Sabine Pass Liquefaction 10-Q 1 Nov 23 2023 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2023 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
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	Yes
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	2023
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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues
Revenues	$ 2,079	$ 4,506	$ 6,830	$ 11,849
Operating costs and expenses (recoveries)
Cost of sales	695	4,850	1,656	10,646
Operating and maintenance expense	313	302	996	874
General and administrative expense (recovery)	16	17	49	49
Depreciation and amortization expense	138	137	415	401
Other	2	0	4	0
Total operating costs and expenses	1,164	5,306	3,120	11,970
Income (loss) from operations	915	(800)	3,710	(121)
Other income (expense)
Interest expense, net of capitalized interest	(138)	(169)	(459)	(495)
Loss on modification or extinguishment of debt	(4)	0	(6)	0
Other income, net	3	3	11	3
Total other expense	(139)	(166)	(454)	(492)
Net income (loss)	$ 776	$ (966)	$ 3,256	$ (613)
Revenue, Product and Service [Extensible Enumeration]	LNG [Member]	LNG [Member]	LNG [Member]	LNG [Member]
Nonrelated Party [Member]
Revenues
Revenues	$ 1,564	$ 3,130	$ 5,085	$ 8,577
Operating costs and expenses (recoveries)
Cost of sales	681	4,739	1,597	10,444
Operating and maintenance expense	181	164	590	474
General and administrative expense (recovery)	1	1	3	(1)
Affiliate [Member]
Revenues
Revenues	515	1,376	1,745	3,268
Operating costs and expenses (recoveries)
Cost of sales	14	111	59	201
Operating and maintenance expense	118	120	362	355
General and administrative expense (recovery)	15	16	46	50
Related Party [Member]
Revenues
Revenues	0	0	0	4
Operating costs and expenses (recoveries)
Cost of sales	0	0	0	1
Operating and maintenance expense	$ 14	$ 18	$ 44	$ 45

Balance Sheets

Balance Sheets - USD ($) $ in Millions		Sep. 30, 2023	Dec. 31, 2022
Current assets
Restricted cash and cash equivalents		$ 35	$ 92
Trade and other receivables, net of current expected credit losses		283	622
Trade receivables—affiliate		167	553
Advances to affiliate		122	151
Inventory		111	143
Current derivative assets	[1]	34	24
Margin deposits		0	35
Other current assets, net		67	54
Total current assets		819	1,674
Property, plant and equipment, net of accumulated depreciation		13,446	13,805
Debt issuance costs, net of accumulated amortization		9	5
Derivative assets	[1]	111	28
Other non-current assets, net		162	160
Total assets		$ 14,547	$ 15,672
Accounts Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Other Receivable, after Allowance for Credit Loss, Current, Related and Nonrelated Party Status [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Current liabilities
Accounts payable		$ 43	$ 28
Accrued liabilities		587	1,400
Current debt, net of discount and debt issuance costs		349	0
Deferred revenue		140	132
Current derivative liabilities	[1]	294	769
Other current liabilities		2	0
Total current liabilities		1,415	2,329
Long-term debt, net of discount and debt issuance costs		10,059	12,040
Derivative liabilities	[1]	1,731	3,024
Other non-current liabilities		80	27
Member’s equity (deficit)		1,262	(1,748)
Total liabilities and member’s equity (deficit)		14,547	15,672
Nonrelated Party [Member]
Current assets
Other current assets, net		45	33
Current liabilities
Accrued liabilities		533	1,314
Other non-current liabilities		59	7
Affiliate [Member]
Current assets
Other current assets, net		22	21
Current liabilities
Accrued liabilities		49	80
Other non-current liabilities		21	20
Related Party [Member]
Current liabilities
Accrued liabilities		$ 5	$ 6
[1]Does not include collateral posted by counterparties to us of $1 million as of September 30, 2023, which is included in other current liabilities on our Balance Sheets, and collateral posted with counterparties by us of $35 million as of December 31, 2022, which is included in margin deposits on our Balance Sheets.

Statements of Member's Equity (

Statements of Member's Equity (Deficit) - USD ($) $ in Millions	Total	Sabine Pass LNG-LP, LLC [Member]
Members' equity, beginning of period at Dec. 31, 2021	$ 1,621	$ 1,621
Increase (Decrease) in Partners' Capital [Roll Forward]
Novated IPM agreement (see Note 12)	(2,712)	(2,712)
Distributions	(563)	(563)
Net income (loss)	85	85
Member's equity, end of period at Mar. 31, 2022	(1,569)	(1,569)
Members' equity, beginning of period at Dec. 31, 2021	1,621	1,621
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-cash contributions related to extinguishment of debt	0
Net income (loss)	(613)
Member's equity, end of period at Sep. 30, 2022	(3,404)	(3,404)
Members' equity, beginning of period at Mar. 31, 2022	(1,569)	(1,569)
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(588)	(588)
Net income (loss)	268	268
Member's equity, end of period at Jun. 30, 2022	(1,889)	(1,889)
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(549)	(549)
Net income (loss)	(966)	(966)
Member's equity, end of period at Sep. 30, 2022	(3,404)	(3,404)
Members' equity, beginning of period at Dec. 31, 2022	(1,748)	(1,748)
Increase (Decrease) in Partners' Capital [Roll Forward]
Distributions	(622)	(622)
Net income (loss)	1,893	1,893
Member's equity, end of period at Mar. 31, 2023	(477)	(477)
Members' equity, beginning of period at Dec. 31, 2022	(1,748)	(1,748)
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-cash contributions related to extinguishment of debt	2
Net income (loss)	3,256
Member's equity, end of period at Sep. 30, 2023	1,262	1,262
Members' equity, beginning of period at Mar. 31, 2023	(477)	(477)
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-cash contributions related to extinguishment of debt	1	1
Distributions	(275)	(275)
Net income (loss)	587	587
Member's equity, end of period at Jun. 30, 2023	(164)	(164)
Increase (Decrease) in Partners' Capital [Roll Forward]
Non-cash contributions related to extinguishment of debt	1	1
Contributions (excluding items shown separately below)	1,190	1,190
Partners Capital Account Distributions, Property	(4)	(4)
Distributions	(537)	(537)
Net income (loss)	776	776
Member's equity, end of period at Sep. 30, 2023	$ 1,262	$ 1,262

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Cash flows from operating activities
Net income (loss)	$ 3,256	$ (613)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization expense	415	401
Amortization of debt issuance costs, premium and discount	16	18
Loss on modification or extinguishment of debt	6	0
Total losses (gains) on derivative instruments, net	(1,867)	2,447
Net cash provided by (used for) settlement of derivative instruments	6	(54)
Other	1	6
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	339	(292)
Trade receivables—affiliate	386	(235)
Advances to affiliate	25	1
Inventory	32	(67)
Margin deposits	35	(52)
Accounts payable and accrued liabilities	(698)	575
Accrued liabilities—related party	(2)	5
Due to affiliates	(28)	(1)
Total deferred revenue	60	8
Other, net	(10)	(8)
Other, net—affiliate	(1)	3
Net cash provided by operating activities	1,971	2,142
Cash flows from investing activities
Property, plant and equipment, net	(123)	(345)
Other	(6)	0
Net cash used in investing activities	(129)	(345)
Cash flows from financing activities
Redemptions and repayments of debt	(1,650)	0
Debt issuance and other financing costs	(4)	0
Debt extinguishment costs	(1)	0
Contributions	1,190	0
Distributions	(1,434)	(1,700)
Net cash used in financing activities	(1,899)	(1,700)
Net increase (decrease) in restricted cash and cash equivalents	(57)	97
Restricted cash and cash equivalents—beginning of period	92	98
Restricted cash and cash equivalents—end of period	$ 35	$ 195

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We are a Delaware limited liability company formed by CQP and based in Houston with one member, Sabine Pass LNG-LP, LLC, an indirect wholly owned subsidiary of CQP. We and SPLNG are each indirect wholly owned subsidiaries of Cheniere Investments, which is a wholly owned subsidiary of CQP, a publicly traded limited partnership (NYSE MKT: CQP). CQP is a 48.6% owned subsidiary of Cheniere, a Houston-based energy company primarily engaged in LNG-related businesses. Cheniere also owns 100% of the general partner interest in CQP through ownership in Cheniere Energy Partners GP, LLC. The natural gas liquefaction and export facility located in Cameron Parish, Louisiana at Sabine Pass (the “Sabine Pass LNG Terminal” ) has six operational Trains, for a total production capacity of approximately 30 mtpa of LNG (the “Liquefaction Project” ). The Sabine Pass LNG Terminal also has operational regasification facilities owned by SPLNG. We have increased available liquefaction capacity at our Liquefaction Project as a result of debottlenecking and other optimization projects. We hold a significant land position at the Sabine Pass LNG Terminal, which provides opportunity for further liquefaction capacity expansion. In May 2023, we and another subsidiary of CQP entered the pre-filing review process with the FERC under the National Environmental Policy Act for an expansion adjacent to the Liquefaction Project with a potential production capacity of up to 20 mtpa of LNG. This expansion may be developed and constructed by an affiliate of ours outside of the Liquefaction Project. The development of this site or other projects, including infrastructure projects in support of natural gas supply and LNG demand, will require, among other things, acceptable commercial and financing arrangements before we make a positive final investment decision. We do not have employees and thus we have various services agreements with affiliates of Cheniere in the ordinary course of business, including services required to construct, operate and maintain the Liquefaction Project, and administrative services. See Note 10—Related Party Transactions for additional details of the activity under these services agreements during the three and nine months ended September 30, 2023 and 2022. Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the financial results for the interim periods presented. 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, 2022 . Results of operations for the three and nine months ended September 30, 2023 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2023. We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss is included in the federal income tax return of CQP. CQP is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of CQP’s taxable income. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements. Recent Accounting Standards ASU 2020-04 In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting . This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements as a result of the market transition from LIBOR to alternative reference rates. The temporary optional expedients under the standard became effective March 12, 2020 and will be available until December 31, 2024 following a subsequent amendment to the standard. As further detailed in Note 8—Debt

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	9 Months Ended
	Sep. 30, 2023
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTSAs of September 30, 2023 and December 31, 2022, we had $35 million and $92 million of restricted cash and cash equivalents, respectively, for which the usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project as required under certain debt arrangements.

Trade and Other Receivables, Ne

Trade and Other Receivables, Net of Current Expected Credit Losses	9 Months Ended
	Sep. 30, 2023
Receivables [Abstract]
Trade and Other Receivables, Net of Current Expected Credit Losses	TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2023 2022 Trade receivables $ 275 $ 603 Other receivables 8 19 Total trade and other receivables, net of current expected credit losses $ 283 $ 622

Inventory

Inventory	9 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Inventory	INVENTORY Inventory consisted of the following (in millions): September 30, December 31, 2023 2022 Materials $ 86 $ 87 LNG 8 26 Natural gas 16 28 Other 1 2 Total inventory $ 111 $ 143

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	9 Months Ended
	Sep. 30, 2023
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2023 2022 LNG terminal Terminal $ 16,277 $ 16,240 Construction-in-process 128 114 Accumulated depreciation (2,963) (2,553) Total LNG terminal, net of accumulated depreciation 13,442 13,801 Fixed assets Fixed assets 20 19 Accumulated depreciation (16) (15) Total fixed assets, net of accumulated depreciation 4 4 Property, plant and equipment, net of accumulated depreciation $ 13,446 $ 13,805 The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Depreciation expense $ 137 $ 136 $ 411 $ 397 Offsets to LNG terminal costs (1) — — — 148

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have commodity derivatives consisting of natural gas supply contracts, including those under our IPM agreement, for the operation of the Liquefaction Project and associated economic hedges (collectively, 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 such changes are 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, by the fair value hierarchy levels prescribed by GAAP (in millions): Fair Value Measurements as of September 30, 2023 December 31, 2022 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) $ 13 $ (1) $ (1,892) $ (1,880) $ (12) $ (10) $ (3,719) $ (3,741) We value our Liquefaction Supply Derivatives using a market or option-based approach incorporating present value techniques, as needed, which incorporates observable commodity price curves, when available, and other relevant data. The fair value of our Liquefaction Supply Derivatives is predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated events deriving fair value including, but not limited to, evaluation of whether the respective market exists from the perspective of market participants as infrastructure is developed. We include a significant portion of our 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 may use in valuing the asset or liability. To the extent valued using an option pricing model, we consider the future prices of energy units for unobservable periods to be a significant unobservable input to estimated net fair value. In estimating the future prices of energy units, we make judgments about market risk related to liquidity of commodity indices and volatility utilizing available market data. Changes in facts and circumstances or additional information may result in revised estimates and judgments, and actual results may differ from these estimates and judgments. We derive our volatility assumptions based on observed historical settled global LNG market pricing or accepted proxies for global LNG market pricing as well as settled domestic natural gas pricing. Such volatility assumptions also contemplate, as of the balance sheet date, observable forward curve data of such indices, as well as evolving available industry data and independent studies. In developing our volatility assumptions, we acknowledge that the global LNG industry is inherently influenced by events such as unplanned supply constraints, geopolitical incidents, unusual climate events including drought and uncommonly mild, by historical standards, winters and summers, and real or threatened disruptive operational impacts to global energy infrastructure. Our current estimate of volatility does not exclude the impact of otherwise rare events unless we believe market participants would exclude such events on account of their assertion that those events were specific to our company and deemed within our control. The Level 3 fair value measurements of our natural gas positions within our Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Liquefaction Supply Derivatives as of September 30, 2023: Net Fair Value Liability (in millions) Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Liquefaction Supply Derivatives $(1,892) Market approach incorporating present value techniques Henry Hub basis spread $(0.543) - $0.510 / $0.040 Option pricing model International LNG pricing spread, relative to Henry Hub (2) 103% - 422% / 213% (1) Unobservable inputs were weighted by the relative fair value of the instruments. (2) Spread contemplates U.S. dollar-denominated pricing. Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Liquefaction Supply Derivatives. The following table shows the changes in the fair value of our Level 3 Liquefaction Supply Derivatives (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Balance, beginning of period $ (2,255) $ (3,456) $ (3,719) $ 38 Realized and change in fair value gains (losses) included in net income (loss) (1): Included in cost of sales, existing deals (2) 294 (1,545) 1,275 (155) Included in cost of sales, new deals (3) 8 — 23 — Purchases and settlements: Purchases (4) — 3 — (4,896) Settlements (5) 59 (24) 522 (11) Transfers out of level 3 (6) 2 (2) 7 — Balance, end of period $ (1,892) $ (5,024) $ (1,892) $ (5,024) Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period $ 302 $ (1,545) $ 1,298 $ (155) (1) Does not include the realized value associated with derivative instruments that settle through physical delivery, as settlement is equal to contractually fixed price from trade date multiplied by contractual volume. See settlements line item in this table. (2) Impact to earnings on deals that existed at the beginning of the period and continue to exist at the end of the period. (3) Impact to earnings on deals that were entered into during the reporting period and continue to exist at the end of the period. (4) Includes any day one gain (loss) recognized during the reporting period on deals that were entered into during the reporting period which continue to exist at the end of the period, in addition to any derivative contracts acquired from entities at a value other than zero on acquisition date, such as derivatives assigned or novated during the reporting period and continuing to exist at the end of the period. (5) Roll-off in the current period of amounts recognized in our Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period. (6) Transferred 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 and the unconditional contractual right of set-off 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 depending on the position of the derivative. 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 hold Liquefaction Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. The firm terms of the Liquefaction Supply Derivatives range up to approximately 15 years, some of which commence upon the satisfaction of certain events or states of affairs. The forward notional amount for our Liquefaction Supply Derivatives was approximately 5,642 TBtu and 5,972 TBtu as of September 30, 2023 and December 31, 2022, respectively, excluding notional amounts associated with extension options that were uncertain to be taken as of September 30, 2023. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations (in millions): Gain (Loss) Recognized in Statements of Operations Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues $ — $ (3) $ — $ 1 Cost of sales 365 (1,625) 1,867 (2,448) (1) Does not include the realized value associated with Liquefaction Supply Derivatives 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. 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, 2023 December 31, 2022 Current derivative assets $ 34 $ 24 Derivative assets 111 28 Total derivative assets 145 52 Current derivative liabilities (294) (769) Derivative liabilities (1,731) (3,024) Total derivative liabilities (2,025) (3,793) Derivative liability, net $ (1,880) $ (3,741) (1) Does not include collateral posted by counterparties to us of $1 million as of September 30, 2023, which is included in other current liabilities on our Balance Sheets, and collateral posted with counterparties by us of $35 million as of December 31, 2022, which is included in margin deposits on our Balance Sheets. Balance Sheets Presentation The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions) for our derivative instruments that are presented on a net basis on our Balance Sheets: Liquefaction Supply Derivatives September 30, 2023 December 31, 2022 Gross assets $ 172 $ 57 Offsetting amounts (27) (5) Net assets $ 145 $ 52 Gross liabilities $ (2,029) $ (3,814) Offsetting amounts 4 21 Net liabilities $ (2,025) $ (3,793)

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2023
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of the following (in millions): September 30, December 31, 2023 2022 Natural gas purchases $ 372 $ 1,017 Interest costs and related debt fees 83 165 Liquefaction Project costs 73 125 Other accrued liabilities 5 7 Total accrued liabilities $ 533 $ 1,314

Debt

Debt	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Debt	DEBT Debt consisted of the following (in millions): September 30, December 31, 2023 2022 Senior Secured Notes: 5.75% due 2024 (the “2024 Senior Notes” ) $ 350 $ 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.746% weighted average rate due 2037 1,782 1,782 Total Senior Secured Notes 10,482 12,132 Working capital revolving credit and letter of credit reimbursement agreement (the “Working Capital Facility” ) — — Revolving credit and guaranty agreement (the “Revolving Credit Facility” ) — — Total debt 10,482 12,132 Current debt, net of discount and debt issuance costs (349) — Long-term portion of unamortized discount and debt issuance costs, net (74) (92) Total long-term debt, net of discount and debt issuance costs $ 10,059 $ 12,040 Revolving Credit Facility Below is a summary of our Revolving Credit Facility as of September 30, 2023 (in millions): Revolving Credit Facility (1) Total facility size $ 1,000 Less: Outstanding balance — Letters of credit issued 284 Available commitment $ 716 Priority ranking Senior secured Interest rate on available balance (2) SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.75% or base rate plus 0.0% - 0.75% Commitment fees on undrawn balance (2) 0.075% - 0.30% Maturity date June 23, 2028 (1) In June 2023, we refinanced and replaced the Working Capital Facility with the Revolving Credit Facility, resulting in an extended maturity date, revised borrowing capacity, reduced rate of interest and commitment fees applicable thereunder and certain other changes to terms and conditions. (2) The margin on the interest rate and the commitment fees is subject to change based on our credit rating. Restrictive Debt Covenants The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit our ability to make certain investments or pay dividends or distributions. We are restricted from making distributions under agreements governing our indebtedness generally until, among other requirements, appropriate reserves have been established for debt service using cash or letters of credit and a historical debt service coverage ratio and projected debt service coverage ratio of at least 1.25:1.00 is satisfied. As of September 30, 2023, 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, 2023 2022 2023 2022 Total interest cost $ 140 $ 177 $ 463 $ 532 Capitalized interest (2) (8) (4) (37) Total interest expense, net of capitalized interest $ 138 $ 169 $ 459 $ 495 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our senior notes (in millions): September 30, 2023 December 31, 2022 Carrying Estimated Carrying Estimated Senior notes $ 10,482 $ 9,997 $ 12,132 $ 11,793 (1) As of both September 30, 2023 and December 31, 2022, $1.2 billion of the fair value of our senior notes were classified as Level 3 since these senior notes were valued by applying an unobservable illiquidity adjustment to the price derived from trades or indicative bids of instruments with similar terms, maturities and credit standing. The remainder of our senior notes are classified as Level 2, based on prices derived from trades or indicative bids of the instruments.

Revenues

Revenues	9 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Revenues	REVENUES The following table represents a disaggregation of revenue earned (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Revenues from contracts with customers LNG revenues $ 1,564 $ 3,133 $ 5,085 $ 8,576 LNG revenues—affiliate 515 1,376 1,745 3,268 LNG revenues—related party — — — 4 Total revenues from contracts with customers 2,079 4,509 6,830 11,848 Net derivative gain (loss) (1) — (3) — 1 Total revenues $ 2,079 $ 4,506 $ 6,830 $ 11,849 (1) See Note 6 —Derivative Instruments for additional information about our derivatives. Contract Assets and Liabilities The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets, net and other non-current assets, net on our Balance Sheets (in millions): September 30, December 31, 2023 2022 Contract assets, net of current expected credit losses $ 1 $ 1 The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Balance Sheets (in millions): Nine Months Ended September 30, 2023 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 192 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 192 The following table reflects the changes in our contract liabilities to affiliate, which we classify as other non-current liabilities—affiliate on our Balance Sheets (in millions): Nine Months Ended September 30, 2023 Deferred revenue—affiliate, beginning of period $ 5 Cash received but not yet recognized in revenue 5 Revenue recognized from prior period deferral (5) Deferred revenue—affiliate, end of period $ 5 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: September 30, 2023 December 31, 2022 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 48.4 8 $ 50.8 8 LNG revenues—affiliate 1.5 2 2.0 2 Total revenues $ 49.9 $ 52.8 (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. Additionally, we have excluded variable consideration related to volumes that contractually are subject to additional liquefaction capacity beyond what is currently in construction or operation. The following table summarizes the amount of variable consideration earned under contracts with customers included in the table above: Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues 53 % 78 % 55 % 74 % LNG revenues—affiliate 64 % 77 % 68 % 76 %

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2023
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our transactions with our affiliates and other related parties, all in the ordinary course of business, as reported on our Statements of Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues—affiliate SPAs and Letter Agreements with Cheniere Marketing $ 513 $ 1,328 $ 1,742 $ 3,173 Contracts for Sale and Purchase of Natural Gas and LNG with other affiliates 2 48 3 95 Total LNG revenues—affiliate 515 1,376 1,745 3,268 LNG revenues—related party Natural Gas Transportation and Storage Agreements (1) — — — 4 Cost of sales—affiliate Cargo loading fees under TUA 12 12 37 37 Contracts for Sale and Purchase of Natural Gas and LNG 2 99 22 164 Total cost of sales—affiliate 14 111 59 201 Cost of sales—related party Natural Gas Transportation and Storage Agreements (1) — — — 1 Operating and maintenance expense—affiliate TUA 69 67 206 200 Natural Gas Transportation Agreement 20 20 61 60 Services Agreements (see Note 1 ) 29 33 94 94 LNG Site Sublease Agreement — — 1 1 Total operating and maintenance expense—affiliate 118 120 362 355 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements (1) 14 18 44 45 General and administrative expense—affiliate Services Agreements (see Note 1 ) 15 16 46 50 (1) This related party is partially owned by Brookfield Asset Management, Inc., who indirectly owns a portion of CQP’s limited partner interests. Other 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 $4 million of assets to SPLNG under this agreement during each of the three and nine months ended September 30, 2023, and expect to convey an additional $4 million in the fourth quarter of 2023. We did not convey any assets to SPLNG under this agreement during the three and nine months ended September 30, 2022.

Customer Concentration

Customer Concentration	9 Months Ended
	Sep. 30, 2023
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The concentration of our customer credit risk in excess of 10% of total revenues and/or trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses was as follows: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2023 2022 2023 2022 2023 2022 Customer A 18% 21% 24% 25% 20% 28% Customer B 19% 18% 16% 17% 15% 18% Customer C 18% 17% 17% 18% 22% * Customer D 16% 19% 15% 17% 11% 18% Customer E * 12% * * * 13% Customer F * * * * 15% * * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2023
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, 2023 2022 Cash paid during the period for interest on debt, net of amounts capitalized $ 524 $ 456 Non-cash investing and financing activities: Non-cash distributions to affiliates for conveyance of property, plant, and equipment 4 — Non-cash contributions related to extinguishment of debt 2 — Unpaid purchases of property, plant and equipment, net 19 143 Novation of IPM Agreement from Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”) In March 2022, in connection with a prior commitment from Cheniere to collateralize financing for Train 6 of the Liquefaction Project, we and CCL Stage III, formerly a wholly owned direct subsidiary of Cheniere that merged with and into CCL, entered into an agreement to assign to us an IPM agreement to purchase 140,000 MMBtu per day of natural gas at a price based on the Platts Japan Korea Marker ( “JKM”

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Financial Statements of SPL have been prepared in accordance with GAAP for interim financial information and in accordance with Rule 10-01 of Regulation S-X and reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair statement of the financial results for the interim periods presented. 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, 2022 . Results of operations for the three and nine months ended September 30, 2023 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2023.
Income Taxes, Policy	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss is included in the federal income tax return of CQP. CQP is not subject to federal or state income taxes, as its partners are taxed individually on their allocable share of CQP’s taxable income. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Financial Statements.
Recent Accounting Standards	Recent Accounting Standards ASU 2020-04 In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting . This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements as a result of the market transition from LIBOR to alternative reference rates. The temporary optional expedients under the standard became effective March 12, 2020 and will be available until December 31, 2024 following a subsequent amendment to the standard. As further detailed in Note 8—Debt

Trade and Other Receivables, _2

Trade and Other Receivables, Net of Current Expected Credit Losses (Tables)	9 Months Ended
	Sep. 30, 2023
Receivables [Abstract]
Schedule of Accounts and Other Receivables, Net of Current Expected Credit Losses	Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2023 2022 Trade receivables $ 275 $ 603 Other receivables 8 19 Total trade and other receivables, net of current expected credit losses $ 283 $ 622

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2023
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consisted of the following (in millions): September 30, December 31, 2023 2022 Materials $ 86 $ 87 LNG 8 26 Natural gas 16 28 Other 1 2 Total inventory $ 111 $ 143

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	9 Months Ended
	Sep. 30, 2023
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2023 2022 LNG terminal Terminal $ 16,277 $ 16,240 Construction-in-process 128 114 Accumulated depreciation (2,963) (2,553) Total LNG terminal, net of accumulated depreciation 13,442 13,801 Fixed assets Fixed assets 20 19 Accumulated depreciation (16) (15) Total fixed assets, net of accumulated depreciation 4 4 Property, plant and equipment, net of accumulated depreciation $ 13,446 $ 13,805
Schedule of Depreciation and Offsets to LNG Terminal Costs	The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Depreciation expense $ 137 $ 136 $ 411 $ 397 Offsets to LNG terminal costs (1) — — — 148

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2023
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, by the fair value hierarchy levels prescribed by GAAP (in millions): Fair Value Measurements as of September 30, 2023 December 31, 2022 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) $ 13 $ (1) $ (1,892) $ (1,880) $ (12) $ (10) $ (3,719) $ (3,741)
Fair Value Measurement Inputs and Valuation Techniques	The following table includes quantitative information for the unobservable inputs for our Level 3 Liquefaction Supply Derivatives as of September 30, 2023: Net Fair Value Liability (in millions) Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Liquefaction Supply Derivatives $(1,892) Market approach incorporating present value techniques Henry Hub basis spread $(0.543) - $0.510 / $0.040 Option pricing model International LNG pricing spread, relative to Henry Hub (2) 103% - 422% / 213% (1) Unobservable inputs were weighted by the relative fair value of the instruments. (2) Spread contemplates U.S. dollar-denominated pricing.
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	The following table shows the changes in the fair value of our Level 3 Liquefaction Supply Derivatives (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Balance, beginning of period $ (2,255) $ (3,456) $ (3,719) $ 38 Realized and change in fair value gains (losses) included in net income (loss) (1): Included in cost of sales, existing deals (2) 294 (1,545) 1,275 (155) Included in cost of sales, new deals (3) 8 — 23 — Purchases and settlements: Purchases (4) — 3 — (4,896) Settlements (5) 59 (24) 522 (11) Transfers out of level 3 (6) 2 (2) 7 — Balance, end of period $ (1,892) $ (5,024) $ (1,892) $ (5,024) Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period $ 302 $ (1,545) $ 1,298 $ (155) (1) Does not include the realized value associated with derivative instruments that settle through physical delivery, as settlement is equal to contractually fixed price from trade date multiplied by contractual volume. See settlements line item in this table. (2) Impact to earnings on deals that existed at the beginning of the period and continue to exist at the end of the period. (3) Impact to earnings on deals that were entered into during the reporting period and continue to exist at the end of the period. (4) Includes any day one gain (loss) recognized during the reporting period on deals that were entered into during the reporting period which continue to exist at the end of the period, in addition to any derivative contracts acquired from entities at a value other than zero on acquisition date, such as derivatives assigned or novated during the reporting period and continuing to exist at the end of the period. (5) Roll-off in the current period of amounts recognized in our Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period. (6) Transferred out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Operations (in millions): Gain (Loss) Recognized in Statements of Operations Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues $ — $ (3) $ — $ 1 Cost of sales 365 (1,625) 1,867 (2,448)
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, 2023 December 31, 2022 Current derivative assets $ 34 $ 24 Derivative assets 111 28 Total derivative assets 145 52 Current derivative liabilities (294) (769) Derivative liabilities (1,731) (3,024) Total derivative liabilities (2,025) (3,793) Derivative liability, net $ (1,880) $ (3,741)
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) for our derivative instruments that are presented on a net basis on our Balance Sheets: Liquefaction Supply Derivatives September 30, 2023 December 31, 2022 Gross assets $ 172 $ 57 Offsetting amounts (27) (5) Net assets $ 145 $ 52 Gross liabilities $ (2,029) $ (3,814) Offsetting amounts 4 21 Net liabilities $ (2,025) $ (3,793)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2023
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following (in millions): September 30, December 31, 2023 2022 Natural gas purchases $ 372 $ 1,017 Interest costs and related debt fees 83 165 Liquefaction Project costs 73 125 Other accrued liabilities 5 7 Total accrued liabilities $ 533 $ 1,314

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Debt Instruments	Debt consisted of the following (in millions): September 30, December 31, 2023 2022 Senior Secured Notes: 5.75% due 2024 (the “2024 Senior Notes” ) $ 350 $ 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.746% weighted average rate due 2037 1,782 1,782 Total Senior Secured Notes 10,482 12,132 Working capital revolving credit and letter of credit reimbursement agreement (the “Working Capital Facility” ) — — Revolving credit and guaranty agreement (the “Revolving Credit Facility” ) — — Total debt 10,482 12,132 Current debt, net of discount and debt issuance costs (349) — Long-term portion of unamortized discount and debt issuance costs, net (74) (92) Total long-term debt, net of discount and debt issuance costs $ 10,059 $ 12,040
Schedule of Line of Credit Facilities	Below is a summary of our Revolving Credit Facility as of September 30, 2023 (in millions): Revolving Credit Facility (1) Total facility size $ 1,000 Less: Outstanding balance — Letters of credit issued 284 Available commitment $ 716 Priority ranking Senior secured Interest rate on available balance (2) SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.75% or base rate plus 0.0% - 0.75% Commitment fees on undrawn balance (2) 0.075% - 0.30% Maturity date June 23, 2028 (1) In June 2023, we refinanced and replaced the Working Capital Facility with the Revolving Credit Facility, resulting in an extended maturity date, revised borrowing capacity, reduced rate of interest and commitment fees applicable thereunder and certain other changes to terms and conditions. (2) The margin on the interest rate and the commitment fees is subject to change based on our credit rating.
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, 2023 2022 2023 2022 Total interest cost $ 140 $ 177 $ 463 $ 532 Capitalized interest (2) (8) (4) (37) Total interest expense, net of capitalized interest $ 138 $ 169 $ 459 $ 495
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount and estimated fair value of our senior notes (in millions): September 30, 2023 December 31, 2022 Carrying Estimated Carrying Estimated Senior notes $ 10,482 $ 9,997 $ 12,132 $ 11,793 (1) As of both September 30, 2023 and December 31, 2022, $1.2 billion of the fair value of our senior notes were classified as Level 3 since these senior notes were valued by applying an unobservable illiquidity adjustment to the price derived from trades or indicative bids of instruments with similar terms, maturities and credit standing. The remainder of our senior notes are classified as Level 2, based on prices derived from trades or indicative bids of the instruments.

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 Revenues from contracts with customers LNG revenues $ 1,564 $ 3,133 $ 5,085 $ 8,576 LNG revenues—affiliate 515 1,376 1,745 3,268 LNG revenues—related party — — — 4 Total revenues from contracts with customers 2,079 4,509 6,830 11,848 Net derivative gain (loss) (1) — (3) — 1 Total revenues $ 2,079 $ 4,506 $ 6,830 $ 11,849 (1) See Note 6 —Derivative Instruments for additional information about our derivatives.
Contract with Customer, Asset	The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets, net and other non-current assets, net on our Balance Sheets (in millions): September 30, December 31, 2023 2022 Contract assets, net of current expected credit losses $ 1 $ 1
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as deferred revenue and other non-current liabilities on our Balance Sheets (in millions): Nine Months Ended September 30, 2023 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 192 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 192 The following table reflects the changes in our contract liabilities to affiliate, which we classify as other non-current liabilities—affiliate on our Balance Sheets (in millions): Nine Months Ended September 30, 2023 Deferred revenue—affiliate, beginning of period $ 5 Cash received but not yet recognized in revenue 5 Revenue recognized from prior period deferral (5) Deferred revenue—affiliate, end of period $ 5
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: September 30, 2023 December 31, 2022 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 48.4 8 $ 50.8 8 LNG revenues—affiliate 1.5 2 2.0 2 Total revenues $ 49.9 $ 52.8 (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.
Revenue, Remaining Performance Obligation, Variable Consideration	The following table summarizes the amount of variable consideration earned under contracts with customers included in the table above: Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues 53 % 78 % 55 % 74 % LNG revenues—affiliate 64 % 77 % 68 % 76 %

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2023
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our transactions with our affiliates and other related parties, all in the ordinary course of business, as reported on our Statements of Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2023 2022 2023 2022 LNG revenues—affiliate SPAs and Letter Agreements with Cheniere Marketing $ 513 $ 1,328 $ 1,742 $ 3,173 Contracts for Sale and Purchase of Natural Gas and LNG with other affiliates 2 48 3 95 Total LNG revenues—affiliate 515 1,376 1,745 3,268 LNG revenues—related party Natural Gas Transportation and Storage Agreements (1) — — — 4 Cost of sales—affiliate Cargo loading fees under TUA 12 12 37 37 Contracts for Sale and Purchase of Natural Gas and LNG 2 99 22 164 Total cost of sales—affiliate 14 111 59 201 Cost of sales—related party Natural Gas Transportation and Storage Agreements (1) — — — 1 Operating and maintenance expense—affiliate TUA 69 67 206 200 Natural Gas Transportation Agreement 20 20 61 60 Services Agreements (see Note 1 ) 29 33 94 94 LNG Site Sublease Agreement — — 1 1 Total operating and maintenance expense—affiliate 118 120 362 355 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements (1) 14 18 44 45 General and administrative expense—affiliate Services Agreements (see Note 1 ) 15 16 46 50 (1) This related party is partially owned by Brookfield Asset Management, Inc., who indirectly owns a portion of CQP’s limited partner interests.

Customer Concentration (Tables)

Customer Concentration (Tables)	9 Months Ended
	Sep. 30, 2023
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	The concentration of our customer credit risk in excess of 10% of total revenues and/or trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses was as follows: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2023 2022 2023 2022 2023 2022 Customer A 18% 21% 24% 25% 20% 28% Customer B 19% 18% 16% 17% 15% 18% Customer C 18% 17% 17% 18% 22% * Customer D 16% 19% 15% 17% 11% 18% Customer E * 12% * * * 13% Customer F * * * * 15% * * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2023
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, 2023 2022 Cash paid during the period for interest on debt, net of amounts capitalized $ 524 $ 456 Non-cash investing and financing activities: Non-cash distributions to affiliates for conveyance of property, plant, and equipment 4 — Non-cash contributions related to extinguishment of debt 2 — Unpaid purchases of property, plant and equipment, net 19 143

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details)	9 Months Ended
	Sep. 30, 2023 milliontonnes / yr members trains
Organization and Nature of Operations [Line Items]
Limited Liability Company (LLC) Number Of Members | members	1
Sabine Pass LNG Terminal [Member]
Organization and Nature of Operations [Line Items]
Number of Liquefaction LNG Trains Operating | trains	6
Total Production Capability	30
Sabine Pass LNG Terminal Expansion | Maximum [Member]
Organization and Nature of Operations [Line Items]
Total Production Capability	20
Cheniere Energy Partners, LP | Cheniere [Member]
Organization and Nature of Operations [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest	48.60%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	100%

Restricted Cash and Cash Equi_2

Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 35	$ 92
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 35	$ 92

Trade and Other Receivables, _3

Trade and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Accounts, Notes, Loans and Financing Receivable [Line Items]
Trade and other receivables, net of current expected credit losses	$ 283	$ 622
Trade receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Trade and other receivables, net of current expected credit losses	275	603
Other Receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Trade and other receivables, net of current expected credit losses	$ 8	$ 19

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Inventory [Line Items]
Inventory	$ 111	$ 143
Materials [Member]
Inventory [Line Items]
Inventory	86	87
LNG [Member]
Inventory [Line Items]
Inventory	8	26
Natural gas [Member]
Inventory [Line Items]
Inventory	16	28
Other [Member]
Inventory [Line Items]
Inventory	$ 1	$ 2

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, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 13,446	$ 13,805
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(2,963)	(2,553)
Property, plant and equipment, net of accumulated depreciation	13,442	13,801
Terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16,277	16,240
Construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	128	114
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	20	19
Accumulated depreciation	(16)	(15)
Property, plant and equipment, net of accumulated depreciation	$ 4	$ 4

Property, Plant and Equipment_4

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Depreciation and Offsets to LNG Terminal Costs (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 137	$ 136	$ 411	$ 397
Offsets to LNG terminal costs	[1]	$ 0	$ 0	$ 0	$ 148
[1]We recognize offsets to LNG terminal costs related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of the respective Trains of the Liquefaction Project during the testing phase for its construction.

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - tbtu	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	5,642	5,972
Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	15 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (1,880)	$ (3,741)
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	13	(12)
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	(1)	(10)
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	$ (1,892)	$ (3,719)

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - USD ($)		9 Months Ended
		Sep. 30, 2023	Dec. 31, 2022
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liabilities		$ (1,880,000,000)	$ (3,741,000,000)
Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liabilities		(1,892,000,000)	$ (3,719,000,000)
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liabilities		(1,892,000,000)
Liquefaction Supply Derivatives [Member] | Valuation, Market Approach | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	(0.543)
Liquefaction Supply Derivatives [Member] | Valuation, Market Approach | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	0.510
Liquefaction Supply Derivatives [Member] | Valuation, Market Approach | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Significant Unobservable Inputs Range	[1]	$ 0.040
Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model | Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	103%
Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model | Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	422%
Liquefaction Supply Derivatives [Member] | Valuation Technique, Option Pricing Model | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	[1],[2]	213%
[1]Unobservable inputs were weighted by the relative fair value of the instruments.[2]Spread contemplates U.S. dollar-denominated pricing.

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ (2,255)	$ (3,456)	$ (3,719)	$ 38
Realized and change in fair value gains (losses) included in net income:
Included in cost of sales, existing deals	[1],[2]	294	(1,545)	1,275	(155)
Included in cost of sales, new deals	[1],[3]	8	0	23	0
Purchases and settlements:
Purchases	[4]	0	3	0	(4,896)
Settlements	[5]	59	(24)	522	(11)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	[6]	2	(2)	7	0
Balance, end of period		(1,892)	(5,024)	(1,892)	(5,024)
Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period		$ 302	$ (1,545)	$ 1,298	$ (155)
[1]Does not include the realized value associated with derivative instruments that settle through physical delivery, as settlement is equal to contractually fixed price from trade date multiplied by contractual volume.  See settlements line item in this table.[2]Impact to earnings on deals that existed at the beginning of the period and continue to exist at the end of the period.[3]Impact to earnings on deals that were entered into during the reporting period and continue to exist at the end of the period.[4]Includes any day one gain (loss) recognized during the reporting period on deals that were entered into during the reporting period which continue to exist at the end of the period, in addition to any derivative contracts acquired from entities at a value other than zero on acquisition date, such as derivatives assigned or novated during the reporting period and continuing to exist at the end of the period.[5]Roll-off in the current period of amounts recognized in our Balance Sheets at the end of the previous period due to settlement of the underlying instruments in the current period.[6]Transferred out of Level 3 as a result of observable market for the underlying natural gas purchase agreements.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
LNG revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 0	$ (3)	$ 0	$ 1
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 365	$ (1,625)	$ 1,867	$ (2,448)
[1]Does not include the realized value associated with Liquefaction Supply Derivatives 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 - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Current derivative assets	[1]	$ 34	$ 24
Derivative assets	[1]	111	28
Total derivative assets	[1]	145	52
Current derivative liabilities	[1]	(294)	(769)
Derivative liabilities	[1]	(1,731)	(3,024)
Total derivative liabilities	[1]	(2,025)	(3,793)
Derivative asset (liability), net	[1]	(1,880)	(3,741)
Derivative, collateral posted by counterparties		$ 1
Derivative, collateral posted by us			$ 35
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]		Current derivative assets	Current derivative assets
Derivative Asset, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Derivative assets	Derivative assets
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]		Current derivative liabilities	Current derivative liabilities
Derivative Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]		Derivative liabilities	Derivative liabilities
[1]Does not include collateral posted by counterparties to us of $1 million as of September 30, 2023, which is included in other current liabilities on our Balance Sheets, and collateral posted with counterparties by us of $35 million as of December 31, 2022, which is included in margin deposits on our Balance Sheets.

Derivative Instruments - Deri_2

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Derivative [Line Items]
Net Amounts Presented in our Balance Sheets	$ (1,880)	$ (3,741)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	172	57
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(27)	(5)
Net Amounts Presented in our Balance Sheets	145	52
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(2,029)	(3,814)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	4	21
Net Amounts Presented in our Balance Sheets	$ (2,025)	$ (3,793)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Accrued Liabilities [Line Items]
Natural gas purchases	$ 372	$ 1,017
Interest costs and related debt fees	83	165
Liquefaction Project costs	73	125
Other accrued liabilities	5	7
Accrued liabilities	587	1,400
Nonrelated Party [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	$ 533	$ 1,314

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2023		Dec. 31, 2022
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 10,482		$ 12,132
Long-Term Debt, Current Maturities	(349)		0
Long-term portion of unamortized discount and debt issuance costs, net	(74)		(92)
Long-Term Debt, Total	10,059		12,040
Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	10,482		12,132
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 350		2,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage	5.625%
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage	5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage	5%
2028 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 1,350		1,350
Debt Instrument, Interest Rate, Stated Percentage	4.20%
2030 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 2,000		2,000
Debt Instrument, Interest Rate, Stated Percentage	4.50%
2037 Senior Notes [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 1,782		1,782
2037 Senior Notes [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.746%
Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 0		0
SPL Revolving Credit Facility
Debt Instrument [Line Items]
Long-Term Debt, Gross	$ 0	[1]	$ 0
[1]In June 2023, we refinanced and replaced the Working Capital Facility with the Revolving Credit Facility, resulting in an extended maturity date, revised borrowing capacity, reduced rate of interest and commitment fees applicable thereunder and certain other changes to terms and conditions.

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) $ in Millions		9 Months Ended
		Sep. 30, 2023 USD ($) unit Rate		Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Outstanding balance | $		$ 10,482		$ 12,132
Debt, Minimum Historical Debt Service Coverage Ratio And Projected Debt Service Coverage Ratio | unit		1.25
SPL Revolving Credit Facility
Line of Credit Facility [Line Items]
Total facility size | $	[1]	$ 1,000
Outstanding balance | $		0	[1]	$ 0
Letters of credit issued | $	[1]	284
Available commitment | $	[1]	$ 716
Debt Instrument, Description of Variable Rate Basis		SOFR or base rate
Debt Instrument, Maturity Date	[1]	Jun. 23, 2028
SPL Revolving Credit Facility | Minimum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	[1],[2]	0.075%
SPL Revolving Credit Facility | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	[1],[2]	0.30%
SPL Revolving Credit Facility | SOFR
Line of Credit Facility [Line Items]
Debt Instrument, Credit Spread Adjustment On Variable Rate | Rate	[1],[2]	0.10%
SPL Revolving Credit Facility | SOFR | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1],[2]	1%
SPL Revolving Credit Facility | SOFR | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1],[2]	1.75%
SPL Revolving Credit Facility | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1],[2]	0%
SPL Revolving Credit Facility | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1],[2]	0.75%
[1]In June 2023, we refinanced and replaced the Working Capital Facility with the Revolving Credit Facility, resulting in an extended maturity date, revised borrowing capacity, reduced rate of interest and commitment fees applicable thereunder and certain other changes to terms and conditions.[2]The margin on the interest rate and the commitment fees is subject to change based on our credit rating.

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Debt Disclosure [Abstract]
Total interest cost	$ 140	$ 177	$ 463	$ 532
Capitalized interest	(2)	(8)	(4)	(37)
Total interest expense, net of capitalized interest	$ 138	$ 169	$ 459	$ 495

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - Senior Notes [Member] - USD ($) $ in Millions		Sep. 30, 2023	Dec. 31, 2022
Carrying Amount [Member] | Fair Value, Inputs, Level 2 and Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-Term Debt, Gross	[1]	$ 10,482	$ 12,132
Estimated Fair Value [Member] | Fair Value, Inputs, Level 2 and Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[1]	9,997	11,793
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		$ 1,200	$ 1,200
[1]As of both September 30, 2023 and December 31, 2022, $1.2 billion of the fair value of our senior notes were classified as Level 3 since these senior notes were valued by applying an unobservable illiquidity adjustment to the price derived from trades or indicative bids of instruments with similar terms, maturities and credit standing. The remainder of our senior notes are classified as Level 2, based on prices derived from trades or indicative bids of the instruments.

Revenues - Schedule of Disaggre

Revenues - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 2,079	$ 4,509	$ 6,830	$ 11,848
Net derivative gain (loss)	[1]	0	(3)	0	1
Total Revenues		$ 2,079	$ 4,506	$ 6,830	$ 11,849
Revenue, Product and Service [Extensible Enumeration]		LNG [Member]	LNG [Member]	LNG [Member]	LNG [Member]
Nonrelated Party [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 1,564	$ 3,133	$ 5,085	$ 8,576
Total Revenues		1,564	3,130	5,085	8,577
Affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		515	1,376	1,745	3,268
Total Revenues		515	1,376	1,745	3,268
Related Party [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	0	0	4
Total Revenues		$ 0	$ 0	$ 0	$ 4
[1] See Note 6 —Derivative Instruments for additional information about our derivatives.

Revenues - Contract Assets and

Revenues - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract assets, net of current expected credit losses	$ 1	$ 1
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	132
Cash received but not yet recognized in revenue	192
Revenue recognized from prior period deferral	(132)
Deferred revenue, end of period	192
Affiliate [Member]
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	5
Cash received but not yet recognized in revenue	5
Revenue recognized from prior period deferral	(5)
Deferred revenue, end of period	$ 5

Revenues - Schedule of Transact

Revenues - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		Sep. 30, 2023	Dec. 31, 2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 52.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 49.9
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 50.8
Weighted Average Recognition Timing	[1]		8 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Affiliate [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price			$ 2
Weighted Average Recognition Timing	[1]		2 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 48.4
Weighted Average Recognition Timing	[1]	8 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-10-01 | Affiliate [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 1.5
Weighted Average Recognition Timing	[1]	2 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.

Revenues - Remaining Performanc

Revenues - Remaining Performance Obligation, Variable Consideration (Details) - LNG [Member]	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenue, Remaining Performance Obligation, Variable Consideration [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	53%	78%	55%	74%
Affiliate [Member]
Revenue, Remaining Performance Obligation, Variable Consideration [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage	64%	77%	68%	76%

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Related Party Transaction [Line Items]
Revenues		$ 2,079	$ 4,506	$ 6,830	$ 11,849
Cost of sales		695	4,850	1,656	10,646
Operating and maintenance expense		313	302	996	874
General and administrative expense (recovery)		16	17	49	49
Affiliate [Member]
Related Party Transaction [Line Items]
Revenues		515	1,376	1,745	3,268
Cost of sales		14	111	59	201
Operating and maintenance expense		118	120	362	355
General and administrative expense (recovery)		15	16	46	50
Related Party [Member]
Related Party Transaction [Line Items]
Revenues		0	0	0	4
Cost of sales		0	0	0	1
Operating and maintenance expense		14	18	44	45
LNG [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Revenues		515	1,376	1,745	3,268
Cheniere Marketing Agreements [Member] | LNG [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Revenues		513	1,328	1,742	3,173
Contracts for Sale and Purchase of Natural Gas And LNG [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Cost of sales		2	99	22	164
Contracts for Sale and Purchase of Natural Gas And LNG [Member] | LNG [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Revenues		2	48	3	95
Natural Gas Transportation and Storage Agreements [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Cost of sales	[1]	0	0	0	1
Operating and maintenance expense	[1]	14	18	44	45
Natural Gas Transportation and Storage Agreements [Member] | LNG [Member] | Related Party [Member]
Related Party Transaction [Line Items]
Revenues	[1]	0	0	0	4
Terminal Use Agreement [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Cost of sales		12	12	37	37
Operating and maintenance expense		69	67	206	200
Natural Gas Transportation Agreement [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense		20	20	61	60
Service Agreements [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense		29	33	94	94
General and administrative expense (recovery)		15	16	46	50
LNG Site Sublease Agreement [Member] | Affiliate [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense		$ 0	$ 0	$ 1	$ 1
[1]This related party is partially owned by Brookfield Asset Management, Inc., who indirectly owns a portion of CQP’s limited partner interests

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Dec. 31, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Related Party Transaction [Line Items]
Non-cash distributions to affiliates for conveyance of property, plant, and equipment				$ 4	$ 0
SPLNG [Member] | Cooperation Agreement [Member]
Related Party Transaction [Line Items]
Non-cash distributions to affiliates for conveyance of property, plant, and equipment		$ 4	$ 0	$ 4	$ 0
SPLNG [Member] | Cooperation Agreement [Member] | Subsequent Event
Related Party Transaction [Line Items]
Non-cash distributions to affiliates for conveyance of property, plant, and equipment	$ 4

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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	18%	21%	24%	25%
Customer A [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			20%		28%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	19%	18%	16%	17%
Customer B [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			15%		18%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	18%	17%	17%	18%
Customer C [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			22%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	16%	19%	15%	17%
Customer D [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			11%		18%
Customer E [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage		12%
Customer E [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage					13%
Customer F [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			15%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) $ in Millions			1 Months Ended	3 Months Ended			9 Months Ended
		Mar. 15, 2022 USD ($)	Mar. 31, 2022 MMBTU	Sep. 30, 2023 USD ($)	Jun. 30, 2023 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized							$ 524	$ 456
Non-cash distributions to affiliates for conveyance of property, plant, and equipment							4	0
Non-cash contributions related to extinguishment of debt				$ 1	$ 1		2	0
Unpaid purchases of property, plant and equipment, net							19	$ 143
Nonmonetary Transaction [Line Items]
Distributions for Novated IPM Agreement						$ 2,712
Current derivative liabilities	[1]			294			294		$ 769
Derivative liabilities	[1]			1,731			$ 1,731		$ 3,024
Sabine Pass LNG-LP, LLC [Member]
Supplemental Cash Flow Information [Abstract]
Non-cash contributions related to extinguishment of debt				$ 1	$ 1
Nonmonetary Transaction [Line Items]
Distributions for Novated IPM Agreement						$ 2,712
Novation of IPM Agreement
Nonmonetary Transaction [Line Items]
Distributions for Novated IPM Agreement		$ 2,700
Current derivative liabilities		142
Derivative liabilities		$ 2,600
Novation of IPM Agreement | Cheniere Corpus Christi Liquefaction Stage III
Nonmonetary Transaction [Line Items]
Contract Volume | MMBTU			140,000
IPM Agreement, Term of Agreement			15 years
[1]Does not include collateral posted by counterparties to us of $1 million as of September 30, 2023, which is included in other current liabilities on our Balance Sheets, and collateral posted with counterparties by us of $35 million as of December 31, 2022, which is included in margin deposits on our Balance Sheets.