Cheniere Corpus Christi 10-Q 2 Nov 22 2022 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2022 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	333-215435
Entity Registrant Name	Cheniere Corpus Christi Holdings, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	47-1929160
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	0001693317
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
No Trading Symbol Flag	true
Entity Common Stock, Shares Outstanding	0

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues
Revenues	$ 2,863	$ 1,538	$ 7,228	$ 3,578
Revenues from contracts with customers	2,863	1,541	7,221	3,581
Operating costs and expenses
Cost of sales (excluding items shown separately below)	5,929	1,608	10,712	2,593
Cost of sales—affiliate	47	12	95	49
Cost of sales—related party	0	53	0	124
Operating and maintenance expense	119	112	350	315
Operating and maintenance expense—affiliate	28	25	86	77
Operating and maintenance expense—related party	2	2	7	7
General and administrative expense	2	2	6	5
General and administrative expense—affiliate	11	8	27	20
Depreciation and amortization expense	112	110	334	309
Other	1	1	5	2
Total operating costs and expenses	6,251	1,933	11,622	3,501
Income (loss) from operations	(3,388)	(395)	(4,394)	77
Other income (expense)
Interest expense, net of capitalized interest	(106)	(117)	(340)	(328)
Loss on modification or extinguishment of debt	(6)	(9)	(36)	(9)
Interest rate derivative gain (loss), net	0	(2)	2	(3)
Other income, net	2	0	3	0
Total other expense	(110)	(128)	(371)	(340)
Net loss	(3,498)	(523)	(4,765)	(263)
LNG [Member]
Revenues
Revenues	1,737	1,029	4,668	2,470
Revenues from contracts with customers	1,737	1,032	4,661	2,473
LNG—affiliate [Member]
Revenues
Revenues from contracts with customers	$ 1,126	$ 509	$ 2,560	$ 1,108

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Current assets
Restricted cash and cash equivalents	$ 202	$ 44
Trade and other receivables, net of current expected credit losses	400	280
Accounts receivable—affiliate	599	315
Advances to affiliate	101	128
Inventory	138	156
Current derivative assets	23	17
Margin deposits	93	13
Other current assets	23	15
Total current assets	1,579	968
Property, plant and equipment, net of accumulated depreciation	13,392	12,607
Debt issuance and deferred financing costs, net of accumulated amortization	41	7
Derivative assets	13	37
Other non-current assets, net	215	145
Total assets	15,240	13,764
Current liabilities
Accounts payable	156	119
Accrued liabilities	1,080	631
Accrued liabilities—related party	1	1
Current debt, net of discount and debt issuance costs	0	366
Due to affiliates	35	35
Current derivative liabilities	1,901	668
Other current liabilities	1	1
Total current liabilities	3,174	1,821
Long-term debt, net of discount and debt issuance costs	8,369	9,986
Derivative liabilities	6,973	638
Other non-current liabilities	67	38
Other non-current liabilities—affiliate	3	0
Member’s equity (deficit)	(3,346)	1,281
Total liabilities and member’s equity (deficit)	$ 15,240	$ 13,764

Consolidated Statements of Memb

Consolidated Statements of Member's Equity - USD ($) $ in Millions	Total	Cheniere CCH HoldCo I, LLC [Member]
Member's equity, beginning of period at Dec. 31, 2020	$ 2,624	$ 2,624
Net income (loss)	331	331
Member's equity, end of period at Mar. 31, 2021	2,955	2,955
Member's equity, beginning of period at Dec. 31, 2020	2,624	2,624
Net income (loss)	(263)
Member's equity, end of period at Sep. 30, 2021	1,743	1,743
Member's equity, beginning of period at Mar. 31, 2021	2,955	2,955
Distributions	337	337
Net income (loss)	(71)	(71)
Member's equity, end of period at Jun. 30, 2021	2,547	2,547
Distributions	(281)	(281)
Net income (loss)	(523)	(523)
Member's equity, end of period at Sep. 30, 2021	1,743	1,743
Member's equity, beginning of period at Dec. 31, 2021	1,281	1,281
Contribution for net gain on extinguishment of debt	138	138
Net income (loss)	(740)	(740)
Member's equity, end of period at Mar. 31, 2022	679	679
Member's equity, beginning of period at Dec. 31, 2021	1,281	1,281
Net income (loss)	(4,765)
Member's equity, end of period at Sep. 30, 2022	(3,346)	(3,346)
Member's equity, beginning of period at Mar. 31, 2022	679	679
Contribution for net gain on extinguishment of debt	801	801
Contribution of CCL Stage III entity	(1,482)	(1,482)
Net income (loss)	(527)	(527)
Member's equity, end of period at Jun. 30, 2022	(529)	(529)
Contribution for net gain on extinguishment of debt	681	681
Net income (loss)	(3,498)	(3,498)
Member's equity, end of period at Sep. 30, 2022	$ (3,346)	$ (3,346)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Cash flows from operating activities
Net loss	$ (4,765)	$ (263)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization expense	334	309
Amortization of discount and debt issuance costs	15	18
Loss on modification or extinguishment of debt	36	9
Total losses on derivatives instruments, net	5,754	987
Total gains on derivatives, net—related party	0	(13)
Net cash used for settlement of derivative instruments	(106)	(69)
Other	4	3
Changes in operating assets and liabilities:
Trade and other receivables, net of current expected credit losses	(120)	(72)
Accounts receivable—affiliate	(284)	(96)
Advances to affiliate	(25)	43
Inventory	16	(32)
Margin deposits	(80)	0
Accounts payable and accrued liabilities	462	316
Accrued liabilities—related party	0	8
Due to affiliates	(1)	0
Deferred revenue	32	0
Other, net	(38)	(54)
Net cash provided by operating activities	1,234	1,094
Cash flows from investing activities
Property, plant and equipment	(618)	(221)
Other	0	(2)
Net cash used in investing activities	(618)	(223)
Cash flows from financing activities
Proceeds from issuances of debt	440	750
Repayments of debt	(2,419)	(1,006)
Debt issuance and deferred financing costs	(44)	(3)
Debt extinguishment costs	(18)	(5)
Contributions	1,583	0
Distributions	0	(618)
Net cash used in financing activities	(458)	(882)
Net increase (decrease) in restricted cash and cash equivalents	158	(11)
Restricted cash and cash equivalents—beginning of period	44	70
Restricted cash and cash equivalents—end of period	$ 202	$ 59

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION We operate a natural gas liquefaction and export facility located near Corpus Christi, Texas (the “Corpus Christi LNG Terminal”) through CCL, which has three operational Trains for a total production capacity of approximately 15 mtpa of LNG, three LNG storage tanks and two marine berths. Additionally, we are constructing an expansion of the Corpus Christi LNG Terminal (the “Corpus Christi Stage 3 Project”) for up to seven midscale Trains with an expected total production capacity of over 10 mtpa of LNG. CCL Stage III, CCL and CCP received approval from FERC in November 2019 to site, construct and operate the Corpus Christi Stage 3 Project. In March 2022, CCL Stage III issued limited notice to proceed to Bechtel Energy Inc. (“Bechtel”) to commence early engineering, procurement and site works. In June 2022, Cheniere’s board of directors made a positive FID with respect to the investment in the construction and operation of the Corpus Christi Stage 3 Project and issued a full notice to proceed with construction to Bechtel effective June 16, 2022. In connection with the positive FID, CCL Stage III, through which Cheniere was developing and constructing the Corpus Christi Stage 3 Project, was contributed to us from Cheniere (the “Contribution”) on June 15, 2022. Immediately following the Contribution, CCL Stage III was merged with and into CCL (the “Merger”), the surviving entity of the merger and our wholly owned subsidiary. Refer to Note 2—CCL Stage III Contribution and Merger for additional information on the Contribution and Merger of CCL Stage III. Through our subsidiary CCP, we also own a 21.5-mile natural gas supply pipeline that interconnects the Corpus Christi LNG Terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline” and together with the existing operational Trains, midscale Trains, storage tanks and marine berths, the “Liquefaction Project”). 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 Corpus Christi LNG Terminal which provides opportunity for further liquefaction capacity expansion. In August 2022, CCH and another subsidiary of Cheniere 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 two midscale Trains with an expected total production capacity of approximately 3 mtpa of LNG. 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 FID. Basis of Presentation The accompanying unaudited Consolidated Financial Statements of CCH 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 Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2021 . Results of operations for the three and nine months ended September 30, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022. We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is included in the consolidated federal income tax return of Cheniere. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Consolidated 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 contracts expected to arise from the market transition from LIBOR to alternative reference rates. The standard is effective from March 12, 2020 to December 31, 2022. We had interest rate swaps and various credit facilities indexed to LIBOR, as further described in Note 7—Derivative Instruments and Note 9—Debt , respectively. In June 2022, we amended our credit facilities to bear interest at a variable rate per annum based on SOFR as a result of the expected LIBOR transition. Since adoption of the standard, we elected to apply the optional expedients as applicable to certain modified facilities; however, the impact of applying the optional expedients was not material, and the transition to SOFR or other replacement rate indexes does not have a material impact on our cash flows.

CCL Stage III Contribution and

CCL Stage III Contribution and Merger	9 Months Ended
	Sep. 30, 2022
Business Combination and Asset Acquisition [Abstract]
CCL Stage III Contribution and Merger	CCL STAGE III CONTRIBUTION AND MERGER As described in Note 1—Nature of Operations and Basis of Presentation , the Contribution of the CCL Stage III legal entity to us from Cheniere occurred on June 15, 2022, which was immediately followed by the Merger, in which CCL Stage III was merged with and into CCL, with CCL continuing as the surviving company. The Contribution was accounted for as a common control transaction as the assets and liabilities were transferred between entities under Cheniere’s control. As a result, the net liability transfer was recognized as a contribution in our Consolidated Statement of Member’s Equity (Deficit) and at the historical basis of Cheniere on June 15, 2022 in our Consolidated Balance Sheets. The Contribution has been presented prospectively as we have concluded that the Contribution did not represent a change in our reporting entity, primarily as we concluded that CCL Stage III did not constitute a business under FASB topic Accounting Standards Codification 805, Business Combinations . The Merger had no impact on our Consolidated Financial Statements as it occurred between our consolidated subsidiaries. The net liabilities of CCL Stage III contributed to us and recognized on our Consolidated Balance Sheets on June 15, 2022 consisted of the following (in millions): June 15, 2022 ASSETS Property, plant and equipment, net of accumulated depreciation $ 441 Derivatives assets 112 Other non-current assets, net 19 Total assets $ 572 LIABILITIES Current liabilities Accounts payable $ 3 Due to affiliates 1 Total current liabilities 4 Derivative liabilities 2,050 Total net liabilities contributed $ (1,482) Amended and Restated Debt Agreements In June 2022, in connection with the FID with respect to the Corpus Christi Stage 3 Project referenced above, CCH amended and restated its term loan credit facility (the “CCH Credit Facility”) and its working capital facility (“CCH Working Capital Facility”) to, among other things, (1) increase the commitments to approximately $4.0 billion and $1.5 billion for the CCH Credit Facility and the CCH Working Capital Facility, respectively, (2) extend the maturity of the CCH Credit Facility to the earlier of June 15, 2029 or two years after the substantial completion of the last Train of the Corpus Christi Stage 3 Project and of the CCH Working Capital Facility through June 15, 2027, (3) update the indexed interest rate to SOFR and (4) make certain other changes to the terms and conditions of the existing facility. See Note 9—Debt for additional information on our credit facilities.

Restricted Cash and Cash Equiva

Restricted Cash and Cash Equivalents	9 Months Ended
	Sep. 30, 2022
Restricted Cash and Cash Equivalents [Abstract]
Restricted Cash and Cash Equivalents	RESTRICTED CASH AND CASH EQUIVALENTSRestricted cash and cash equivalents consist of funds that are contractually or legally restricted as to usage or withdrawal. As of September 30, 2022 and December 31, 2021, we had $202 million and $44 million of restricted cash and cash equivalents, respectively.Pursuant to the accounts agreement entered into with the collateral trustee for the benefit of our debt holders, we are required to deposit all cash received into reserve accounts controlled by the collateral trustee.  The usage or withdrawal of such cash is restricted to the payment of liabilities related to the Liquefaction Project and other restricted payments.

Trade and Other Receivables, Ne

Trade and Other Receivables, Net of Current Expected Credit Losses	9 Months Ended
	Sep. 30, 2022
Receivables [Abstract]
Trade and Other Receivables, Net of Current Expected Credit Losses	TRADE AND OTHER RECEIVABLES, NET OF CURRENT EXPECTED CREDIT LOSSES Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2022 2021 Trade receivables $ 309 $ 256 Other receivables 91 24 Total trade and other receivables, net of current expected credit losses $ 400 $ 280

Inventory

Inventory	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Inventory	INVENTORY Inventory consisted of the following (in millions): September 30, December 31, 2022 2021 Materials $ 89 $ 88 LNG 26 45 Natural gas 23 21 Other — 2 Total inventory $ 138 $ 156

Property, Plant and Equipment,

Property, Plant and Equipment, Net of Accumulated Depreciation	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, Net of Accumulated Depreciation	PROPERTY, PLANT AND EQUIPMENT, NET OF ACCUMULATED DEPRECIATION Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2022 2021 LNG terminal Terminal and interconnecting pipeline facilities $ 13,285 $ 13,222 Site and related costs 302 294 Construction-in-process 1,111 66 Accumulated depreciation (1,311) (981) Total LNG terminal, net of accumulated depreciation 13,387 12,601 Fixed assets Fixed assets 24 23 Accumulated depreciation (19) (17) Total fixed assets, net of accumulated depreciation 5 6 Property, plant and equipment, net of accumulated depreciation $ 13,392 $ 12,607 The following table shows depreciation expense and offsets to LNG terminal costs (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Depreciation expense $ 111 $ 111 $ 332 $ 309 Offsets to LNG terminal costs (1) — — — 143 (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

Derivative Instruments	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS We have entered into the following derivative instruments: • interest rate swaps (“Interest Rate Derivatives”) to hedge the exposure to volatility in a portion of the floating-rate interest payments on our CCH Credit Facility, with the last of our Interest Rate Derivatives expiring in May 2022; and • commodity derivatives consisting of natural gas and power supply contracts, including those under our IPM agreements, for the development, commissioning and operation of the Liquefaction Project (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (“Financial Liquefaction Supply Derivatives,” and collectively with the Physical Liquefaction Supply Derivatives, the “Liquefaction Supply Derivatives”). We recognize our derivative instruments as either assets or liabilities and measure those instruments at fair value. None of our derivative instruments are designated as cash flow or fair value hedging instruments, and changes in fair value are recorded within our Consolidated 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 (in millions): Fair Value Measurements as of September 30, 2022 December 31, 2021 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Interest Rate Derivatives liability $ — $ — $ — $ — $ — $ (40) $ — $ (40) Liquefaction Supply Derivatives asset (liability) (76) 19 (8,781) (8,838) 5 4 (1,221) (1,212) We value our Interest Rate Derivatives using an income-based approach utilizing observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data. We value our 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 Physical Liquefaction Supply Derivatives is predominantly driven by observable and unobservable market commodity prices and, as applicable to our natural gas supply contracts, our assessment of the associated events deriving fair value, including, but not limited to, evaluation of whether the respective market exists from the perspective of market participants as infrastructure is developed. We include a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity and volatility. The Level 3 fair value measurements of natural gas positions within our Physical Liquefaction Supply Derivatives could be materially impacted by a significant change in certain natural gas and international LNG prices. The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(8,781) Market approach incorporating present value techniques Henry Hub basis spread $(1.992) - $0.355 / $(0.153) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 89% - 943% / 190% (1) Unobservable inputs were weighted by the relative fair value of the instruments. (2) Spread contemplates U.S. dollar-denominated pricing. Increases or decreases in basis or pricing spreads, in isolation, would decrease or increase, respectively, the fair value of our Physical Liquefaction Supply Derivatives. The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives, including those with related parties (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 (1) 2022 2021 (1) Balance, beginning of period $ (5,006) $ (260) $ (1,221) $ 12 Realized and mark-to-market losses: Included in cost of sales (4,123) (766) (2,727) (1,032) Purchases and settlements: Purchases 1 (1) (5,290) 17 Settlements 346 52 457 28 Transfers out of Level 3, net (2) 1 — — — Balance, end of period $ (8,781) $ (975) $ (8,781) $ (975) Change in unrealized losses relating to instruments still held at end of period $ (4,123) $ (766) $ (2,727) $ (1,032) (1) Includes amounts recorded related to natural gas supply contracts that CCL had with a related party. The agreement ceased to be considered a related party agreement during 2021, as discussed in Note 11—Related Party Transactions . (2) Transferred out of Level 3 as a result of unobservable market for the underlying natural gas purchase agreements. Except for Interest Rate Derivatives, 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 those 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. Interest Rate Derivatives We previously entered into the following Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility, which expired in May 2022: Notional Amounts September 30, 2022 December 31, 2021 Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $— $4.5 billion 2.30% One-month LIBOR The following table shows the effect and location of our Interest Rate Derivatives on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Interest Rate Derivatives Interest rate derivative gain (loss), net $ — $ (2) $ 2 $ (3) Liquefaction Supply Derivatives CCL holds Liquefaction Supply Derivatives which are primarily indexed to the natural gas market and international LNG indices. The remaining terms of the Physical Liquefaction Supply Derivatives range up to 25 years, some of which commence upon the satisfaction of certain events or states of affairs. The terms of the Financial Liquefaction Supply Derivatives range up to approximately three years. The forward notional amount for our Liquefaction Supply Derivatives was approximately 8,137 TBtu and 2,915 TBtu as of September 30, 2022 and December 31, 2021, respectively. The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues $ — $ (3) $ 7 $ (3) Cost of sales (3,883) (733) (5,763) (981) Cost of sales—related party (2) — 6 — 13 (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement as of November 1, 2021 as discussed in Note 11—Related Party Transactions . Fair Value and Location of Derivative Assets and Liabilities on the Consolidated Balance Sheets The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions): September 30, 2022 Interest Rate Derivatives Liquefaction Supply Derivatives (1) Total Consolidated Balance Sheets Location Current derivative assets $ — $ 23 $ 23 Derivative assets — 13 13 Total derivative assets — 36 36 Current derivative liabilities — (1,901) (1,901) Derivative liabilities — (6,973) (6,973) Total derivative liabilities — (8,874) (8,874) Derivative liability, net $ — $ (8,838) $ (8,838) December 31, 2021 Interest Rate Derivatives Liquefaction Supply Derivatives (1) Total Consolidated Balance Sheets Location Current derivative assets $ — $ 17 $ 17 Derivative assets — 37 37 Total derivative assets — 54 54 Current derivative liabilities (40) (628) (668) Derivative liabilities — (638) (638) Total derivative liabilities (40) (1,266) (1,306) Derivative liability, net $ (40) $ (1,212) $ (1,252) (1) Does not include collateral posted with counterparties by us of $93 million and $13 million as of September 30, 2022 and December 31, 2021, respectively, which are included in other current assets in our Consolidated Balance Sheets. Consolidated 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 Consolidated Balance Sheets: Liquefaction Supply Derivatives As of September 30, 2022 Gross assets $ 41 Offsetting amounts (5) Net assets $ 36 Gross liabilities $ (9,349) Offsetting amounts 475 Net liabilities $ (8,874) As of December 31, 2021 Gross assets $ 76 Offsetting amounts (22) Net assets $ 54 Gross liabilities $ (1,295) Offsetting amounts 29 Net liabilities $ (1,266)

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2022
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of the following (in millions): September 30, December 31, 2022 2021 Natural gas purchases $ 844 $ 531 Interest costs and related debt fees 112 7 Liquefaction Project costs 82 43 Other accrued liabilities 42 50 Total accrued liabilities $ 1,080 $ 631

Debt

Debt	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt	DEBT Debt consisted of the following (in millions): September 30, December 31, 2022 2021 Senior Secured Notes: 7.000% due 2024 $ 1,250 $ 1,250 5.875% due 2025 1,500 1,500 5.125% due 2027 (1) 1,500 1,500 3.700% due 2029 (1) 1,492 1,500 3.72% weighted average rate due 2039 (1) 2,699 2,721 Total Senior Secured Notes 8,441 8,471 CCH Credit Facility — 1,728 CCH Working Capital Facility (2) — 250 Total debt 8,441 10,449 Current portion of long-term debt — (117) Short-term debt — (250) Unamortized discount and debt issuance costs, net (72) (96) Total long-term debt, net of discount and debt issuance costs $ 8,369 $ 9,986 (1) Subsequent to September 30, 2022 and through October 31, 2022, Cheniere executed bond repurchases totaling $221 million, inclusive of CCH’s Senior Secured Notes due 2027, 2029 and 2039 on the open market, which were immediately contributed to us from Cheniere and cancelled by us. (2) The CCH Working Capital Facility is classified as short-term debt. Cancellation of CCH Senior Secured Notes Contributed from Cheniere During the three and nine months ended September 30, 2022, Cheniere repurchased $30 million of CCH’s Senior Secured Notes due 2029 and 2039 on the open market, which were immediately contributed to us from Cheniere, and cancelled by us. It was determined that for accounting purposes, Cheniere repurchased the bonds on our behalf as a principal as opposed to as an agent, and thus the debt extinguishment was accounted for as an extinguishment directly with Cheniere. As a result, the net gain on extinguishment of $5 million was recorded as a contribution within our Consolidated Statements of Member’s Equity. Credit Facilities Below is a summary of our credit facilities outstanding as of September 30, 2022 (in millions): CCH Credit Facility (1) CCH Working Capital Facility (1) Total facility size $ 3,260 $ 1,500 Less: Outstanding balance — — Letters of credit issued — 218 Available commitment $ 3,260 $ 1,282 Priority ranking Senior secured Senior secured Interest rate on available balance SOFR plus credit spread adjustment of 0.1% , plus margin of 1.5% or base rate plus 0.5% SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.5% or base rate plus applicable margin Commitment fees on undrawn balance 0.53% 0.18% Maturity date (2) June 15, 2027 (1) In June 2022, we amended and restated the CCH Credit Facility and CCH Working Capital Facility resulting in $20 million of debt extinguishment and modification costs to, among other things, (a) provide incremental commitments of $3.7 billion and $300 million for the CCH Credit Facility and the CCH Working Capital Facility, respectively, in connection with the FID with respect to the Corpus Christi Stage 3 Project, (b) extend the maturity, (c) update the indexed interest rate to SOFR and (d) make certain other changes to the terms and conditions of each existing facility. (2) The CCH Credit Facility matures the earlier of June 15, 2029 or two years after the substantial completion of the last Train of the Corpus Christi Stage 3 Project. Restrictive Debt Covenants The indentures governing our senior notes and other agreements underlying our debt contain customary terms and events of default and certain covenants that, among other things, may limit us and our restricted subsidiaries’ ability to make certain investments or pay dividends or distributions. As of September 30, 2022, we were in compliance with all covenants related to our debt agreements. Interest Expense Total interest expense, net of capitalized interest consisted of the following (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Total interest cost $ 119 $ 118 $ 356 $ 355 Capitalized interest, including amounts capitalized as an allowance for funds used during construction (13) (1) (16) (27) Total interest expense, net of capitalized interest $ 106 $ 117 $ 340 $ 328 Fair Value Disclosures The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 6,470 $ 6,049 $ 6,500 $ 7,095 Senior notes — Level 3 (2) 1,971 1,797 1,971 2,227 (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 credit facilities 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	9 Months Ended
	Sep. 30, 2022
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, 2022 2021 2022 2021 Revenues from contracts with customers LNG revenues $ 1,737 $ 1,032 $ 4,661 $ 2,473 LNG revenues—affiliate 1,126 509 2,560 1,108 Total revenues from contracts with customers 2,863 1,541 7,221 3,581 Net derivative gain (loss) (1) — (3) 7 (3) Total revenues $ 2,863 $ 1,538 $ 7,228 $ 3,578 (1) See Note 7—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 and other non-current assets, net on our Consolidated Balance Sheets (in millions): September 30, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 132 $ 104 The following table reflects the changes in our contract liabilities, which we classify as other non-current liabilities on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue, beginning of period $ 35 Cash received but not yet recognized in revenue 67 Revenue recognized from prior year end deferral (35) Deferred revenue, end of period $ 67 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, 2022 December 31, 2021 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.4 11 $ 31.7 9 LNG revenues—affiliate 1.3 9 1.1 10 Total revenues $ 52.7 $ 32.8 (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 73% and 59% of our LNG revenues from contracts included in the table above during the three months ended September 30, 2022 and 2021, respectively, and approximately 70% and 53% of our LNG revenues from contracts included in the table above during the nine months ended September 30, 2022 and 2021, respectively, were related to variable consideration received from customers. Approximately 89% and 87% of our LNG revenues—affiliate from contracts included in the table above during the three and nine months ended September 30, 2022, respectively, were related to variable consideration received from customers. None of our LNG revenues—affiliates from the contract included in the table above were related to variable consideration received from customers during the three and nine months ended September 30, 2021. We may enter into contracts to sell LNG that are conditioned upon one or both of the parties achieving certain milestones such as reaching FID on a certain liquefaction Train, obtaining financing or achieving substantial completion of a Train and any related facilities. These contracts are considered completed contracts for revenue recognition purposes and are included in the transaction price above when the conditions are considered probable of being met.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2022
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Below is a summary of our related party transactions as reported on our Consolidated Statements of Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 1,022 $ 500 $ 2,394 $ 1,079 Contracts for Sale and Purchase of Natural Gas and LNG 104 9 166 29 Total LNG revenues—affiliate 1,126 509 2,560 1,108 Cost of sales—affiliate Contracts for Sale and Purchase of Natural Gas and LNG 47 12 95 18 Cheniere Marketing Agreements — — — 31 Total cost of sales—affiliate 47 12 95 49 Cost of sales—related party Natural Gas Supply Agreement (1) — 53 — 124 Operating and maintenance expense—affiliate Services Agreements 28 24 86 76 Land Agreements — 1 — 1 Total operating and maintenance expense—affiliate 28 25 86 77 Operating and maintenance expense—related party Natural Gas Transportation Agreements 2 2 7 7 General and administrative expense—affiliate Services Agreements 11 8 27 20 (1) Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement during 2021, as discussed below. We had $35 million due to affiliates as of both September 30, 2022 and December 31, 2021, under agreements with affiliates, as described below. Cheniere Marketing Agreements Cheniere Marketing SPA CCL has an amended and restated fixed price SPA with Cheniere Marketing International LLP (“Cheniere Marketing”), a wholly owned subsidiary of Cheniere, (the “Cheniere Marketing Base SPA”) with a term of 20 years which allows Cheniere Marketing to purchase, at its option, (1) up to a cumulative total of 150 TBtu of LNG within the commissioning periods for Trains 1 through 3 and (2) any excess LNG produced by the Liquefaction Project that is not committed to customers under third party SPAs. Under the Cheniere Marketing Base SPA, Cheniere Marketing may, without charge, elect to suspend deliveries of cargoes (other than commissioning cargoes) scheduled for any month under the applicable annual delivery program by providing specified notice in advance. Additionally, CCL has: (1) a fixed price SPA with a term through 2043 with Cheniere Marketing which allows them to purchase volumes of approximately 15 TBtu per annum of LNG and (2) an SPA with Cheniere Marketing for approximately 44 TBtu of LNG with a maximum term up to 2026 associated with the integrated production marketing gas supply agreement between CCL and EOG Resources, Inc. As of September 30, 2022 and December 31, 2021, CCL had $593 million and $314 million of accounts receivable—affiliate, respectively, under these agreements with Cheniere Marketing. In association with an IPM agreement between CCL and ARC Resources U.S. Corp, CCL entered into an SPA in June 2022 with Cheniere Marketing to sell Cheniere Marketing approximately 44 TBtu per annum of LNG at a price linked to the Platts Japan Korea Marker (“JKM”), for a term of 15 years commencing with commercial operations of Train 7 of the Corpus Christi Stage 3 Project. Cheniere Marketing Letter Agreement CCL has a letter agreement with Cheniere Marketing for the sale of up to 48 cargoes scheduled to be delivered between 2023 and 2025 at a price equal to 115% of Henry Hub plus $1.97 per MMBtu. Facility Swap Agreement 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 (1) 115% of the applicable natural gas feedstock purchase price or (2) an FOB U.S. Gulf Coast LNG market price, whichever is greater. Services Agreements Gas and Power Supply Services Agreement (“G&P Agreement”) CCL has a G&P Agreement with Cheniere Energy Shared Services, Inc. (“Shared Services”), a wholly owned subsidiary of Cheniere, pursuant to which Shared Services will manage the gas and power procurement requirements of CCL. The services include, among other services, exercising the day-to-day management of CCL’s natural gas and power supply requirements, negotiating agreements on CCL’s behalf and providing other administrative services. Prior to the substantial completion of each Train of the Liquefaction Project, no monthly fee payment is required except for reimbursement of operating expenses. After substantial completion of each Train of the Liquefaction Project, CCL will pay, in addition to the reimbursement of related expenses, a fixed monthly fee of $30,000 (indexed for inflation) per mtpa for services performed with respect to such Train. Operation and Maintenance Agreements (“O&M Agreements”) CCL has an O&M Agreement (“CCL O&M Agreement”) with Cheniere LNG O&M Services, LLC (“O&M Services”), a wholly owned subsidiary of Cheniere, pursuant to which CCL receives all of the necessary services required to construct, operate and maintain the Liquefaction Project. The services to be provided include, among other services, preparing and maintaining staffing plans, identifying and arranging for procurement of equipment and materials, overseeing contractors, administering various agreements, information technology services and other services required to operate and maintain the Liquefaction Project. Prior to the substantial completion of each Train of the Liquefaction Project, no monthly fee payment is required except for reimbursement of operating expenses. After substantial completion of each Train of the Liquefaction Project, CCL will pay, in addition to the reimbursement of related expenses, a fixed monthly fee of $53,000 (indexed for inflation) per mtpa for services performed with respect to such Train. CCP has an O&M Agreement (“CCP O&M Agreement”) with O&M Services pursuant to which CCP receives all of the necessary services required to construct, operate and maintain the Corpus Christi Pipeline. The services to be provided include, among other services, preparing and maintaining staffing plans, identifying and arranging for procurement of equipment and materials, overseeing contractors, information technology services and other services required to operate and maintain the Corpus Christi Pipeline. CCP is required to reimburse O&M Services for all operating expenses incurred on behalf of CCP. Management Services Agreements (“MSAs”) CCL has an MSA with Shared Services pursuant to which Shared Services manages the construction and operation of the Liquefaction Project, excluding those matters provided for under the G&P Agreement and the CCL O&M Agreement. The services include, among other services, exercising the day-to-day management of CCL’s affairs and business, managing CCL’s regulatory matters, preparing status reports, providing contract administration services for all contracts associated with the Liquefaction Project and obtaining insurance. Prior to the substantial completion of each Train of the Liquefaction Project, no monthly fee payment is required except for reimbursement of expenses. After substantial completion of each Train, CCL will pay, in addition to the reimbursement of related expenses, a monthly fee of $157,000 (adjusted for inflation) per mtpa for services performed with respect to such Train. CCP has an MSA with Shared Services pursuant to which Shared Services manages CCP’s operations and business, excluding those matters provided for under the CCP O&M Agreement. The services include, among other services, exercising the day-to-day management of CCP’s affairs and business, managing CCP’s regulatory matters, preparing status reports, providing contract administration services for all contracts associated with the Corpus Christi Pipeline and obtaining insurance. CCP is required to reimburse Shared Services for the aggregate of all costs and expenses incurred in the course of performing the services under the MSA. Natural Gas Supply Agreement CCL was party to a natural gas supply agreement with a related party in the ordinary course of business, to obtain a fixed minimum daily volume of feed gas for the operation of the Liquefaction Project. The related party entity was acquired by a non-related party on November 1, 2021, therefore, as of such date, this agreement ceased to be considered a related party agreement. Natural Gas Transportation Agreements Agreements with Related Party CCL is party to natural gas transportation agreements with a related party in the ordinary course of business for the operation of the Liquefaction Project, for a period of 10 years which began in May 2020. Cheniere accounts for its investment in this related party as an equity method investment. CCL recorded accrued liabilities—related party of $1 million as of both September 30, 2022 and December 31, 2021 with this related party. CCL is party to a natural gas transportation agreement with a related party in the ordinary course of business for the operation of the Liquefaction Project, with an initial term of 20 years with extension rights. Cheniere has an equity interest in this related party. Contracts for Sale and Purchase of Natural Gas and LNG CCL has an agreement with Sabine Pass Liquefaction, LLC that allows the parties to sell and purchase natural gas with each other. Natural gas purchased under this agreement is initially recorded as inventory and then to cost of sales—affiliate upon its sale, except for purchases related to commissioning activities which are capitalized as LNG terminal construction-in-process. Natural gas sold under this agreement is recorded as LNG revenues—affiliate. CCL also has an agreement with Midship Pipeline Company, LLC that allows them to sell and purchase natural gas with each other. Land Agreements Rental Agreements CCL has agreements with Cheniere Land Holdings, LLC (“CLH”), a wholly owned subsidiary of Cheniere, to rent the land owned by CLH for the Liquefaction Project. The total annual rental payment is $0.6 million with terms through 2031. Easement Agreements CCL has agreements with CLH which grant CCL easements on land owned by CLH for the Liquefaction Project. The total annual payment for easement agreements is $0.1 million, excluding any previously paid one-time payments, and the terms of the agreements range from three Master License Agreements CCL has agreements with CLH which grant CCL licenses to enter certain land owned by CLH for the Liquefaction Project. The aggregate annual payment for these agreements is $1 million, commencing January 2022 through completion of construction at the Liquefaction Project, subject to early termination. Dredge Material Disposal Agreement CCL has a dredge material disposal agreement with CLH that terminates in 2042 which grants CCL permission to use land owned by CLH for the deposit of dredge material from the construction and maintenance of the Liquefaction Project. Under the terms of the agreement, CCL will pay CLH $0.50 per cubic yard of dredge material deposits up to 5.0 million cubic yards and $4.62 per cubic yard for any quantities above that. Tug Hosting Agreement CCL has a tug hosting agreement with Corpus Christi Tug Services, LLC (“Tug Services”), a wholly owned subsidiary of Cheniere, to provide certain marine structures, support services and access necessary at the Liquefaction Project for Tug Services to provide its customers with tug boat and marine services. Tug Services is required to reimburse CCL for any third party costs incurred by CCL in connection with providing the goods and services. State Tax Sharing Agreements CCL and CCP each have a state tax sharing agreement with Cheniere. Under these agreements, Cheniere has agreed to prepare and file all state and local tax returns which each of the entities 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, each of the respective entities will pay to Cheniere an amount equal to the state and local tax that each of the entities would be required to pay if its 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 agreements. The agreements for both CCL and CCP were effective for tax returns due on or after May 2015. Equity Contribution Agreements We entered into equity contribution agreements with Cheniere and certain of its subsidiaries (the “Equity Contribution Agreements”) pursuant to which Cheniere agreed to contribute any of CCH’s Senior Secured Notes that Cheniere has repurchased to CCH. During the three and nine months ended September 30, 2022, Cheniere repurchased a total of $30 million of the outstanding principal amount of CCH’s Senior Secured Notes due 2029 and 2039 on the open market, which were immediately contributed under the Equity Contribution Agreements to us from Cheniere and cancelled by us.

Customer Concentration

Customer Concentration	9 Months Ended
	Sep. 30, 2022
Risks and Uncertainties [Abstract]
Customer Concentration	CUSTOMER CONCENTRATION The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2022 2021 2022 2021 2022 2021 Customer A 20% 22% 22% 23% * * Customer B 15% 13% 15% 16% * * Customer C 15% 16% 14% 16% 10% * Customer D * * * * 22% 31% Customer E * * * * 10% 11% Customer F 13% 10% * * * * Customer G * * * * 10% * Customer H 12% * 10% * * * * Less than 10%

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2022
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	SUPPLEMENTAL CASH FLOW INFORMATION The following table provides supplemental disclosure of cash flow information (in millions): Nine Months Ended September 30, 2022 2021 Cash paid during the period for interest on debt, net of amounts capitalized $ 225 $ 219 Right-of-use assets obtained in exchange for new operating lease liabilities 3 — Non-cash investing activity: Transfers of property, plant and equipment in exchange for other non-current assets 17 — Contributions of assets from affiliates 7 — Non-cash financing activity: Cancellation of CCH Senior Secured Notes contributed to us from Cheniere (see Note 9 ) 30 — Contribution of CCL Stage III entity to us from Cheniere (see Note 2 ) (1,482) — The balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate) was $42 million and $15 million as of September 30, 2022 and 2021, respectively.

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation, Policy	Basis of Presentation The accompanying unaudited Consolidated Financial Statements of CCH 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 Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the fiscal year ended December 31, 2021 . Results of operations for the three and nine months ended September 30, 2022 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2022.
Income Taxes, Policy	We are a disregarded entity for federal and state income tax purposes. Our taxable income or loss, which may vary substantially from the net income or loss reported on our Consolidated Statements of Operations, is included in the consolidated federal income tax return of Cheniere. Accordingly, no provision or liability for federal or state income taxes is included in the accompanying Consolidated 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 contracts expected to arise from the market transition from LIBOR to alternative reference rates. The standard is effective from March 12, 2020 to December 31, 2022. We had interest rate swaps and various credit facilities indexed to LIBOR, as further described in Note 7—Derivative Instruments and Note 9—Debt , respectively. In June 2022, we amended our credit facilities to bear interest at a variable rate per annum based on SOFR as a result of the expected LIBOR transition. Since adoption of the standard, we elected to apply the optional expedients as applicable to certain modified facilities; however, the impact of applying the optional expedients was not material, and the transition to SOFR or other replacement rate indexes does not have a material impact on our cash flows.

CCL Stage III Contribution an_2

CCL Stage III Contribution and Merger (Tables)	9 Months Ended
	Sep. 30, 2022
Business Combination and Asset Acquisition [Abstract]
Asset Acquisition	The net liabilities of CCL Stage III contributed to us and recognized on our Consolidated Balance Sheets on June 15, 2022 consisted of the following (in millions): June 15, 2022 ASSETS Property, plant and equipment, net of accumulated depreciation $ 441 Derivatives assets 112 Other non-current assets, net 19 Total assets $ 572 LIABILITIES Current liabilities Accounts payable $ 3 Due to affiliates 1 Total current liabilities 4 Derivative liabilities 2,050 Total net liabilities contributed $ (1,482)

Trade and Other Receivables, _2

Trade and Other Receivables, Net of Current Expected Credit Losses (Tables)	9 Months Ended
	Sep. 30, 2022
Receivables [Abstract]
Schedule of Accounts and Other Receivables	Trade and other receivables, net of current expected credit losses consisted of the following (in millions): September 30, December 31, 2022 2021 Trade receivables $ 309 $ 256 Other receivables 91 24 Total trade and other receivables, net of current expected credit losses $ 400 $ 280

Inventory (Tables)

Inventory (Tables)	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory consisted of the following (in millions): September 30, December 31, 2022 2021 Materials $ 89 $ 88 LNG 26 45 Natural gas 23 21 Other — 2 Total inventory $ 138 $ 156

Property, Plant and Equipment_2

Property, Plant and Equipment, Net of Accumulated Depreciation (Tables)	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment, net of accumulated depreciation consisted of the following (in millions): September 30, December 31, 2022 2021 LNG terminal Terminal and interconnecting pipeline facilities $ 13,285 $ 13,222 Site and related costs 302 294 Construction-in-process 1,111 66 Accumulated depreciation (1,311) (981) Total LNG terminal, net of accumulated depreciation 13,387 12,601 Fixed assets Fixed assets 24 23 Accumulated depreciation (19) (17) Total fixed assets, net of accumulated depreciation 5 6 Property, plant and equipment, net of accumulated depreciation $ 13,392 $ 12,607
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, 2022 2021 2022 2021 Depreciation expense $ 111 $ 111 $ 332 $ 309 Offsets to LNG terminal costs (1) — — — 143 (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 (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair Value of Derivative Assets and Liabilities	The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis (in millions): Fair Value Measurements as of September 30, 2022 December 31, 2021 Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Quoted Prices in Active Markets Significant Other Observable Inputs Significant Unobservable Inputs Total Interest Rate Derivatives liability $ — $ — $ — $ — $ — $ (40) $ — $ (40) Liquefaction Supply Derivatives asset (liability) (76) 19 (8,781) (8,838) 5 4 (1,221) (1,212)
Fair Value Measurement Inputs and Valuation Techniques	The following table includes quantitative information for the unobservable inputs for our Level 3 Physical Liquefaction Supply Derivatives as of September 30, 2022: Net Fair Value Liability Valuation Approach Significant Unobservable Input Range of Significant Unobservable Inputs / Weighted Average (1) Physical Liquefaction Supply Derivatives $(8,781) Market approach incorporating present value techniques Henry Hub basis spread $(1.992) - $0.355 / $(0.153) Option pricing model International LNG pricing spread, relative to Henry Hub (2) 89% - 943% / 190% (1) Unobservable inputs were weighted by the relative fair value of the instruments.
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	The following table shows the changes in the fair value of our Level 3 Physical Liquefaction Supply Derivatives, including those with related parties (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 (1) 2022 2021 (1) Balance, beginning of period $ (5,006) $ (260) $ (1,221) $ 12 Realized and mark-to-market losses: Included in cost of sales (4,123) (766) (2,727) (1,032) Purchases and settlements: Purchases 1 (1) (5,290) 17 Settlements 346 52 457 28 Transfers out of Level 3, net (2) 1 — — — Balance, end of period $ (8,781) $ (975) $ (8,781) $ (975) Change in unrealized losses relating to instruments still held at end of period $ (4,123) $ (766) $ (2,727) $ (1,032) (1) Includes amounts recorded related to natural gas supply contracts that CCL had with a related party. The agreement ceased to be considered a related party agreement during 2021, as discussed in Note 11—Related Party Transactions . (2) Transferred out of Level 3 as a result of unobservable market for the underlying natural gas purchase agreements.
Fair Value of Derivative Instruments by Balance Sheet Location	The following table shows the fair value and location of our derivative instruments on our Consolidated Balance Sheets (in millions): September 30, 2022 Interest Rate Derivatives Liquefaction Supply Derivatives (1) Total Consolidated Balance Sheets Location Current derivative assets $ — $ 23 $ 23 Derivative assets — 13 13 Total derivative assets — 36 36 Current derivative liabilities — (1,901) (1,901) Derivative liabilities — (6,973) (6,973) Total derivative liabilities — (8,874) (8,874) Derivative liability, net $ — $ (8,838) $ (8,838) December 31, 2021 Interest Rate Derivatives Liquefaction Supply Derivatives (1) Total Consolidated Balance Sheets Location Current derivative assets $ — $ 17 $ 17 Derivative assets — 37 37 Total derivative assets — 54 54 Current derivative liabilities (40) (628) (668) Derivative liabilities — (638) (638) Total derivative liabilities (40) (1,266) (1,306) Derivative liability, net $ (40) $ (1,212) $ (1,252)
Derivative Net Presentation on Consolidated Balance Sheets	The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions) for our derivative instruments that are presented on a net basis on our Consolidated Balance Sheets: Liquefaction Supply Derivatives As of September 30, 2022 Gross assets $ 41 Offsetting amounts (5) Net assets $ 36 Gross liabilities $ (9,349) Offsetting amounts 475 Net liabilities $ (8,874) As of December 31, 2021 Gross assets $ 76 Offsetting amounts (22) Net assets $ 54 Gross liabilities $ (1,295) Offsetting amounts 29 Net liabilities $ (1,266)
Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Schedule of Notional Amounts of Outstanding Derivative Positions	We previously entered into the following Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the CCH Credit Facility, which expired in May 2022: Notional Amounts September 30, 2022 December 31, 2021 Weighted Average Fixed Interest Rate Paid Variable Interest Rate Received Interest Rate Derivatives $— $4.5 billion 2.30% One-month LIBOR
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Interest Rate Derivatives on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Interest Rate Derivatives Interest rate derivative gain (loss), net $ — $ (2) $ 2 $ (3)
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Instruments, Gain (Loss)	The following table shows the effect and location of our Liquefaction Supply Derivatives recorded on our Consolidated Statements of Operations (in millions): Gain (Loss) Recognized in Consolidated Statements of Operations Consolidated Statements of Operations Location (1) Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues $ — $ (3) $ 7 $ (3) Cost of sales (3,883) (733) (5,763) (981) Cost of sales—related party (2) — 6 — 13 (1) Does not include the realized value associated with derivative instruments that settle through physical delivery. Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument. (2) Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement as of November 1, 2021 as discussed in Note 11—Related Party Transactions .

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2022
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities consisted of the following (in millions): September 30, December 31, 2022 2021 Natural gas purchases $ 844 $ 531 Interest costs and related debt fees 112 7 Liquefaction Project costs 82 43 Other accrued liabilities 42 50 Total accrued liabilities $ 1,080 $ 631

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Schedule of Debt Instruments	Debt consisted of the following (in millions): September 30, December 31, 2022 2021 Senior Secured Notes: 7.000% due 2024 $ 1,250 $ 1,250 5.875% due 2025 1,500 1,500 5.125% due 2027 (1) 1,500 1,500 3.700% due 2029 (1) 1,492 1,500 3.72% weighted average rate due 2039 (1) 2,699 2,721 Total Senior Secured Notes 8,441 8,471 CCH Credit Facility — 1,728 CCH Working Capital Facility (2) — 250 Total debt 8,441 10,449 Current portion of long-term debt — (117) Short-term debt — (250) Unamortized discount and debt issuance costs, net (72) (96) Total long-term debt, net of discount and debt issuance costs $ 8,369 $ 9,986 (1) Subsequent to September 30, 2022 and through October 31, 2022, Cheniere executed bond repurchases totaling $221 million, inclusive of CCH’s Senior Secured Notes due 2027, 2029 and 2039 on the open market, which were immediately contributed to us from Cheniere and cancelled by us. (2) The CCH Working Capital Facility is classified as short-term debt.
Schedule of Line of Credit Facilities	Below is a summary of our credit facilities outstanding as of September 30, 2022 (in millions): CCH Credit Facility (1) CCH Working Capital Facility (1) Total facility size $ 3,260 $ 1,500 Less: Outstanding balance — — Letters of credit issued — 218 Available commitment $ 3,260 $ 1,282 Priority ranking Senior secured Senior secured Interest rate on available balance SOFR plus credit spread adjustment of 0.1% , plus margin of 1.5% or base rate plus 0.5% SOFR plus credit spread adjustment of 0.1%, plus margin of 1.0% - 1.5% or base rate plus applicable margin Commitment fees on undrawn balance 0.53% 0.18% Maturity date (2) June 15, 2027 (1) In June 2022, we amended and restated the CCH Credit Facility and CCH Working Capital Facility resulting in $20 million of debt extinguishment and modification costs to, among other things, (a) provide incremental commitments of $3.7 billion and $300 million for the CCH Credit Facility and the CCH Working Capital Facility, respectively, in connection with the FID with respect to the Corpus Christi Stage 3 Project, (b) extend the maturity, (c) update the indexed interest rate to SOFR and (d) make certain other changes to the terms and conditions of each existing facility. (2) The CCH Credit Facility matures the earlier of June 15, 2029 or two years after the substantial completion of the last Train of the Corpus Christi Stage 3 Project.
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, 2022 2021 2022 2021 Total interest cost $ 119 $ 118 $ 356 $ 355 Capitalized interest, including amounts capitalized as an allowance for funds used during construction (13) (1) (16) (27) Total interest expense, net of capitalized interest $ 106 $ 117 $ 340 $ 328
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	The following table shows the carrying amount and estimated fair value of our debt (in millions): September 30, 2022 December 31, 2021 Carrying Estimated Carrying Estimated Senior notes — Level 2 (1) $ 6,470 $ 6,049 $ 6,500 $ 7,095 Senior notes — Level 3 (2) 1,971 1,797 1,971 2,227 (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)	9 Months Ended
	Sep. 30, 2022
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, 2022 2021 2022 2021 Revenues from contracts with customers LNG revenues $ 1,737 $ 1,032 $ 4,661 $ 2,473 LNG revenues—affiliate 1,126 509 2,560 1,108 Total revenues from contracts with customers 2,863 1,541 7,221 3,581 Net derivative gain (loss) (1) — (3) 7 (3) Total revenues $ 2,863 $ 1,538 $ 7,228 $ 3,578 (1) See Note 7—Derivative Instruments
Contract with Customer, Asset	The following table shows our contract assets, net of current expected credit losses, which are classified as other current assets and other non-current assets, net on our Consolidated Balance Sheets (in millions): September 30, December 31, 2022 2021 Contract assets, net of current expected credit losses $ 132 $ 104
Contract Balances Reconciliation	The following table reflects the changes in our contract liabilities, which we classify as other non-current liabilities on our Consolidated Balance Sheets (in millions): Nine Months Ended September 30, 2022 Deferred revenue, beginning of period $ 35 Cash received but not yet recognized in revenue 67 Revenue recognized from prior year end deferral (35) Deferred revenue, end of period $ 67
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, 2022 December 31, 2021 Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) Unsatisfied Transaction Price (in billions) Weighted Average Recognition Timing (years) (1) LNG revenues $ 51.4 11 $ 31.7 9 LNG revenues—affiliate 1.3 9 1.1 10 Total revenues $ 52.7 $ 32.8 (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)	9 Months Ended
	Sep. 30, 2022
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Below is a summary of our related party transactions as reported on our Consolidated Statements of Operations (in millions): Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 LNG revenues—affiliate Cheniere Marketing Agreements $ 1,022 $ 500 $ 2,394 $ 1,079 Contracts for Sale and Purchase of Natural Gas and LNG 104 9 166 29 Total LNG revenues—affiliate 1,126 509 2,560 1,108 Cost of sales—affiliate Contracts for Sale and Purchase of Natural Gas and LNG 47 12 95 18 Cheniere Marketing Agreements — — — 31 Total cost of sales—affiliate 47 12 95 49 Cost of sales—related party Natural Gas Supply Agreement (1) — 53 — 124 Operating and maintenance expense—affiliate Services Agreements 28 24 86 76 Land Agreements — 1 — 1 Total operating and maintenance expense—affiliate 28 25 86 77 Operating and maintenance expense—related party Natural Gas Transportation Agreements 2 2 7 7 General and administrative expense—affiliate Services Agreements 11 8 27 20 (1) Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement during 2021, as discussed below.

Customer Concentration (Tables)

Customer Concentration (Tables)	9 Months Ended
	Sep. 30, 2022
Risks and Uncertainties [Abstract]
Schedule of Revenue and Accounts Receivable by Major Customers	The following table shows external customers with revenues of 10% or greater of total revenues from external customers and external customers with trade and other receivables, net of current expected credit losses and contract assets, net of current expected credit losses balances of 10% or greater of total trade and other receivables, net of current expected credit losses from external customers and contract assets, net of current expected credit losses from external customers, respectively: Percentage of Total Revenues from External Customers Percentage of Trade and Other Receivables, Net and Contract Assets, Net from External Customers Three Months Ended September 30, Nine Months Ended September 30, September 30, December 31, 2022 2021 2022 2021 2022 2021 Customer A 20% 22% 22% 23% * * Customer B 15% 13% 15% 16% * * Customer C 15% 16% 14% 16% 10% * Customer D * * * * 22% 31% Customer E * * * * 10% 11% Customer F 13% 10% * * * * Customer G * * * * 10% * Customer H 12% * 10% * * * * Less than 10%

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2022
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, 2022 2021 Cash paid during the period for interest on debt, net of amounts capitalized $ 225 $ 219 Right-of-use assets obtained in exchange for new operating lease liabilities 3 — Non-cash investing activity: Transfers of property, plant and equipment in exchange for other non-current assets 17 — Contributions of assets from affiliates 7 — Non-cash financing activity: Cancellation of CCH Senior Secured Notes contributed to us from Cheniere (see Note 9 ) 30 — Contribution of CCL Stage III entity to us from Cheniere (see Note 2 ) (1,482) —

Nature of Operations and Basi_3

Nature of Operations and Basis of Presentation (Details)	9 Months Ended
	Sep. 30, 2022 milliontonnes / yr mi unit item trains
Corpus Christi Pipeline [Member]
Nature of Operations and Basis of Presentation [Line Items]
Length Of Natural Gas Pipeline | mi	21.5
Corpus Christi LNG Terminal [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains Operating | trains	3
Total Production Capability | milliontonnes / yr	15
Number of LNG Storage Tanks | unit	3
Number of Marine Berths | item	2
Corpus Christi LNG Terminal Expansion
Nature of Operations and Basis of Presentation [Line Items]
Total Production Capability | milliontonnes / yr	3
Number of Liquefaction LNG Trains | trains	2
Corpus Christi Stage 3 Project | Maximum [Member]
Nature of Operations and Basis of Presentation [Line Items]
Number of Liquefaction LNG Trains | trains	7
Corpus Christi Stage 3 Project | Minimum [Member]
Nature of Operations and Basis of Presentation [Line Items]
Total Production Capability | milliontonnes / yr	10

CCL Stage III Contribution an_3

CCL Stage III Contribution and Merger (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2022		Jun. 30, 2022	Jun. 15, 2022	Dec. 31, 2021	Sep. 30, 2021
Asset Acquisition [Line Items]
Property, plant and equipment, net of accumulated depreciation		$ 13,392				$ 12,607
Derivative assets		13				37
Other non-current assets, net		215				145
Total assets		15,240				13,764
Accounts payable		156				119
Due to affiliates		35				35
Total current liabilities		3,174				1,821
Derivative liabilities		6,973				$ 638
Cheniere Corpus Christi Liquefaction Stage III, LLC [Member]
Asset Acquisition [Line Items]
Property, plant and equipment, net of accumulated depreciation					$ 441
Derivative assets					112
Other non-current assets, net					19
Total assets					572
Accounts payable					3
Due to affiliates					1
Total current liabilities					4
Derivative liabilities					2,050
Asset Acquisition, Net Liability Acquired		(1,482)			$ (1,482)		$ 0
CCH Credit Facility [Member]
Asset Acquisition [Line Items]
Total facility size		$ 3,260	[1]	$ 4,000
CCH Credit Facility [Member] | Maximum [Member]
Asset Acquisition [Line Items]
Maturity Date		Jun. 15, 2029
CCH Working Capital Facility [Member]
Asset Acquisition [Line Items]
Total facility size		$ 1,500	[1]	$ 1,500
Maturity Date	[1]	Jun. 15, 2027
[1]In June 2022, we amended and restated the CCH Credit Facility and CCH Working Capital Facility resulting in $20 million of debt extinguishment and modification costs to, among other things, (a) provide incremental commitments of $3.7 billion and $300 million for the CCH Credit Facility and the CCH Working Capital Facility, respectively, in connection with the FID with respect to the Corpus Christi Stage 3 Project, (b) extend the maturity, (c) update the indexed interest rate to SOFR and (d) make certain other changes to the terms and conditions of each existing facility.

Restricted Cash and Cash Equi_2

Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 202	$ 44
CCL Project [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash and cash equivalents	$ 202	$ 44

Trade and Other Receivables, _3

Trade and Other Receivables, Net of Current Expected Credit Losses (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Receivables [Abstract]
Trade receivables	$ 309	$ 256
Other receivables	91	24
Total trade and other receivables, net of current expected credit losses	$ 400	$ 280

Inventory (Details)

Inventory (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Inventory [Line Items]
Inventory	$ 138	$ 156
Materials [Member]
Inventory [Line Items]
Inventory	89	88
LNG [Member]
Inventory [Line Items]
Inventory	26	45
Natural gas [Member]
Inventory [Line Items]
Inventory	23	21
Other [Member]
Inventory [Line Items]
Inventory	$ 0	$ 2

Property, Plant and Equipment_3

Property, Plant and Equipment, Net of Accumulated Depreciation - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net of accumulated depreciation	$ 13,392	$ 12,607
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(1,311)	(981)
Property, plant and equipment, net of accumulated depreciation	13,387	12,601
LNG terminal and interconnecting pipeline facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,285	13,222
LNG site and related costs [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	302	294
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,111	66
Fixed assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	24	23
Accumulated depreciation	(19)	(17)
Property, plant and equipment, net of accumulated depreciation	$ 5	$ 6

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, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Property, Plant and Equipment [Abstract]
Depreciation expense		$ 111	$ 111	$ 332	$ 309
Offsets to LNG terminal costs	[1]	$ 0	$ 0	$ 0	$ 143
[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) - CCL [Member] - tbtu	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Physical Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	25 years
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount	8,137	2,915
Financial Liquefaction Supply Derivatives | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract	3 years

Derivative Instruments - Fair V

Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ (40)
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	(40)
Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(8,838)	(1,212)
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(76)	5
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	19	4
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ (8,781)	$ (1,221)

Derivative Instruments - Fair_2

Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Physical Liquefaction Supply Derivatives [Member] - Fair Value, Inputs, Level 3 [Member]	9 Months Ended
	Sep. 30, 2022 USD ($)
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Net Fair Value Liability	$ (8,781,000,000)
Valuation, Market Approach [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread	(1.992)	[1]
Valuation, Market Approach [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread	0.355	[1]
Valuation, Market Approach [Member] | Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread	$ (0.153)	[1]
Valuation Technique, Option Pricing Model [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	89%	[1],[2]
Valuation Technique, Option Pricing Model [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	943%	[1],[2]
Valuation Technique, Option Pricing Model [Member] | Weighted Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value Inputs Basis Spread Percentage	190%	[1],[2]
[1]Unobservable inputs were weighted by the relative fair value of the instruments.[2]Spread contemplates U.S. dollar-denominated pricing.

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Level 3 Activity (Details) - Physical Liquefaction Supply Derivatives [Member] - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021		Sep. 30, 2022	Sep. 30, 2021
Fair Value, Assets (Liabilities) Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period		$ (5,006)	$ (260)	[1]	$ (1,221)	$ 12	[1]
Realized and mark-to-market losses:
Included in cost of sales		(4,123)	(766)	[1]	(2,727)	(1,032)	[1]
Purchases and settlements:
Purchases		1	(1)	[1]	(5,290)	17	[1]
Settlements		346	52	[1]	457	28	[1]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers out of Level 3	[2]	1	0		0	0
Balance, end of period		(8,781)	(975)	[1]	(8,781)	(975)	[1]
Change in unrealized losses relating to instruments still held at end of period		$ (4,123)	$ (766)	[1]	$ (2,727)	$ (1,032)	[1]
[1] Includes amounts recorded related to natural gas supply contracts that CCL had with a related party. The agreement ceased to be considered a related party agreement during 2021, as discussed in Note 11—Related Party Transactions .

Derivative Instruments - Sche_2

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) - Interest Rate Derivatives [Member] - USD ($) $ in Billions	Sep. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative, Notional Amount	$ 0	$ 4.5
Weighted Average Fixed Interest Rate Paid	2.30%

Derivative Instruments - Deriva

Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Interest Rate Derivatives [Member] | Interest rate derivative loss, net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net		$ 0	$ (2)	$ 2	$ (3)
Liquefaction Supply Derivatives [Member] | LNG Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	0	(3)	7	(3)
Liquefaction Supply Derivatives [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1]	(3,883)	(733)	(5,763)	(981)
Liquefaction Supply Derivatives [Member] | Cost of sales—related party [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative gain (loss), net	[1],[2]	$ 0	$ 6	$ 0	$ 13
[1]Does not include the realized value associated with derivative instruments that settle through physical delivery. Fair value fluctuations associated with commodity derivative activities are classified and presented consistently with the item economically hedged and the nature and intent of the derivative instrument.[2] Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement as of November 1, 2021 as discussed in Note 11—Related Party Transactions .

Derivative Instruments - Fair_3

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Current derivative assets		$ 23	$ 17
Derivative assets		13	37
Total derivative assets		36	54
Current derivative liabilities		(1,901)	(668)
Derivative liabilities		(6,973)	(638)
Total derivative liabilities		(8,874)	(1,306)
Derivative liability, net		(8,838)	(1,252)
Current derivative assets
Derivatives, Fair Value [Line Items]
Current derivative assets		23	17
Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets		13	37
Current derivative liabilities
Derivatives, Fair Value [Line Items]
Current derivative liabilities		(1,901)	(668)
Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities		(6,973)	(638)
Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		0	0
Total derivative liabilities		0	(40)
Derivative liability, net		0	(40)
Interest Rate Derivatives [Member] | Current derivative assets
Derivatives, Fair Value [Line Items]
Current derivative assets		0	0
Interest Rate Derivatives [Member] | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets		0	0
Interest Rate Derivatives [Member] | Current derivative liabilities
Derivatives, Fair Value [Line Items]
Current derivative liabilities		0	(40)
Interest Rate Derivatives [Member] | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities		0	0
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	36	54
Total derivative liabilities	[1]	(8,874)	(1,266)
Derivative liability, net	[1]	(8,838)	(1,212)
Derivative, collateral posted by us		93	13
Liquefaction Supply Derivatives [Member] | Current derivative assets
Derivatives, Fair Value [Line Items]
Current derivative assets	[1]	23	17
Liquefaction Supply Derivatives [Member] | Derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	[1]	13	37
Liquefaction Supply Derivatives [Member] | Current derivative liabilities
Derivatives, Fair Value [Line Items]
Current derivative liabilities	[1]	(1,901)	(628)
Liquefaction Supply Derivatives [Member] | Derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	$ (6,973)	$ (638)
[1]Does not include collateral posted with counterparties by us of $93 million and $13 million as of September 30, 2022 and December 31, 2021, respectively, which are included in other current assets in our Consolidated Balance Sheets.

Derivative Instruments - Deri_2

Derivative Instruments - Derivative Net Presentation on Consolidated Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Liquefaction Supply Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 41	$ 76
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(5)	(22)
Derivative Assets (Liabilities), at Fair Value, Net	36	54
Liquefaction Supply Derivative Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(9,349)	(1,295)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	475	29
Derivative Assets (Liabilities), at Fair Value, Net	$ (8,874)	$ (1,266)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Accrued Liabilities, Current [Abstract]
Natural gas purchases	$ 844	$ 531
Interest costs and related debt fees	112	7
Liquefaction Project costs	82	43
Other accrued liabilities	42	50
Total accrued liabilities	$ 1,080	$ 631

Debt - Schedule of Debt Instrum

Debt - Schedule of Debt Instruments (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended			9 Months Ended
		Oct. 31, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount			$ 8,441			$ 8,441		$ 10,449
Current portion of long-term debt			0			0		(117)
Short-term debt			0			0		(250)
Unamortized discount and debt issuance costs, net			(72)			(72)		(96)
Total long-term debt, net of discount and debt issuance costs			8,369			8,369		9,986
Non-cash contributions from affiliates for conveyance of assets						7	$ 0
Debt Instrument, Repurchased Face Amount, Contributed from Affiliate			30			30	$ 0
Contribution for net gain on extinguishment of debt			681	$ 801	$ 138
CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount			8,441			8,441		8,471
CCH Senior Notes [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt		$ 221
CCH Senior Notes [Member] | Cheniere [Member]
Debt Instrument [Line Items]
Debt Instrument, Repurchased Face Amount, Contributed from Affiliate			30			30
Contribution for net gain on extinguishment of debt						5
2024 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount			$ 1,250			$ 1,250		1,250
Debt Instrument, Interest Rate, Stated Percentage			7%			7%
2025 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[1]		$ 1,500			$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage			5.875%			5.875%
2027 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[1]		$ 1,500			$ 1,500		1,500
Debt Instrument, Interest Rate, Stated Percentage			5.125%			5.125%
2029 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[1]		$ 1,492			$ 1,492		1,500
Debt Instrument, Interest Rate, Stated Percentage			3.70%			3.70%
2039 CCH Senior Notes [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[1]		$ 2,699			$ 2,699		2,721
2039 CCH Senior Notes [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			3.72%			3.72%
CCH Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount			$ 0			$ 0		1,728
CCH Working Capital Facility [Member]
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	[2]		0			0		$ 250
Short-term debt	[3]		$ 0			$ 0
[1]Subsequent to September 30, 2022 and through October 31, 2022, Cheniere executed bond repurchases totaling $221 million, inclusive of CCH’s Senior Secured Notes due 2027, 2029 and 2039 on the open market, which were immediately contributed to us from Cheniere and cancelled by us.[2]The CCH Working Capital Facility is classified as short-term debt.[3]In June 2022, we amended and restated the CCH Credit Facility and CCH Working Capital Facility resulting in $20 million of debt extinguishment and modification costs to, among other things, (a) provide incremental commitments of $3.7 billion and $300 million for the CCH Credit Facility and the CCH Working Capital Facility, respectively, in connection with the FID with respect to the Corpus Christi Stage 3 Project, (b) extend the maturity, (c) update the indexed interest rate to SOFR and (d) make certain other changes to the terms and conditions of each existing facility.

Debt - Credit Facilities Table

Debt - Credit Facilities Table (Details) - USD ($) $ in Millions		3 Months Ended			6 Months Ended	9 Months Ended
		Sep. 30, 2022		Sep. 30, 2021	Jun. 30, 2022	Sep. 30, 2022		Sep. 30, 2021	Dec. 31, 2021
Line of Credit Facility [Line Items]
Outstanding balance - current		$ 0				$ 0			$ 250
Loss on modification or extinguishment of debt		(6)		$ (9)		(36)		$ (9)
CCH Credit Facility and CCH Working Capital Facility
Line of Credit Facility [Line Items]
Loss on modification or extinguishment of debt					$ 20
CCH Credit Facility [Member]
Line of Credit Facility [Line Items]
Total facility size		3,260	[1]		4,000	3,260	[1]
Outstanding balance	[1]	0				0
Letters of credit issued	[1]	0				0
Available commitment	[1]	3,260				$ 3,260
Debt Instrument, Description of Variable Rate Basis						SOFR or the base rate
Line of Credit Facility, Commitment Fee Percentage						0.53%
Incremental commitments					3,700
CCH Credit Facility [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Maturity Date						Jun. 15, 2029
CCH Credit Facility [Member] | Base Rate [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	[1]					0.50%
CCH Credit Facility [Member] | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Debt Instrument, Credit Spread Adjustment On Variable Rate	[1]					0.10%
Debt Instrument, Basis Spread on Variable Rate	[1]					1.50%
CCH Working Capital Facility [Member]
Line of Credit Facility [Line Items]
Total facility size		1,500	[1]		1,500	$ 1,500	[1]
Outstanding balance - current	[1]	0				0
Letters of credit issued	[1]	218				218
Available commitment	[1]	$ 1,282				$ 1,282
Debt Instrument, Description of Variable Rate Basis						SOFR or the base rate
Line of Credit Facility, Commitment Fee Percentage	[1]					0.18%
Maturity Date	[1]					Jun. 15, 2027
Incremental commitments					$ 300
CCH Working Capital Facility [Member] | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Debt Instrument, Credit Spread Adjustment On Variable Rate	[1]					0.10%
CCH Working Capital Facility [Member] | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Minimum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	[1]					1%
CCH Working Capital Facility [Member] | Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate | Maximum [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	[1]					1.50%
[1]In June 2022, we amended and restated the CCH Credit Facility and CCH Working Capital Facility resulting in $20 million of debt extinguishment and modification costs to, among other things, (a) provide incremental commitments of $3.7 billion and $300 million for the CCH Credit Facility and the CCH Working Capital Facility, respectively, in connection with the FID with respect to the Corpus Christi Stage 3 Project, (b) extend the maturity, (c) update the indexed interest rate to SOFR and (d) make certain other changes to the terms and conditions of each existing facility.

Debt - Interest Expense (Detail

Debt - Interest Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Debt Disclosure [Abstract]
Total interest cost	$ 119	$ 118	$ 356	$ 355
Capitalized interest, including amounts capitalized as an Allowance for Funds Used During Construction	(13)	(1)	(16)	(27)
Total interest expense, net of capitalized interest	$ 106	$ 117	$ 340	$ 328

Debt - Schedule of Carrying Val

Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value		$ 8,441	$ 10,449
Senior notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[1]	6,470	6,500
Senior notes [Member] | Carrying Amount [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt, Carrying Value	[2]	1,971	1,971
Senior notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	6,049	7,095
Senior notes [Member] | Estimated Fair Value [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[2]	$ 1,797	$ 2,227
[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		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 2,863	$ 1,541	$ 7,221	$ 3,581
Net derivative gain (loss)	[1]	0	(3)	7	(3)
Revenues		2,863	1,538	7,228	3,578
LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		1,737	1,032	4,661	2,473
Revenues		1,737	1,029	4,668	2,470
LNG—affiliate [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		$ 1,126	$ 509	$ 2,560	$ 1,108
[1] See Note 7—Derivative Instruments

Revenues - Contract Assets and

Revenues - Contract Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Contract assets, net of current expected credit losses	$ 132	$ 104
Change in Contract with Customer, Liability [Roll Forward]
Deferred revenue, beginning of period	35
Cash received but not yet recognized in revenue	67
Revenue recognized from prior year end deferral	(35)
Deferred revenue, end of period	$ 67

Revenues - Schedule of Transact

Revenues - Schedule of Transaction Price Allocated to Future Performance Obligations (Details) - USD ($) $ in Billions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 32.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 52.7		$ 52.7
LNG [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		73%	59%	70%	53%
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 31.7
Weighted Average Recognition Timing	[1]					9 years
LNG [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 51.4		$ 51.4
Weighted Average Recognition Timing	[1]	11 years		11 years
LNG—affiliate [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Variable Consideration Received From Customers, Percentage		89%	0%	87%	0%
LNG—affiliate [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price						$ 1.1
Weighted Average Recognition Timing	[1]					10 years
LNG—affiliate [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied Transaction Price		$ 1.3		$ 1.3
Weighted Average Recognition Timing	[1]	9 years		9 years
[1]The weighted average recognition timing represents an estimate of the number of years during which we shall have recognized half of the unsatisfied transaction price.

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Related Party Transaction [Line Items]
LNG revenues—affiliate		$ 2,863	$ 1,541	$ 7,221	$ 3,581
Cost of sales—affiliate		47	12	95	49
Cost of sales—related party		0	53	0	124
Operating and maintenance expense—affiliate		28	25	86	77
Operating and maintenance expense—related party		2	2	7	7
General and administrative expense—affiliate		11	8	27	20
LNG—affiliate [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate		1,126	509	2,560	1,108
Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate		0	0	0	31
Cheniere Marketing Agreements [Member] | LNG—affiliate [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate		1,022	500	2,394	1,079
Contracts for Sale and Purchase of Natural Gas And LNG [Member]
Related Party Transaction [Line Items]
Cost of sales—affiliate		47	12	95	18
Contracts for Sale and Purchase of Natural Gas And LNG [Member] | LNG—affiliate [Member]
Related Party Transaction [Line Items]
LNG revenues—affiliate		104	9	166	29
Natural Gas Supply Agreement [Member]
Related Party Transaction [Line Items]
Cost of sales—related party	[1]	0	53	0	124
Service Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate		28	24	86	76
General and administrative expense—affiliate		11	8	27	20
Land Agreements [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—affiliate		0	1	0	1
Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Operating and maintenance expense—related party		$ 2	$ 2	$ 7	$ 7
[1]Includes amounts recorded related to natural gas supply contracts that we had with a related party. This agreement ceased to be considered a related party agreement during 2021, as discussed below.

Related Party Transactions - LN

Related Party Transactions - LNG Sale and Purchase Agreements (Details)	9 Months Ended
	Sep. 30, 2022 USD ($) tbtu Cargo	Dec. 31, 2021 USD ($)
Related Party Transaction [Line Items]
Due to affiliates | $	$ 35,000,000	$ 35,000,000
CCL [Member] | Affiliated Entity [Member] | Facility Swap Agreement [Member]
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing Agreements [Member]
Related Party Transaction [Line Items]
Accounts receivable—affiliate | $	$ 593,000,000	$ 314,000,000
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing Base SPA [Member]
Related Party Transaction [Line Items]
SPA, Term of Agreement	20 years
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing Base SPA [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Contract Volumes	150
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing SPA [Member]
Related Party Transaction [Line Items]
Contract Volumes	15
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing EOG SPA [Member]
Related Party Transaction [Line Items]
Contract Volumes	44
CCL [Member] | Cheniere Marketing [Member] | Cheniere Marketing ARC IPM
Related Party Transaction [Line Items]
SPA, Term of Agreement	15 years
Contract Volumes	44
CCL [Member] | Cheniere Marketing [Member] | Letter Agreement
Related Party Transaction [Line Items]
LNG Volume, Purchase Price Percentage of Henry Hub	115%
LNG Volume, Purchase Price Per MMBtu | $	$ 1.97
CCL [Member] | Cheniere Marketing [Member] | Letter Agreement | Maximum [Member]
Related Party Transaction [Line Items]
Contract Cargoes | Cargo	48

Related Party Transactions - Se

Related Party Transactions - Service Agreements (Details) - CCL [Member]	Sep. 30, 2022 USD ($)
Shared Services [Member] | Gas and Power Supply Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	$ 30,000
Shared Services [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	157,000
O&M Services [Member] | Operation and Maintenance Agreement [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Committed Monthly Fee	$ 53,000

Related Party Transactions - Na

Related Party Transactions - Natural Gas Transportation Agreement (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Related Party Transaction [Line Items]
Accrued liabilities—related party	$ 1	$ 1
CCL [Member] | Natural Gas Transportation Agreement [Member]
Related Party Transaction [Line Items]
Long-term Purchase Commitment, Period	10 years
Accrued liabilities—related party	$ 1	$ 1

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details)	9 Months Ended
	Sep. 30, 2022 USD ($) yd3
CCL [Member] | Cheniere Land Holdings [Member] | Rental Agreements [Member]
Related Party Transaction [Line Items]
Annual lease payment	$ 600,000
CCL [Member] | Cheniere Land Holdings [Member] | Easement Agreements [Member]
Related Party Transaction [Line Items]
Annual lease payment	$ 100,000
CCL [Member] | Cheniere Land Holdings [Member] | Easement Agreements [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Agreement Term	3 years
CCL [Member] | Cheniere Land Holdings [Member] | Easement Agreements [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Agreement Term	5 years
CCL [Member] | Cheniere Land Holdings [Member] | Licensing Agreements [Member]
Related Party Transaction [Line Items]
Annual lease payment	$ 1,000,000
CCL [Member] | Cheniere Land Holdings [Member] | Dredge Material Disposal Agreement [Member]
Related Party Transaction [Line Items]
Dredge Material Deposits, Price Per Cubic Yard Of Deposit	$ 0.50
Dredge Material Deposits, Deposit Threshold | yd3	5,000,000
Dredge Material Deposits, Price Per Cubic Yard Of Deposit After Exceeding Threshold	$ 4.62
CCL [Member] | Cheniere [Member] | Tax Sharing Agreement [Member]
Related Party Transaction [Line Items]
Income Taxes Paid, Net	0
CCP [Member] | 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		9 Months Ended		12 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Customer A [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	20%	22%	22%	23%
Customer B [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%	13%	15%	16%
Customer C [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	15%	16%	14%	16%
Customer C [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			10%
Customer D [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			22%		31%
Customer E [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			10%		11%
Customer F [Member] | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	13%	10%
Customer G [Member] | Accounts Receivable, Net and Contract Assets, Net from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage			10%
Customer H | Total Revenues from External Customers [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12%		10%

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Supplemental Cash Flow Information [Abstract]
Cash paid during the period for interest on debt, net of amounts capitalized	$ 225	$ 219
Right-of-use assets obtained in exchange for new operating lease liabilities	3	0
Contributions of property, in exchange for other non-current assets	17	0
Non-cash contributions from affiliates for conveyance of assets	7	0
Debt Instrument, Repurchased Face Amount, Contributed from Affiliate	30	0
Balance in property, plant and equipment, net of accumulated depreciation funded with accounts payable and accrued liabilities (including affiliate)	$ 42	$ 15