Line Items]
LNG revenues—affiliate	$ 453	$ 103	$ 878	$ 352
Cost of sales—affiliate	17	37	93	60
Cost of sales—related party	0	0	1	0
Operating and maintenance expense—affiliate	113	114	341	352
Operating and maintenance expense—related party	12	0	34	0
General and administrative expense—affiliate	16	17	45	54
Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	441	87	860	328
Cost of sales—affiliate	0	32	34	32
Contracts for Sale and Purchase of Natural Gas And LNG [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate	12	16	18	24
Cost of sales—affiliate	7	0	27	5
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	10	5	32	23
Operating and maintenance expense—affiliate	66	67	199	200
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	21	20	61	61
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Cost of sales—related party	0	0	1	0
Operating and maintenance expense—related party	12	0	34	0
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	26	27	80	90
General and administrative expense—affiliate	16	17	45	54
LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	$ 0	$ 0	$ 1	$ 1

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2021USD ($)bcf / dCargoitem	Sep. 30, 2020USD ($)	Dec. 31, 2020USD ($)
Related Party Transaction [Line Items]
Accounts receivable—affiliate	$ 198,000,000		$ 198,000,000		$ 185,000,000
Due to affiliates	48,000,000		48,000,000		59,000,000
Accrued liabilities—related party	5,000,000		5,000,000		4,000,000
Advances to affiliate	114,000,000		114,000,000		122,000,000
Operating and maintenance expense—related party	12,000,000	$ 0	34,000,000	$ 0
Cost of sales—related party	0	0	$ 1,000,000	0
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		$ 5,000,000		4,000,000
Operating and maintenance expense—related party	12,000,000	0	34,000,000	0
Cost of sales—related party	0	0	1,000,000	0
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate	$ 114,000,000		$ 114,000,000		122,000,000
Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Related Party Agreement Term			5 years
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		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	$ 0	$ 0	$ 5,000,000
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		$ 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] | 2021-2027 Letter Agreement
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price			$ 1.96
Cheniere Marketing [Member] | 2021-2027 Letter Agreement | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			81
Cheniere Marketing [Member] | 2022 Letter Agreement | 2022 | Plus $1.768 per MMBtu
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price			$ 1.768
Cheniere Marketing [Member] | 2022 Letter Agreement | 2022 | plus $1.952 per MMBtu
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price			$ 1.952
Cheniere Marketing [Member] | 2022 Letter Agreement | 2023
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price			$ 1.768
Cheniere Marketing [Member] | 2022 Letter Agreement | Maximum [Member] | 2022 | Plus $1.768 per MMBtu
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			6
Cheniere Marketing [Member] | 2022 Letter Agreement | Maximum [Member] | 2022 | plus $1.952 per MMBtu
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			6
Cheniere Marketing [Member] | 2022 Letter Agreement | Maximum [Member] | 2023
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			6
Cheniere Marketing [Member] | 2021 Letter Agreement
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 | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			30
Cheniere Marketing [Member] | 2020 Letter Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub			115.00%
LNG Volume, Purchase Price			$ 1.67
Cheniere Marketing [Member] | 2020 Letter Agreement [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo			43
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		$ 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	$ 7,000,000		$ 7,000,000		$ 6,000,000

Customer Concentration - Schedu

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	21.00%		25.00%	23.00%
Customer A [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			27.00%		32.00%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	17.00%	15.00%	16.00%	16.00%
Customer B [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			18.00%		21.00%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	19.00%	28.00%	18.00%	19.00%
Customer C [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			18.00%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	20.00%	24.00%	18.00%	19.00%
Customer D [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			17.00%		22.00%
Customer E [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage				10.00%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest, net of amounts capitalized	$ 451	$ 527
Non-cash distributions to affiliates for conveyance of assets	0	5
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate)	$ 228	$ 217