Sabine Pass Liquefaction 10-Q 1 May 23 2023 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2023 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 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	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	2023
Document Fiscal Period Focus	Q1
No Trading Symbol Flag	true
Entity Common Stock, Shares Outstanding	0

Statements of Income

Statements of Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Revenues
Revenues	$ 2,867	$ 3,245
Revenues from contracts with customers	2,867	3,245
Operating costs and expenses
Cost of sales (excluding items shown separately below)	313	2,561
Cost of sales—affiliate	33	18
Operating and maintenance expense	176	148
Operating and maintenance expense—affiliate	124	117
Operating and maintenance expense—related party	16	12
General and administrative expense	1	1
General and administrative expense—affiliate	16	17
Depreciation and amortization expense	138	130
Total operating costs and expenses	817	3,004
Income from operations	2,050	241
Other income (expense)
Interest expense, net of capitalized interest	(161)	(156)
Other income, net	4	0
Total other expense	(157)	(156)
Net income	1,893	85
LNG [Member]
Revenues
Revenues	2,106	2,488
Revenues from contracts with customers	2,106	2,488
LNG—affiliate
Revenues
Revenues from contracts with customers	$ 761	$ 757

Balance Sheets

Balance Sheets - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current assets
Restricted cash and cash equivalents	$ 160	$ 92
Trade and other receivables, net of current expected credit losses	265	622
Trade receivables—affiliate	263	553
Advances to affiliate	131	151
Inventory	132	143
Current derivative assets	55	24
Margin deposits	0	35
Other current assets	31	33
Other current assets—affiliate	22	21
Total current assets	1,059	1,674
Property, plant and equipment, net of accumulated depreciation	13,689	13,805
Debt issuance costs, net of accumulated amortization	5	5
Derivative assets	32	28
Other non-current assets, net	167	160
Total assets	14,952	15,672
Current liabilities
Accounts payable	66	28
Accrued liabilities	610	1,314
Accrued liabilities—related party	5	6
Current debt, net of discount and debt issuance costs	60	0
Due to affiliates	38	80
Deferred revenue	72	132
Current derivative liabilities	400	769
Other current liabilities	9	0
Total current liabilities	1,260	2,329
Long-term debt, net of premium, discount and debt issuance costs	11,985	12,040
Derivative liabilities	2,157	3,024
Other non-current liabilities	7	7
Other non-current liabilities—affiliate	20	20
Member’s deficit	(477)	(1,748)
Total liabilities and member’s deficit	$ 14,952	$ 15,672

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	85	85
Member's equity, end of period at Mar. 31, 2022	(1,569)	(1,569)
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	1,893	1,893
Member's equity, end of period at Mar. 31, 2023	$ (477)	$ (477)

Statements of Cash Flows

Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Cash flows from operating activities
Net income	$ 1,893	$ 85
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	138	130
Amortization of debt issuance costs, premium and discount	6	5
Total losses (gains) on derivative instruments, net	(1,260)	525
Net cash used for settlement of derivative instruments	(11)	(9)
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	357	83
Trade receivables—affiliate	290	(73)
Advances to affiliate	18	(5)
Inventory	11	26
Margin deposits	35	25
Accounts payable and accrued liabilities	(615)	(5)
Accrued liabilities—related party	(2)	1
Due to affiliates	(40)	(21)
Deferred revenue	(60)	(38)
Other, net	18	(44)
Other, net—affiliate	(1)	1
Net cash provided by operating activities	777	686
Cash flows from investing activities
Property, plant and equipment	(82)	(85)
Other	(5)	0
Net cash used in investing activities	(87)	(85)
Cash flows from financing activities
Distributions	(622)	(563)
Net cash used in financing activities	(622)	(563)
Net increase in restricted cash and cash equivalents	68	38
Restricted cash and cash equivalents—beginning of period	92	98
Restricted cash and cash equivalents—end of period	$ 160	$ 136

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	3 Months Ended
	Mar. 31, 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 February 2023, we and another subsidiary of CQP initiated the pre-filing review process with the FERC under the National Environmental Policy Act for an expansion adjacent to the Liquefaction Project consisting of up to three Trains with an expected total production capacity of approximately 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. 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 months ended March 31, 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 expected to arise from 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. We have not yet applied the optional expedients available under the standard because we have not yet modified any of our existing contracts indexed to LIBOR, mainly our credit facility as further described in Note 8 —Debt

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	3 Months Ended
	Mar. 31, 2023
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTS 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. As of March 31, 2023 and December 31, 2022, we had $160 million and $92 million of restricted cash and cash equivalents, respectively, as required under the above agreement.

Trade and Other Receivables, Ne

Trade and Other Receivables, Net of Current Expected Credit Losses	3 Months Ended
	Mar. 31, 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): March 31, December 31, 2023 2022 Trade receivables $ 259 $ 603 Other receivables 6 19 Total trade and other receivables, net of current expected credit losses $ 265 $ 622

Inventory

Inventory	3 Months Ended
	Mar. 31, 2023
Inventory Disclosure [Abstract]
Inventory	INVENTORY Inventory consisted of the following (in millions): March 31, December 31, 2023 2022 Materials $ 90 $ 87 LNG 19 26 Natural gas 22 28 Other 1 2 Total inventory $ 132 $ 143

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	3 Months Ended
	Mar. 31, 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): March 31, December 31, 2023 2022 LNG terminal Terminal $ 16,262 $ 16,240 Construction-in-process 113 114 Accumulated depreciation (2,690) (2,553) Total LNG terminal, net of accumulated depreciation 13,685 13,801 Fixed assets Fixed assets 19 19 Accumulated depreciation (15) (15) Total fixed assets, net of accumulated depreciation 4 4 Property, plant and equipment, net of accumulated depreciation $ 13,689 $ 13,805 The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended March 31, 2023 2022 Depreciation expense $ 137 $ 129 Offsets to LNG terminal costs (1) — 148

Derivative Instruments

Derivative Instruments	3 Months Ended
	Mar. 31, 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, “Liquefaction Supply Derivatives”). We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow or fair value hedging instruments, and changes in fair value are recorded within our Statements of Income to the extent not utilized for the commissioning process, in which case 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 (in millions): Fair Value Measurements as of March 31, 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) $ 28 $ 4 $ (2,502) $ (2,470) $ (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, using 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 would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity and volatility. The Level 3 fair value measurements of 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 March 31, 2023: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Liquefaction Supply Derivatives $(2,502) Market approach incorporating present value techniques Henry Hub basis spread $(1.173) - $0.361 / $(0.021) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 93% - 574% / 208% (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 March 31, 2023 2022 Balance, beginning of period $ (3,719) $ 38 Realized and change in fair value gains (losses) included in net income (1): Included in cost of sales, existing deals (2) 1,049 (53) Included in cost of sales, new deals (3) 3 — Purchases and settlements: Purchases (4) — (3,141) Settlements (5) 165 (6) Balance, end of period $ (2,502) $ (3,162) Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period $ 1,052 $ (53) (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. 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 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 6,027 TBtu and 5,972 TBtu as of March 31, 2023 and December 31, 2022, respectively, excluding notional amounts associated with extension options that were uncertain to be taken as of March 31, 2023. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Income (in millions): Gain (Loss) Recognized in Statements of Income Statements of Income Location (1) Three Months Ended March 31, 2023 2022 Cost of sales $ 1,260 $ (525) (1) Does not include the 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. Fair Value and Location of Derivative Assets and Liabilities on the Balance Sheets The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheets Location March 31, 2023 December 31, 2022 Current derivative assets $ 55 $ 24 Derivative assets 32 28 Total derivative assets 87 52 Current derivative liabilities (400) (769) Derivative liabilities (2,157) (3,024) Total derivative liabilities (2,557) (3,793) Derivative liability, net $ (2,470) $ (3,741) (1) Does not include collateral posted by counterparties to us of $8 million as of March 31, 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 in 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 March 31, 2023 December 31, 2022 Gross assets $ 89 $ 57 Offsetting amounts (2) (5) Net assets $ 87 $ 52 Gross liabilities $ (2,577) $ (3,814) Offsetting amounts 20 21 Net liabilities $ (2,557) $ (3,793)

Accrued Liabilities

Accrued Liabilities	3 Months Ended
	Mar. 31, 2023
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of the following (in millions): March 31, December 31, 2023 2022 Natural gas purchases $ 406 $ 1,017 Interest costs and related debt fees 118 165 Liquefaction Project costs 80 125 Other accrued liabilities 6 7 Total accrued liabilities $ 610 $ 1,314

Debt

Debt	3 Months Ended
	Mar. 31, 2023
Debt Disclosure [Abstract]
Debt	DEBT Debt consisted of the following (in millions): March 31, December 31, 2023 2022 Senior Secured Notes: 5.75% due 2024 $ 2,000 $ 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.746% weighted average rate due 2037 1,782 1,782 Total Senior Secured Notes 12,132 12,132 Working capital revolving credit and letter of credit reimbursement agreement (the “Working Capital Facility”) — — Total debt 12,132 12,132 Current portion of long-term debt (1) (60) — Long-term portion of unamortized premium, discount and debt issuance costs, net (87) (92) Total long-term debt, net of premium, discount and debt issuance costs $ 11,985 $ 12,040 (1) As of March 31, 2023, $60 million of debt with contractual maturities of greater than one year was classified as current portion of long-term debt based on our intent and ability to repay the debt with cash that was on hand at March 31, 2023, including repurchases of debt subsequent to the balance sheet date and through April 26, 2023 . Working Capital Facility Below is a summary of our Working Capital Facility as of March 31, 2023 (in millions): Working Capital Facility Total facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 329 Available commitment $ 871 Priority ranking Senior secured Interest rate on available balance (1) LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% Commitment fees on undrawn balance (1) 0.10% - 0.30% Maturity date March 19, 2025 (1) 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 March 31, 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 March 31, 2023 2022 Total interest cost $ 163 $ 177 Capitalized interest (2) (21) Total interest expense, net of capitalized interest $ 161 $ 156 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): March 31, 2023 December 31, 2022 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 10,780 $ 10,718 $ 10,780 $ 10,569 Senior notes — Level 3 (2) 1,352 1,241 1,352 1,224 (1) The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments. (2) The Level 3 estimated fair value was calculated based on inputs that are observable in the market or that could be derived from, or corroborated with, observable market data, including interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market. The estimated fair value of our Working Capital Facility approximates the principal amount outstanding because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

Revenues

Revenues	3 Months Ended
	Mar. 31, 2023
Revenue from Contract with Customer [Abstract]
Revenues	REVENUES The following table represents a disaggregation of revenue earned (in millions): Three Months Ended March 31, 2023 2022 Revenues from contracts with customers LNG revenues $ 2,106 $ 2,488 LNG revenues—affiliate 761 757 Total revenues from contracts with customers $ 2,867 $ 3,245 Contract Assets and Liabilities The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Balance Sheets (in millions): March 31, December 31, 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 on our Balance Sheets (in millions): Three Months Ended March 31, 2023 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 72 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 72 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): Three Months Ended March 31, 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: March 31, 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 $ 49.9 8 $ 50.8 8 LNG revenues—affiliate 1.8 2 2.0 2 Total revenues $ 51.7 $ 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. Approximately 61% and 67% of our LNG revenues from contracts included in the table above during the three months ended March 31, 2023 and 2022, respectively, were related to variable consideration received from customers. Approximately 73% and 100% of our LNG revenues—affiliate from contracts included in the table above during the three months ended March 31, 2023 and 2022, respectively, were related to variable consideration received from customers. We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching a final investment decision on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2023
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Statements of Income (in millions): Three Months Ended March 31, 2023 2022 LNG revenues—affiliate Cheniere Marketing Agreements (1) $ 761 $ 745 Contracts for Sale and Purchase of Natural Gas and LNG (2) — 12 Total LNG revenues—affiliate 761 757 Cost of sales—affiliate Cargo loading fees under TUA (3) 14 13 Contracts for Sale and Purchase of Natural Gas and LNG (2) 19 5 Total cost of sales—affiliate 33 18 Operating and maintenance expense—affiliate TUA (3) 68 66 Natural Gas Transportation Agreement (4) 21 20 Services Agreements (5) 35 31 Total operating and maintenance expense—affiliate 124 117 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements (6) 16 12 General and administrative expense—affiliate Services Agreements (5) 16 17 (1) We primarily sell LNG to Cheniere Marketing under SPAs and letter agreements at a price equal to 115% of Henry Hub plus a fixed fee, except for an SPA associated with an IPM agreement for which pricing is linked to international natural gas prices. We also have a master SPA agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. As of March 31, 2023 and December 31, 2022, we had $263 million and $551 million of trade receivables—affiliate, respectively, under these agreements with Cheniere Marketing. In addition, we have 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 the greater of: (a) 115% of the applicable natural gas feedstock purchase price or (b) an FOB U.S. Gulf Coast LNG market price. (2) We have agreements with SPLNG, CTPL and Corpus Christi Liquefaction, LLC (“CCL”) that allow us to sell and purchase natural gas and LNG with each party. Natural gas purchased under these agreements is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. (3) 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 (a portion of which is indexed for inflation), continuing until at least May 2036. Additionally, we are required to reimburse SPLNG for our proportionate share of ad valorem taxes incurred based on our contracted share of SPLNG’s regasification capacity. CQP has guaranteed our obligations under our TUA. (4) To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG Terminal, we have transportation agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of CQP, and third party pipeline companies. (5) 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. Prior to the substantial completion of each Train of the Liquefaction Project, our payments under the services agreements were primarily based on a cost reimbursement structure, and following the completion of each Train, our payments include a fixed monthly fee (indexed for inflation) per mtpa in addition to the reimbursement of costs. As of March 31, 2023 and December 31, 2022, we had $131 million and $151 million of advances to affiliates, respectively, under the services agreements. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate. (6) We are 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. This related party is partially owned by the investment management company that indirectly acquired a portion of CQP’s limited partner interests in September 2020. We recorded accrued liabilities—related party of $5 million and $6 million as of March 31, 2023 and December 31, 2022, respectively, with this related party. We had $38 million and $80 million due to affiliates as of March 31, 2023 and December 31, 2022, respectively, under agreements with affiliates as described above. Disclosure of future consideration under revenue contracts with affiliates is included in Note 9 —Revenues . Other Agreements 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, with renewal options and adjustment for inflation every five years. As of both March 31, 2023 and December 31, 2022, we recorded other non-current liabilities—affiliate of $15 million related to this agreement. Cooperation Agreement We have a cooperation agreement with SPLNG that allows us to retain and acquire certain rights to access the property and facilities that are owned by SPLNG for the purpose of constructing, modifying and operating the Liquefaction Project. In consideration for access given to us, we have agreed to transfer to SPLNG title of certain facilities, equipment and modifications, which SPLNG is obligated to operate and maintain. The term of this agreement is consistent with our TUA described above. We did not convey any assets to SPLNG under this agreement during the three months ended March 31, 2023 and 2022. 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. To date, there have been no state and local tax payments demanded by Cheniere under the tax sharing agreement. The agreement is effective for tax returns due on or after August 2012.

Customer Concentration

Customer Concentration	3 Months Ended
	Mar. 31, 2023
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The concentration of our customer credit risk in excess of 10% or greater of total revenues and/or trade and other receivables 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 March 31, March 31, December 31, 2023 2022 2023 2022 Customer A 28% 29% 30% 28% Customer B 15% 14% 23% 18% Customer C 17% 18% 15% * Customer D 15% 15% 15% 18% Customer E * 10% * * Customer F * * —% 13% * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 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): Three Months Ended March 31, 2023 2022 Cash paid during the period for interest on debt, net of amounts capitalized $ 202 $ 130 Non-cash investing activity: Unpaid purchases of property, plant and equipment 39 205 Novation of IPM Agreement from Corpus Christi Liquefaction Stage III, LLC (“CCL Stage III”)

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 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 months ended March 31, 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 expected to arise from 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. We have not yet applied the optional expedients available under the standard because we have not yet modified any of our existing contracts indexed to LIBOR, mainly our credit facility as further described in Note 8 —Debt

Trade and Other Receivables, _2

Trade and Other Receivables, Net of Current Expected Credit Losses (Tables)	3 Months Ended
	Mar. 31, 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): March 31, December 31, 2023 2022 Trade receivables $ 259 $ 603 Other receivables 6 19 Total trade and other receivables, net of current expected credit losses $ 265 $ 622

Inventory (Tables)

Inventory (Tables)	3 Months Ended
	Mar. 31, 2023
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consisted of the following (in millions): March 31, December 31, 2023 2022 Materials $ 90 $ 87 LNG 19 26 Natural gas 22 28 Other 1 2 Total inventory $ 132 $ 143

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	3 Months Ended
	Mar. 31, 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): March 31, December 31, 2023 2022 LNG terminal Terminal $ 16,262 $ 16,240 Construction-in-process 113 114 Accumulated depreciation (2,690) (2,553) Total LNG terminal, net of accumulated depreciation 13,685 13,801 Fixed assets Fixed assets 19 19 Accumulated depreciation (15) (15) Total fixed assets, net of accumulated depreciation 4 4 Property, plant and equipment, net of accumulated depreciation $ 13,689 $ 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 March 31, 2023 2022 Depreciation expense $ 137 $ 129 Offsets to LNG terminal costs (1) — 148

Derivative Instruments (Tables)

Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 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 (in millions): Fair Value Measurements as of March 31, 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) $ 28 $ 4 $ (2,502) $ (2,470) $ (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 March 31, 2023: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Liquefaction Supply Derivatives $(2,502) Market approach incorporating present value techniques Henry Hub basis spread $(1.173) - $0.361 / $(0.021) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 93% - 574% / 208% (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 March 31, 2023 2022 Balance, beginning of period $ (3,719) $ 38 Realized and change in fair value gains (losses) included in net income (1): Included in cost of sales, existing deals (2) 1,049 (53) Included in cost of sales, new deals (3) 3 — Purchases and settlements: Purchases (4) — (3,141) Settlements (5) 165 (6) Balance, end of period $ (2,502) $ (3,162) Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period $ 1,052 $ (53) (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.
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Statements of Income (in millions): Gain (Loss) Recognized in Statements of Income Statements of Income Location (1) Three Months Ended March 31, 2023 2022 Cost of sales $ 1,260 $ (525)
Fair Value of Derivative Instruments by Balance Sheet Location	The following table shows the fair value and location of our Liquefaction Supply Derivatives on our Balance Sheets (in millions): Fair Value Measurements as of (1) Balance Sheets Location March 31, 2023 December 31, 2022 Current derivative assets $ 55 $ 24 Derivative assets 32 28 Total derivative assets 87 52 Current derivative liabilities (400) (769) Derivative liabilities (2,157) (3,024) Total derivative liabilities (2,557) (3,793) Derivative liability, net $ (2,470) $ (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 March 31, 2023 December 31, 2022 Gross assets $ 89 $ 57 Offsetting amounts (2) (5) Net assets $ 87 $ 52 Gross liabilities $ (2,577) $ (3,814) Offsetting amounts 20 21 Net liabilities $ (2,557) $ (3,793)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2023
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following (in millions): March 31, December 31, 2023 2022 Natural gas purchases $ 406 $ 1,017 Interest costs and related debt fees 118 165 Liquefaction Project costs 80 125 Other accrued liabilities 6 7 Total accrued liabilities $ 610 $ 1,314

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2023
Debt Disclosure [Abstract]
Schedule of Debt Instruments	Debt consisted of the following (in millions): March 31, December 31, 2023 2022 Senior Secured Notes: 5.75% due 2024 $ 2,000 $ 2,000 5.625% due 2025 2,000 2,000 5.875% due 2026 1,500 1,500 5.00% due 2027 1,500 1,500 4.200% due 2028 1,350 1,350 4.500% due 2030 2,000 2,000 4.746% weighted average rate due 2037 1,782 1,782 Total Senior Secured Notes 12,132 12,132 Working capital revolving credit and letter of credit reimbursement agreement (the “Working Capital Facility”) — — Total debt 12,132 12,132 Current portion of long-term debt (1) (60) — Long-term portion of unamortized premium, discount and debt issuance costs, net (87) (92) Total long-term debt, net of premium, discount and debt issuance costs $ 11,985 $ 12,040 (1) As of March 31, 2023, $60 million of debt with contractual maturities of greater than one year was classified as current portion of long-term debt based on our intent and ability to repay the debt with cash that was on hand at March 31, 2023, including repurchases of debt subsequent to the balance sheet date and through April 26, 2023
Schedule of Line of Credit Facilities	Below is a summary of our Working Capital Facility as of March 31, 2023 (in millions): Working Capital Facility Total facility size $ 1,200 Less: Outstanding balance — Letters of credit issued 329 Available commitment $ 871 Priority ranking Senior secured Interest rate on available balance (1) LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750% Commitment fees on undrawn balance (1) 0.10% - 0.30% Maturity date March 19, 2025 (1) 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 March 31, 2023 2022 Total interest cost $ 163 $ 177 Capitalized interest (2) (21) Total interest expense, net of capitalized interest $ 161 $ 156
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount and estimated fair value of our debt (in millions): March 31, 2023 December 31, 2022 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 10,780 $ 10,718 $ 10,780 $ 10,569 Senior notes — Level 3 (2) 1,352 1,241 1,352 1,224 (1) The Level 2 estimated fair value was based on quotes obtained from broker-dealers or market makers of these senior notes and other similar instruments.

Revenues (Tables)

Revenues (Tables)	3 Months Ended
	Mar. 31, 2023
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table represents a disaggregation of revenue earned (in millions): Three Months Ended March 31, 2023 2022 Revenues from contracts with customers LNG revenues $ 2,106 $ 2,488 LNG revenues—affiliate 761 757 Total revenues from contracts with customers $ 2,867 $ 3,245
Contract with Customer, Asset	The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Balance Sheets (in millions): March 31, December 31, 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 on our Balance Sheets (in millions): Three Months Ended March 31, 2023 Deferred revenue, beginning of period $ 132 Cash received but not yet recognized in revenue 72 Revenue recognized from prior period deferral (132) Deferred revenue, end of period $ 72 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): Three Months Ended March 31, 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: March 31, 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 $ 49.9 8 $ 50.8 8 LNG revenues—affiliate 1.8 2 2.0 2 Total revenues $ 51.7 $ 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.

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2023
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Statements of Income (in millions): Three Months Ended March 31, 2023 2022 LNG revenues—affiliate Cheniere Marketing Agreements (1) $ 761 $ 745 Contracts for Sale and Purchase of Natural Gas and LNG (2) — 12 Total LNG revenues—affiliate 761 757 Cost of sales—affiliate Cargo loading fees under TUA (3) 14 13 Contracts for Sale and Purchase of Natural Gas and LNG (2) 19 5 Total cost of sales—affiliate 33 18 Operating and maintenance expense—affiliate TUA (3) 68 66 Natural Gas Transportation Agreement (4) 21 20 Services Agreements (5) 35 31 Total operating and maintenance expense—affiliate 124 117 Operating and maintenance expense—related party Natural Gas Transportation and Storage Agreements (6) 16 12 General and administrative expense—affiliate Services Agreements (5) 16 17 (1) We primarily sell LNG to Cheniere Marketing under SPAs and letter agreements at a price equal to 115% of Henry Hub plus a fixed fee, except for an SPA associated with an IPM agreement for which pricing is linked to international natural gas prices. We also have a master SPA agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. As of March 31, 2023 and December 31, 2022, we had $263 million and $551 million of trade receivables—affiliate, respectively, under these agreements with Cheniere Marketing. In addition, we have 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 the greater of: (a) 115% of the applicable natural gas feedstock purchase price or (b) an FOB U.S. Gulf Coast LNG market price. (2) We have agreements with SPLNG, CTPL and Corpus Christi Liquefaction, LLC (“CCL”) that allow us to sell and purchase natural gas and LNG with each party. Natural gas purchased under these agreements is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. (3) 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 (a portion of which is indexed for inflation), continuing until at least May 2036. Additionally, we are required to reimburse SPLNG for our proportionate share of ad valorem taxes incurred based on our contracted share of SPLNG’s regasification capacity. CQP has guaranteed our obligations under our TUA. (4) To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG Terminal, we have transportation agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of CQP, and third party pipeline companies. (5) 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. Prior to the substantial completion of each Train of the Liquefaction Project, our payments under the services agreements were primarily based on a cost reimbursement structure, and following the completion of each Train, our payments include a fixed monthly fee (indexed for inflation) per mtpa in addition to the reimbursement of costs. As of March 31, 2023 and December 31, 2022, we had $131 million and $151 million of advances to affiliates, respectively, under the services agreements. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate. (6) We are 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. This related party is partially owned by the investment management company that indirectly acquired a portion of CQP’s limited partner interests in September 2020. We recorded accrued liabilities—related party of $5 million and $6 million as of March 31, 2023 and December 31, 2022, respectively, with this related party.

Customer Concentration (Tables)

Customer Concentration (Tables)	3 Months Ended
	Mar. 31, 2023
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended March 31, March 31, December 31, 2023 2022 2023 2022 Customer A 28% 29% 30% 28% Customer B 15% 14% 23% 18% Customer C 17% 18% 15% * Customer D 15% 15% 15% 18% Customer E * 10% * * Customer F * * —% 13% * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2023
Supplemental Cash Flow Information [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table provides supplemental disclosure of cash flow information (in millions): Three Months Ended March 31, 2023 2022 Cash paid during the period for interest on debt, net of amounts capitalized $ 202 $ 130 Non-cash investing activity: Unpaid purchases of property, plant and equipment 39 205

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details)	3 Months Ended
	Mar. 31, 2023 milliontonnes / yr trains members
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 | milliontonnes / yr	30
Sabine Pass LNG Terminal Expansion
Organization and Nature of Operations [Line Items]
Total Production Capability | milliontonnes / yr	20
Number of Liquefaction LNG Trains | trains	3
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	Mar. 31, 2023	Dec. 31, 2022
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 160	$ 92
SPL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 160	$ 92

Trade and Other Receivables, _3

Trade and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Receivables [Abstract]
Trade receivables	$ 259	$ 603
Other receivables	6	19
Total trade and other receivables, net of current expected credit losses	$ 265	$ 622

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Inventory [Line Items]
Inventory	$ 132	$ 143
Materials [Member]
Inventory [Line Items]
Inventory	90	87
LNG [Member]
Inventory [Line Items]
Inventory	19	26
Natural gas [Member]
Inventory [Line Items]
Inventory	22	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	Mar. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 13,689	$ 13,805
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(2,690)	(2,553)
Property, plant and equipment, net of accumulated depreciation	13,685	13,801
Terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16,262	16,240
Construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	113	114
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	19	19
Accumulated depreciation	(15)	(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
		Mar. 31, 2023	Mar. 31, 2022
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 137	$ 129
Offsets to LNG terminal costs	[1]	$ 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	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	6,027	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	Mar. 31, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (2,470)	$ (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	28	(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	4	(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	$ (2,502)	$ (3,719)

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - USD ($)		3 Months Ended
		Mar. 31, 2023	Dec. 31, 2022
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liabilities		$ (2,470,000,000)	$ (3,741,000,000)
Fair Value, Inputs, Level 3 [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liabilities		(2,502,000,000)	$ (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		(2,502,000,000)
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]	(1.173)
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]	0.361
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]	$ (0.021)
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]	93%
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]	574%
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]	208%
[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
		Mar. 31, 2023	Mar. 31, 2022
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ (3,719)	$ 38
Realized and change in fair value gains (losses) included in net income:
Included in cost of sales, existing deals	[1],[2]	1,049	(53)
Included in cost of sales, new deals	[1],[3]	3	0
Purchases and settlements:
Purchases	[4]	0	(3,141)
Settlements	[5]	165	(6)
Balance, end of period		(2,502)	(3,162)
Favorable (unfavorable) changes in fair value relating to instruments still held at the end of the period		$ 1,052	$ (53)
[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.

Derivative Instruments - Deriva

Derivative Instruments - Derivative Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022
Cost of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	$ 1,260	$ (525)
[1]Does not include the 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 - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Mar. 31, 2023	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 55	$ 24
Derivative assets		32	28
Total derivative assets	[1]	87	52
Current derivative liabilities		(400)	(769)
Derivative liabilities		(2,157)	(3,024)
Total derivative liabilities	[1]	(2,557)	(3,793)
Derivative asset (liability), net	[1]	(2,470)	(3,741)
Derivative, collateral posted by counterparties		8
Derivative, collateral posted by us			35
Current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	55	24
Derivative assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	32	28
Current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(400)	(769)
Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	$ (2,157)	$ (3,024)
[1]Does not include collateral posted by counterparties to us of $8 million as of March 31, 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 in our Balance Sheets.

Derivative Instruments - Deri_2

Derivative Instruments - Derivative Net Presentation on Balance Sheets (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Net Amounts Presented in our Balance Sheets	$ (2,470)	$ (3,741)
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	89	57
Derivative Asset, Gross Amounts Offset in the Balance Sheets	(2)	(5)
Net Amounts Presented in our Balance Sheets	87	52
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(2,577)	(3,814)
Derivative Liability, Gross Amounts Offset in the Balance Sheets	20	21
Net Amounts Presented in our Balance Sheets	$ (2,557)	$ (3,793)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Accrued Liabilities, Current [Abstract]
Natural gas purchases	$ 406	$ 1,017
Interest costs and related debt fees	118	165
Liquefaction Project costs	80	125
Other accrued liabilities	6	7
Total accrued liabilities	$ 610	$ 1,314

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		Mar. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 12,132	$ 12,132
Long-Term Debt, Current Maturities	[1]	(60)	0
Long-term portion of unamortized premium, discount and debt issuance costs, net		(87)	(92)
Long-Term Debt, Total		11,985	12,040
Long Term Debt Current Gross		60
Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		12,132	12,132
2024 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage		5.75%
2025 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 2,000	2,000
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2026 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage		5.875%
2027 Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 1,500	1,500
Debt Instrument, Interest Rate, Stated Percentage		5%
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
[1] As of March 31, 2023, $60 million of debt with contractual maturities of greater than one year was classified as current portion of long-term debt based on our intent and ability to repay the debt with cash that was on hand at March 31, 2023, including repurchases of debt subsequent to the balance sheet date and through April 26, 2023

Debt - Credit Facilities (Detai

Debt - Credit Facilities (Details) $ in Millions		3 Months Ended
		Mar. 31, 2023 USD ($) unit Rate	Dec. 31, 2022 USD ($)
Line of Credit Facility [Line Items]
Outstanding balance		$ 12,132	$ 12,132
Debt, Minimum Historical Debt Service Coverage Ratio And Projected Debt Service Coverage Ratio | unit		1.25
Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Total facility size		$ 1,200
Outstanding balance		0	$ 0
Letters of credit issued		329
Available commitment		$ 871
Debt Instrument, Description of Variable Rate Basis		LIBOR or base rate
Debt Instrument, Maturity Date		Mar. 19, 2025
Working Capital Facility [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	[1]	0.10%
Working Capital Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Commitment Fee Percentage	[1]	0.30%
Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1]	1.125%
Working Capital Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1]	1.75%
Working Capital Facility [Member] | Base Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1]	0.125%
Working Capital Facility [Member] | Base Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate | Rate	[1]	0.75%
[1]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
	Mar. 31, 2023	Mar. 31, 2022
Debt Disclosure [Abstract]
Total interest cost	$ 163	$ 177
Capitalized interest	(2)	(21)
Total interest expense, net of capitalized interest	$ 161	$ 156

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - Senior Notes [Member] - USD ($) $ in Millions		Mar. 31, 2023	Dec. 31, 2022
Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	$ 10,780	$ 10,780
Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	1,352	1,352
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]	10,718	10,569
Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes, Estimated Fair Value	[2]	$ 1,241	$ 1,224
[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 - Schedule of Disaggre

Revenues - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,867	$ 3,245
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,106	2,488
LNG—affiliate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 761	$ 757

Revenues - Contract Assets and

Revenues - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 1	$ 1
Change In Contract With Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	132
Cash received but not yet recognized in revenue	72
Revenue recognized from prior period deferral	(132)
Deferred revenue, end of period	72
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

Revenues - Schedule of Transact

Revenues - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022	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]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 51.7
LNG [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		61%	67%
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]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 49.9
Weighted Average Recognition Timing	[1]	8 years
LNG—affiliate
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		73%	100%
LNG—affiliate | 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				$ 2
Weighted Average Recognition Timing	[1]			2 years
LNG—affiliate | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 1.8
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.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022
Related Party Transaction [Line Items]
Revenues from contracts with customers		$ 2,867	$ 3,245
Cost of sales—affiliate		33	18
Operating and maintenance expense—affiliate		124	117
Operating and maintenance expense—related party		16	12
General and administrative expense—affiliate		16	17
LNG—affiliate
Related Party Transaction [Line Items]
Revenues from contracts with customers		761	757
Cheniere Marketing Agreements [Member] | LNG—affiliate
Related Party Transaction [Line Items]
Revenues from contracts with customers	[1]	761	745
Contracts for Sale and Purchase of Natural Gas And LNG [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	[2]	19	5
Contracts for Sale and Purchase of Natural Gas And LNG [Member] | LNG—affiliate
Related Party Transaction [Line Items]
Revenues from contracts with customers	[2]	0	12
Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate	[3]	14	13
Operating and maintenance expense—affiliate	[3]	68	66
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	[4]	21	20
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate	[5]	35	31
General and administrative expense—affiliate	[5]	16	17
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—related party	[6]	$ 16	$ 12
[1]We primarily sell LNG to Cheniere Marketing under SPAs and letter agreements at a price equal to 115% of Henry Hub plus a fixed fee, except for an SPA associated with an IPM agreement for which pricing is linked to international natural gas prices. We also have a master SPA agreement with Cheniere Marketing that allows us to sell and purchase LNG with Cheniere Marketing by executing and delivering confirmations under this agreement. As of March 31, 2023 and December 31, 2022, we had $263 million and $551 million of trade receivables—affiliate, respectively, under these agreements with Cheniere Marketing. In addition, we have 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 the greater of: (a) 115% of the applicable natural gas feedstock purchase price or (b) an FOB U.S. Gulf Coast LNG market price.[2]We have agreements with SPLNG, CTPL and Corpus Christi Liquefaction, LLC (“CCL”) that allow us to sell and purchase natural gas and LNG with each party. Natural gas purchased under these agreements is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process.[3]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 (a portion of which is indexed for inflation), continuing until at least May 2036. Additionally, we are required to reimburse SPLNG for our proportionate share of ad valorem taxes incurred based on our contracted share of SPLNG’s regasification capacity. CQP has guaranteed our obligations under our TUA.[4]To ensure we are able to transport adequate natural gas feedstock to the Sabine Pass LNG Terminal, we have transportation agreements to secure firm pipeline transportation capacity with CTPL, a wholly owned subsidiary of CQP, and third party pipeline companies.[5]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. Prior to the substantial completion of each Train of the Liquefaction Project, our payments under the services agreements were primarily based on a cost reimbursement structure, and following the completion of each Train, our payments include a fixed monthly fee (indexed for inflation) per mtpa in addition to the reimbursement of costs. As of March 31, 2023 and December 31, 2022, we had $131 million and $151 million of advances to affiliates, respectively, under the services agreements. The non-reimbursement amounts incurred under these agreements are recorded in general and administrative expense—affiliate.[6]We are 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. This related party is partially owned by the investment management company that indirectly acquired a portion of CQP’s limited partner interests in September 2020. We recorded accrued liabilities—related party of $5 million and $6 million as of March 31, 2023 and December 31, 2022, respectively, with this related party.

Related Party Transactions - Ta

Related Party Transactions - Table Footnotes (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) bcf / d	Dec. 31, 2022 USD ($)
Related Party Transaction [Line Items]
Trade receivables—affiliate	$ 263	$ 553
Advances to affiliate	131	151
Accrued liabilities—related party	5	6
Due to affiliates	38	80
Service Agreements [Member]
Related Party Transaction [Line Items]
Advances to affiliate	131	151
Natural Gas Transportation and Storage Agreements [Member]
Related Party Transaction [Line Items]
Accrued liabilities—related party	$ 5	6
Affiliated Entity [Member] | Facility Swap Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
Cheniere Marketing International, LLP | Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
Trade receivables—affiliate	$ 263	$ 551
SPLNG [Member] | Terminal Use Agreement [Member]
Related Party Transaction [Line Items]
Regasification Capacity | bcf / d	2
Related Party Transaction, Committed Annual Fee	$ 250

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details) - USD ($)	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Operating Lease Liability Noncurrent—Affiliate	$ 15,000,000		$ 15,000,000
SPLNG [Member] | LNG Site Sublease Agreement [Member]
Related Party Transaction [Line Items]
Annual Sublease Payment	$ 1,000,000
Review Period for Inflation Adjustment	5 years
SPLNG [Member] | Cooperation Agreement [Member]
Related Party Transaction [Line Items]
Non-cash distributions to affiliates for conveyance of assets	$ 0	$ 0
Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net	$ 0

Customer Concentration - Schedu

Customer Concentration - Schedule of Customer Concentration (Details) - Customer Concentration Risk [Member]	3 Months Ended		12 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	28%	29%
Customer A [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	30%		28%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%	14%
Customer B [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	23%		18%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	17%	18%
Customer C [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%
Customer D [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%	15%
Customer D [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%		18%
Customer E [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage		10%
Customer F [Member] | Accounts Receivable, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0%		13%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) $ in Millions		1 Months Ended	3 Months Ended
	Mar. 15, 2022 USD ($)	Mar. 31, 2022 MMBTU	Mar. 31, 2023 USD ($)	Mar. 31, 2022 USD ($)	Dec. 31, 2022 USD ($)
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized			$ 202	$ 130
Unpaid purchases of property, plant and equipment			39	205
Nonmonetary Transaction [Line Items]
Distributions for Novated IPM Agreement				$ 2,712
Current derivative liabilities			400		$ 769
Derivative liabilities			$ 2,157		$ 3,024
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