UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~June 30, 2019~~March 31, 2020

☐TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 001-16383

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)



Delaware	95-4352386
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

~~700 Milam Street~~	,	~~Suite 1900~~
~~Houston~~	,	~~Texas~~	~~77002~~
~~(Address of principal executive offices)~~			~~(Zip~~

700 Milam Street, Suite 1900

Houston, Texas77002

(Address of principal executive offices) (Zip Code)

(713) 375-5000

(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $ 0.003 par value	LNG	NYSE American

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.



Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of ~~August 2, 2019,~~April 24, 2020, the issuer had ~~256,779,983~~252,107,558 shares of Common Stock outstanding.

CHENIERE ENERGY, INC.

TABLE OF CONTENTS

DEFINITIONS

As used in this quarterly report, the terms listed below have the following meanings:

Common Industry and Other Terms



Bcf		billion cubic feet
Bcf/d		billion cubic feet per day
Bcf/yr		billion cubic feet per year
Bcfe		billion cubic feet equivalent
DOE		U.S. Department of Energy
EPC		engineering, procurement and construction
FERC		Federal Energy Regulatory Commission
FTA countries		countries with which the United States has a free trade agreement providing for national treatment for trade in natural gas
GAAP		generally accepted accounting principles in the United States
Henry Hub		the final settlement price (in USD per MMBtu) for the New York Mercantile Exchange’s Henry Hub natural gas futures contract for the month in which a relevant cargo’s delivery window is scheduled to begin
LIBOR		London Interbank Offered Rate
LNG		liquefied natural gas, a product of natural gas that, through a refrigeration process, has been cooled to a liquid state, which occupies a volume that is approximately 1/600th of its gaseous state
MMBtu		million British thermal units, an energy unit
mtpa		million tonnes per annum
non-FTA countries		countries with which the United States does not have a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC		U.S. Securities and Exchange Commission
SPA		LNG sale and purchase agreement
TBtu		trillion British thermal units, an energy unit
Train		an industrial facility comprised of a series of refrigerant compressor loops used to cool natural gas into LNG
TUA		terminal use agreement

Abbreviated Legal Entity Structure

The following diagram depicts our abbreviated legal entity structure as of ~~June 30, 2019,~~March 31, 2020, including our ownership of certain subsidiaries, and the references to these entities used in this quarterly report:

Unless the context requires otherwise, references to “Cheniere,” the “Company,” “we,” “us” and “our” refer to Cheniere Energy, Inc. and its consolidated subsidiaries, including our publicly traded subsidiary, Cheniere Partners.

Unless the context requires otherwise, references to the “CCH Group” refer to CCH HoldCo II, CCH HoldCo I, CCH, CCL and CCP, collectively.


PART I.	FINANCIAL INFORMATION


ITEM 1.	CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (1)

(in millions, except share data)


	June 30,			December 31,			March 31,			December 31,
	2019			2018			2020			2019
ASSETS	(unaudited)						(unaudited)
Current assets
Cash and cash equivalents	$	2,279		$	981		$	2,399		$	2,474
Restricted cash	1,161			2,175			430			520
Accounts and other receivables	433			585			468			491
Inventory	290			316			239			312
Derivative assets	127			63			322			323
Other current assets	135			114			79			92
Total current assets	4,425			4,234			3,937			4,212

Property, plant and equipment, net	29,073			27,245			29,802			29,673
Operating lease assets, net	502			—			350			439
Debt issuance costs, net	55			72
Non-current derivative assets	103			54			705			174
Goodwill	77			77			77			77
Deferred tax assets							400			529
Other non-current assets, net	337			305			476			388
Total assets	$	34,572		$	31,987		$	35,747		$	35,492

LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	120		$	58		$	29		$	66
Accrued liabilities	1,572			1,169			922			1,281
Current debt	—			239			2,137			—
Deferred revenue	136			139			94			161
Current operating lease liabilities	292			—			178			236
Derivative liabilities	84			128			244			117
Other current liabilities	3			9			53			13
Total current liabilities	2,207			1,742			3,657			1,874

Long-term debt, net	29,944			28,179			28,940			30,774
Non-current operating lease liabilities	202			—			164			189
Non-current finance lease liabilities	58			57			58			58
Non-current derivative liabilities	94			22			186			151
Other non-current liabilities	44			58			23			11

Commitments and contingencies (see Note 16)
Commitments and contingencies (see Note 17)

Stockholders’ equity
Preferred stock, $0.0001 par value, 5.0 million shares authorized, none issued	—			—			—			—
Common stock, $0.003 par value
Authorized: 480.0 million shares at June 30, 2019 and December 31, 2018
Issued: 270.5 million shares at June 30, 2019 and 269.8 million shares at December 31, 2018
Outstanding: 257.5 million shares at June 30, 2019 and 257.0 million shares at December 31, 2018	1			1
Treasury stock: 13.0 million shares and 12.8 million shares at June 30, 2019 and December 31, 2018, respectively, at cost	(423		)	(406		)
Common stock, $0.003 par value, 480.0 million shares authorized
Issued: 272.8 million shares at March 31, 2020 and 270.7 million shares at December 31, 2019
Outstanding: 252.1 million shares at March 31, 2020 and 253.6 million shares at December 31, 2019							1			1
Treasury stock: 20.7 million shares and 17.1 million shares at March 31, 2020 and December 31, 2019, respectively, at cost							(868		)	(674		)
Additional paid-in-capital	4,097			4,035			4,196			4,167
Accumulated deficit	(4,129		)	(4,156		)	(3,133		)	(3,508		)
Total stockholders’ deficit	(454		)	(526		)
Total stockholders’ equity (deficit)							196			(14		)
Non-controlling interest	2,477			2,455			2,523			2,449
Total equity	2,023			1,929			2,719			2,435
Total liabilities and equity	$	34,572		$	31,987
Total liabilities and stockholders’ equity							$	35,747		$	35,492

(1)

Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners, as further discussed in Note 8— Non-controlling Interest and Variable Interest Entity. As of March 31, 2020, total assets and liabilities of Cheniere Partners, which are included in our Consolidated Balance Sheets, were $19.0 billion and $18.4 billion, respectively, including $1.7 billion of cash and cash equivalents and $0.1 billion of restricted cash.

The accompanying notes are an integral part of these consolidated financial statements.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except per share data)

(unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Revenues
LNG revenues	$	2,173		$	1,442		$	4,316		$	3,608		$	2,568		$	2,143
Regasification revenues	67			65			133			130			67			66
Other revenues	52			36			104			47			74			52
Total revenues	2,292			1,543			4,553			3,785			2,709			2,261

Operating costs and expenses
Cost of sales (excluding depreciation and amortization expense shown separately below)	1,277			873			2,491			2,051
Cost of sales (excluding items shown separately below)													724			1,214
Operating and maintenance expense	295			147			516			287			316			221
Development expense	3			3			4			4			4			1
Selling, general and administrative expense	77			73			150			140			81			73
Depreciation and amortization expense	204			111			348			220			233			144
Impairment expense and loss on disposal of assets	4			—			6			—			5			2
Total operating costs and expenses	1,860			1,207			3,515			2,702			1,363			1,655

Income from operations	432			336			1,038			1,083			1,346			606

Other income (expense)
Interest expense, net of capitalized interest	(372		)	(216		)	(619		)	(432		)	(412		)	(247		)
Loss on modification or extinguishment of debt	—			(15		)	—			(15		)	(1		)	—
Derivative gain (loss), net	(74		)	32			(109		)	109
Other income	16			10			32			17
Interest rate derivative loss, net													(208		)	(35		)
Other income, net													9			16
Total other expense	(430		)	(189		)	(696		)	(321		)	(612		)	(266		)

Income before income taxes and non-controlling interest	2			147			342			762			734			340
Income tax benefit (provision)	—			3			(3		)	(12		)
Income tax provision													(131		)	(3		)
Net income	2			150			339			750			603			337
Less: net income attributable to non-controlling interest	116			168			312			411			228			196
Net income (loss) attributable to common stockholders	$	(114	)	$	(18	)	$	27		$	339
Net income attributable to common stockholders													$	375		$	141

Net income (loss) per share attributable to common stockholders—basic (1)	$	(0.44	)	$	(0.07	)	$	0.11		$	1.42
Net income (loss) per share attributable to common stockholders—diluted (1)	$	(0.44	)	$	(0.07	)	$	0.11		$	1.40
Net income per share attributable to common stockholders—basic (1)													$	1.48		$	0.55
Net income per share attributable to common stockholders—diluted (1)													$	1.43		$	0.54

Weighted average number of common shares outstanding—basic	257.4			242.8			257.3			239.2			253.0			257.1
Weighted average number of common shares outstanding—diluted	257.4			242.8			258.6			241.7			299.6			258.5

~~(1)~~


(1)	Earnings per share in the table may not recalculate exactly due to rounding because it is calculated based on whole numbers, not the rounded numbers presented.

The accompanying notes are an integral part of these consolidated financial statements.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(in millions)

(unaudited)

Three and Six Months Ended June 30, 2019
Total Stockholders’ Equity
Common Stock Treasury Stock Additional Paid-in Capital Accumulated Deficit Non-controlling Interest
Total
Equity
Shares Par Value Amount Shares Amount
Balance at December 31, 2018 257.0

$ 1

12.8

$ (406 )
$ 4,035

$ (4,156 )
$ 2,455

$ 1,929
Vesting of restricted stock units 0.6
—
—
—
—
—
—
—
Share-based compensation —
—
—
—
28
—
—
28
Shares withheld from employees related to share-based compensation, at cost (0.2 ) —
0.2
(12 ) —
—
—
(12 )
Net income attributable to non-controlling interest —
—
—
—
—
—
196
196
Distributions and dividends to non-controlling interest —
—
—
—
—
—
(144 ) (144 )
Net income —
—
—
—
—
141
—
141
Balance at March 31, 2019 257.4
1
13.0
(418 ) 4,063
(4,015 ) 2,507
2,138
Vesting of restricted stock units 0.1
—
—
—
—
—
—
—
Share-based compensation —
—
—
—
33
—
—
33
Shares withheld from employees related to share-based compensation, at cost —
—
—
(2 ) —
—
—
(2 )
Shares repurchased, at cost —
—
—
(3 ) —
—
—
(3 )
Net income attributable to non-controlling interest —
—
—
—
—
—
116
116
Equity portion of convertible notes, net —
—
—
—
1
—
—
1
Distributions and dividends to non-controlling interest —
—
—
—
—
—
(146 ) (146 )
Net loss —
—
—
—
—
(114 ) —
(114 )
Balance at June 30, 2019 257.5
$ 1
13.0
$ (423 ) $ 4,097
$ (4,129 ) $ 2,477
$ 2,023



Three Months Ended March 31, 2020
	Total Stockholders’ Equity
	Common Stock				Treasury Stock				Additional Paid-in Capital		Accumulated Deficit			Non-controlling Interest			Total Equity
	Shares		Par Value Amount		Shares	Amount			Additional Paid-in Capital		Accumulated Deficit			Non-controlling Interest			Total Equity
Balance at December 31, 2019	253.6		$	1	17.1	$	(674	)	$	4,167	$	(3,508	)	$	2,449		$	2,435
Vesting of restricted stock units and performance stock units	2.1		—		—	—			—		—			—			—
Share-based compensation	—		—		—	—			29		—			—			29
Issued shares withheld from employees related to share-based compensation, at cost	(0.7	)	—		0.7	(39		)	—		—			—			(39		)
Shares repurchased, at cost	(2.9	)	—		2.9	(155		)	—		—			—			(155		)
Net income attributable to non-controlling interest	—		—		—	—			—		—			228			228
Distributions and dividends to non-controlling interest	—		—		—	—			—		—			(154		)	(154		)
Net income	—		—		—	—			—		375			—			375
Balance at March 31, 2020	252.1		$	1	20.7	$	(868	)	$	4,196	$	(3,133	)	$	2,523		$	2,719



Three Months Ended March 31, 2019
	Total Stockholders’ Equity
	Common Stock				Treasury Stock				Additional Paid-in Capital		Accumulated Deficit			Non-controlling Interest			Total Equity
	Shares		Par Value Amount		Shares	Amount			Additional Paid-in Capital		Accumulated Deficit			Non-controlling Interest			Total Equity
Balance at December 31, 2018	257.0		$	1	12.8	$	(406	)	$	4,035	$	(4,156	)	$	2,455		$	1,929
Vesting of restricted stock units	0.6		—		—	—			—		—			—			—
Share-based compensation	—		—		—	—			28		—			—			28
Issued shares withheld from employees related to share-based compensation, at cost	(0.2	)	—		0.2	(12		)	—		—			—			(12		)
Net income attributable to non-controlling interest	—		—		—	—			—		—			196			196
Distributions and dividends to non-controlling interest	—		—		—	—			—		—			(144		)	(144		)
Net income	—		—		—	—			—		141			—			141
Balance at March 31, 2019	257.4		$	1	13.0	$	(418	)	$	4,063	$	(4,015	)	$	2,507		$	2,138

The accompanying notes are an integral part of these consolidated financial statements.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY—CONTINUED~~

~~(in millions)~~

~~(unaudited)~~

Three and Six Months Ended June 30, 2018
Total Stockholders’ Equity
Common Stock Treasury Stock Additional Paid-in Capital Accumulated Deficit Non-controlling Interest Total
Equity
Shares Par Value Amount Shares Amount
Balance at December 31, 2017 237.6
$ 1
12.5
$ (386 ) $ 3,248
$ (4,627 ) $ 3,004
$ 1,240
Vesting of restricted stock units 0.3
—
—
—
—
—
—
—
Share-based compensation —
—
—
—
16
—
—
16
Shares withheld from employees related to share-based compensation, at cost —
—
0.1
(6 ) —
—
—
(6 )
Net income attributable to non-controlling interest —
—
—
—
—
—
243
243
Distributions and dividends to non-controlling interest —
—
—
—
—
—
(143 ) (143 )
Net income —
—
—
—
—
357
—
357
Balance at March 31, 2018 237.9
1
12.6
(392 ) 3,264
(4,270 ) 3,104
1,707
Issuance of stock to acquire additional interest in Cheniere Holdings 10.3
—
—
—
376
—
(376 ) —
Share-based compensation —
—
—
—
23
—
—
23
Shares withheld from employees related to share-based compensation, at cost (0.1 ) —
—
(2 ) —
—
—
(2 )
Net income attributable to non-controlling interest —
—
—
—
—
—
168
168
Equity portion of convertible notes, net —
—
—
—
1
—
—
1
Distributions and dividends to non-controlling interest —
—
—
—
—
—
(145 ) (145 )
Net loss —
—
—
—
—
(18 ) —
(18 )
Balance at June 30, 2018 248.1
$ 1
12.6
$ (394 ) $ 3,664
$ (4,288 ) $ 2,751
$ 1,734

~~The accompanying notes are an integral part of these consolidated financial statements.~~

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)


	Six Months Ended June 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash flows from operating activities
Net income	$	339		$	750		$	603		$	337
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	348			220			233			144
Share-based compensation expense	61			58			29			28
Non-cash interest expense	93			30			17			33
Amortization of debt issuance costs, deferred commitment fees, premium and discount	44			35
Amortization of operating lease assets	158			—
Amortization of debt issuance costs, premium and discount							32			18
Non-cash operating lease costs							96			79
Loss on modification or extinguishment of debt	—			15			1			—
Total losses (gains) on derivatives, net	(147		)	4
Net cash provided by (used for) settlement of derivative instruments	62			(8		)
Total gains on derivatives, net							(459		)	(122		)
Net cash provided by settlement of derivative instruments							91			16
Impairment expense and loss on disposal of assets	6			—			5			2
Other	2			(5		)
Impairment or loss on equity method investments							1			—
Deferred taxes							129			—
Changes in operating assets and liabilities:
Accounts and other receivables	59			80			23			99
Inventory	33			10			74			44
Other current assets	(46		)	(61		)	13			(15		)
Accounts payable and accrued liabilities	(80		)	(132		)	(176		)	(146		)
Deferred revenue	(2		)	(13		)	(67		)	(31		)
Operating lease liabilities	(163		)	—			(90		)	(85		)
Finance lease liabilities							—			1
Other, net	(7		)	(1		)	19			10
Net cash provided by operating activities	760			982			574			412

Cash flows from investing activities
Property, plant and equipment, net	(1,508		)	(1,508		)	(556		)	(625		)
Investment in equity method investment	(34		)	—			(90		)	(24		)
Other	—			16			(8		)	(2		)
Net cash used in investing activities	(1,542		)	(1,492		)	(654		)	(651		)

Cash flows from financing activities
Proceeds from issuances of debt	2,021			1,799			596			692
Repayments of debt	(630		)	(281		)	(300		)	(441		)
Debt issuance and deferred financing costs	(20		)	(46		)
Debt extinguishment costs	—			(8		)
Debt issuance and other financing costs							(33		)	—
Distributions and dividends to non-controlling interest	(290		)	(288		)	(154		)	(144		)
Payments related to tax withholdings for share-based compensation	(14		)	(8		)	(39		)	(12		)
Repurchase of common stock	(3		)	—			(155		)	—
Other	2			—			—			(1		)
Net cash provided by financing activities	1,066			1,168
Net cash provided by (used in) financing activities							(85		)	94

Net increase in cash, cash equivalents and restricted cash	284			658
Net decrease in cash, cash equivalents and restricted cash							(165		)	(145		)
Cash, cash equivalents and restricted cash—beginning of period	3,156			2,613			2,994			3,156
Cash, cash equivalents and restricted cash—end of period	$	3,440		$	3,271		$	2,829		$	3,011

Balances per Consolidated Balance Sheet:


			March 31,
	June 30, 2019		2020
Cash and cash equivalents	$	2,279	$	2,399
Restricted cash	1,161		430
Total cash, cash equivalents and restricted cash	$	3,440	$	2,829

The accompanying notes are an integral part of these consolidated financial statements.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—NATURE OF OPERATIONS AND BASIS OF PRESENTATION

We ~~own~~are operating and ~~operate two~~constructing 2 natural gas liquefaction and export facilities at Sabine Pass and Corpus Christi. The Sabine Pass LNG terminal is located in Cameron Parish, Louisiana, on the Sabine-Neches Waterway less than four miles from the Gulf Coast. Cheniere Partners, through its subsidiary SPL, is ~~in various stages of constructing and~~currently operating ~~six~~5 natural gas liquefaction ~~facilities~~Trains and is constructing 1 additional Train for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”) at the Sabine Pass LNG ~~terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, SPL. Trains 1 through 5 are operational and Train 6 is under construction.~~terminal. The Sabine Pass LNG terminal has operational regasification facilities owned by Cheniere Partners’ ~~wholly owned~~ subsidiary, SPLNG, that include pre-existing infrastructure of 5 LNG storage tanks, 2 marine berths and vaporizers. Cheniere Partners also owns a 94-mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines ~~owned by Cheniere Partners’ wholly owned~~(the “Creole Trail Pipeline”) through its subsidiary, CTPL. As of March 31, 2020, we owned 100% of the general partner interest and 48.6% of the limited partner interest in Cheniere Partners.

The Corpus Christi LNG terminal is located near Corpus Christi, Texas and is operated and constructed by our ~~wholly owned~~ subsidiary, CCL. We are currently operating 2 Trains and are constructing 1 additional Train for a total production capacity of approximately 15 mtpa of LNG. We also operate a 23-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 ~~liquefaction facilities,~~Trains, the “CCL Project”) through our ~~wholly owned~~ subsidiary, CCP. The CCL Project, ~~is being developed in stages with the first phase being three Trains (“Phase 1”). The first stage includes Trains 1 and 2, two~~once fully constructed, will contain 3 LNG storage tanks ~~one complete~~and 2 marine berth and a second partial berth and all of the CCL Project’s necessary infrastructure facilities (“Stage 1”). The second stage includes Train 3, one LNG storage tank and the completion of the second partial berth (“Stage 2”). Train 1 is operational, Train 2 is undergoing commissioning and Train 3 is under construction.berths.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) ~~and filed an application with FERC in June 2018~~through our subsidiary CCL Stage III, for ~~seven~~up to 7 midscale Trains with an expected ~~aggregate nominal~~total production capacity of approximately ~~9.5~~10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and ~~one LNG storage tank.~~operate the expansion project.

We remain focused on ~~expansion~~operational excellence and customer satisfaction. Increasing demand of LNG has allowed us to expand our ~~existing sites by leveraging existing infrastructure.~~liquefaction infrastructure in a financially disciplined manner. We ~~continue to consider~~hold significant land positions at both the Sabine Pass LNG terminal and the Corpus Christi LNG terminal which provide opportunity for further liquefaction capacity expansion. The development of these sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, ~~which,~~will require, among other things, ~~will require~~ acceptable commercial and financing arrangements before we make a final investment decision (“FID”).

Basis of Presentation

The accompanying unaudited Consolidated Financial Statements of Cheniere have been prepared in accordance with GAAP for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements and should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019.. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included.

Results of operations for the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, ~~2019.~~2020.

Recent Accounting Standards

~~We adopted ASU 2016-02,~~In March 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-04, ~~Leases~~Reference Rate Reform (Topic ~~842)~~848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting,. This guidance primarily provides temporary optional expedients which simplify the accounting for contract modifications to existing debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The optional expedients were available to be used upon issuance of this guidance but we have not yet applied the guidance because we have not yet modified any of our existing contracts for reference rate reform. Once we apply an optional expedient to a modified contract and adopt this standard, the guidance will be applied to all subsequent ~~amendments thereto (“ASC 842”) on January 1, 2019 using~~applicable contract modifications until December 31, 2022, at which time the optional ~~transition approach to apply the standard at the beginning of the first quarter of 2019 with~~expedients are no retrospective adjustments to prior periods. The adoption of the standard resulted in the recognition of right-of-use assets and lease liabilities for operating leases of approximately $550 million on our Consolidated Balance Sheets, with no material impact on our Consolidated Statements of Operations or Consolidated Statements of Cash Flows. We have elected the practical expedients to (1) carryforward prior conclusions related to lease identification and classification for existing leases, (2) combine lease and non-lease components of an arrangement for all classes of leased assets, (3) omit short-term leases with a term of 12 months or less from recognition on the balance sheet and (4) carryforward our existing accounting for land easements not previously accounted for as leases. See ~~Note 11—Leases~~ ~~for additional information on our leases following the adoption of this standard.~~longer available.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 2—RESTRICTED CASH

Restricted cash consists of funds that are contractually ~~and~~or legally restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, restricted cash consisted of the following (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Current restricted cash
SPL Project	$	596	$	756	$	109	$	181
Cheniere Partners and cash held by guarantor subsidiaries	—		785
CCL Project	279		289		94		80
Cash held by our subsidiaries restricted to Cheniere	286		345		227		259
Total current restricted cash	$	1,161	$	2,175	$	430	$	520

Pursuant to the accounts agreements entered into with the collateral trustees for the benefit of SPL’s debt holders and CCH’s debt holders, SPL and CCH are required to deposit all cash received into reserve accounts controlled by the collateral trustees. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) and other restricted payments.

In May 2019, Cheniere Partners entered into the $1.5 billion credit facilities (the “2019 CQP Credit Facilities”), which replaced the previous $2.8 billion credit facilities (the “2016 CQP Credit Facilities”). The cash held by Cheniere Partners and its guarantor subsidiaries was restricted in use under the terms of the 2016 CQP Credit Facilities and the related depositary agreement governing the extension of credit to Cheniere Partners, but is no longer restricted under the 2019 CQP Credit Facilities.

NOTE 3—ACCOUNTS AND OTHER RECEIVABLES

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, accounts and other receivables consisted of the following (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Trade receivables
SPL and CCL	$	257	$	330	$	304	$	328
Cheniere Marketing	145		205		88		113
Other accounts receivable	31		50		76		50
Total accounts and other receivables	$	433	$	585	$	468	$	491

NOTE 4—INVENTORY

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, inventory consisted of the following (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Natural gas	$	19	$	30	$	13	$	16
LNG	38		24		35		67
LNG in-transit	104		173		48		93
Materials and other	129		89		143		136
Total inventory	$	290	$	316	$	239	$	312

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 5—PROPERTY, PLANT AND EQUIPMENT

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, property, plant and equipment, net consisted of the following (in millions):


	June 30,			December 31,			March 31,			December 31,
	2019			2018			2020			2019
LNG terminal costs
LNG terminal and interconnecting pipeline facilities	$	23,650		$	13,386		$	27,330		$	27,305
LNG site and related costs	319			86			322			322
LNG terminal construction-in-process	6,529			14,864			4,233			3,903
Accumulated depreciation	(1,625		)	(1,299		)	(2,272		)	(2,049		)
Total LNG terminal costs, net	28,873			27,037			29,613			29,481
Fixed assets and other
Computer and office equipment	22			17			23			23
Furniture and fixtures	22			22			22			22
Computer software	104			100			112			110
Leasehold improvements	42			41			43			42
Land	59			59			59			59
Other	20			21			24			21
Accumulated depreciation	(127		)	(111		)	(149		)	(141		)
Total fixed assets and other, net	142			149			134			136
Assets under finance lease
Tug vessels	60			60			60			60
Accumulated depreciation	(2		)	(1		)	(5		)	(4		)
Total assets under finance lease, net	58			59			55			56
Property, plant and equipment, net	$	29,073		$	27,245		$	29,802		$	29,673

Depreciation expense was ~~$203~~$232 million and ~~$111~~$143 million during the three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $346 million and $219 million during the six months ended June 30, 2019 and 2018,~~ respectively.

We ~~realize~~realized offsets to LNG terminal costs ~~for sales~~of $202 million during the three months ended March 31, 2019 that were related to the sale of commissioning cargoes ~~that~~because these amounts were earned or loaded prior to the start of commercial operations of the respective ~~Train~~Trains of the Liquefaction Projects, during the testing phase for its construction. We ~~realized offsets to LNG terminal costs of $202 million during the six months ended June 30, 2019 for sales of commissioning cargoes from the Liquefaction Projects. We~~ did ~~not~~0t realize any offsets to LNG terminal costs during the three months ended ~~June 30, 2019 and the three and six months ended June 30, 2018.~~March 31, 2020.

NOTE 6—DERIVATIVE INSTRUMENTS

We have entered into the following derivative instruments that are reported at fair value:

interest rate swaps (“CCH Interest Rate Derivatives”) to hedge the exposure to volatility in a portion of the floating-rate interest payments ~~under~~on CCH’s amended and restated credit ~~facilities (“CCH Interest Rate Derivatives”~~facility (the “CCH Credit Facility”) and to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH, which is anticipated by the end of 2020 (“CCH Interest Rate Forward Start Derivatives” and, collectively with the CCH Interest Rate Derivatives, the “Interest Rate Derivatives”);

commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the ~~SPL Project, CCL Project~~Liquefaction Projects and potential future development of Corpus Christi Stage 3 (“Physical Liquefaction Supply Derivatives”) and associated economic hedges (collectively, the “Liquefaction Supply Derivatives”);

financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (“LNG Trading Derivatives”); and

foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with both LNG Trading Derivatives and operations in countries outside of the United States (“FX 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.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, which are classified as derivative assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets (in millions):


	Fair Value Measurements as of																						Fair Value Measurements as of
	June 30, 2019											December 31, 2018											March 31, 2020											December 31, 2019
	Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total			Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total			Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total			Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
CCH Interest Rate Derivatives asset (liability)	$	—		$	(88	)	$	—	$	(88	)	$	—	$	18		$	—		$	18
CCH Interest Rate Derivatives liability																							$	—		$	(197	)	$	—	$	(197	)	$	—	$	(81	)	$	—	$	(81	)
CCH Interest Rate Forward Start Derivatives liability	—			(7		)	—		(7		)	—		—			—			—			—			(92		)	—		(92		)	—		(8		)	—		(8		)
Liquefaction Supply Derivatives asset (liability)	—			1			89		90			6		(19		)	(29		)	(42		)
Liquefaction Supply Derivatives asset																							1			3			674		678			5		6			138		149
LNG Trading Derivatives asset (liability)	(4		)	51			—		47			1		(25		)	—			(24		)	(3		)	188			—		185			—		165			—		165
FX Derivatives asset	—			10			—		10			—		15			—			15			—			23			—		23			—		4			—		4

We value our ~~CCH~~ Interest Rate ~~Derivatives and CCH Interest Rate Forward Start~~ 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 LNG Trading Derivatives and 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. We value our FX Derivatives with a market approach using observable FX rates 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 ~~conditions precedent,~~events deriving fair value, including evaluating whether the respective market is available as pipeline infrastructure is developed. The fair value of our Physical Liquefaction Supply Derivatives incorporates risk premiums related to the satisfaction of conditions precedent, such as completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow. As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, some of our Physical Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure was under development to accommodate marketable physical gas flow.

We include a portion of our Physical Liquefaction Supply Derivatives as Level 3 within the valuation hierarchy as the fair value is developed through the use of internal models which incorporate significant unobservable inputs. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks, such as future prices of energy units for unobservable periods, liquidity, volatility and contract duration. ~~In determining and recording fair value, we do not use third party sources that derive price based on proprietary models or market surveys.~~

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 ~~June 30, 2019:~~March 31, 2020:



	Net Fair Value Asset ~~(Liability)~~ (in millions)	Valuation Approach	Significant Unobservable Input	Range of Significant Unobservable Inputs ~~Range~~/ Weighted Average (1)
Physical Liquefaction Supply Derivatives	$89674	Market approach incorporating present value techniques	Henry Hub ~~Basis Spread~~basis spread	$~~(0.700)~~(0.619) - ~~$0.056~~$0.054 / (0.027)
		Option pricing model	International LNG pricing spread, relative to Henry Hub ~~(1)~~(2)	~~128%~~48% - ~~176%~~154% / 117%

(1) Unobservable inputs were weighted by the relative fair value of the instruments.

(2) Spread contemplates U.S. dollar-denominated pricing.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

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 during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):


	Three Months Ended June 30,					Six Months Ended June 30,						Three Months Ended March 31,
	2019		2018			2019			2018			2020		2019
Balance, beginning of period	$	31	$	10		$	(29	)	$	43		$	138	$	(29	)
Realized and mark-to-market gains (losses):
Realized and mark-to-market gains:
Included in cost of sales	7		(1		)	23			(12		)	534		12
Purchases and settlements:
Purchases	50		6			50			6			1		1
Settlements	1		(4		)	45			(25		)	—		47
Transfers out of Level 3 (1)	—		1			—			—			1		—
Balance, end of period	$	89	$	12		$	89		$	12		$	674	$	31
Change in unrealized gains (losses) relating to instruments still held at end of period	$	7	$	(1	)	$	23		$	(12	)
Change in unrealized gains relating to instruments still held at end of period												$	534	$	12

(1) Transferred to Level 2 as a result of observable market for the underlying natural gas purchase agreements.

Derivative assets and liabilities arising from our derivative contracts with the same counterparty are reported on a net basis, as all counterparty derivative contracts provide for the unconditional right of set-off in the event of default. The use of derivative instruments exposes us to counterparty credit risk, or the risk that a counterparty will be unable to meet its commitments in instances when our derivative instruments are in an asset position. Additionally, counterparties are at risk that we will be unable to meet our commitments in instances where our derivative instruments are in a liability position. We incorporate both our own nonperformance risk and the respective counterparty’s nonperformance risk in fair value measurements. In adjusting the fair value of our derivative contracts for the effect of nonperformance risk, we have considered the impact of ~~netting and~~ any applicable credit enhancements, such as collateral postings, set-off rights and guarantees.

Interest Rate Derivatives

During the six months ended June 30, 2019, there were no changes to the terms of the CCH Interest Rate Derivatives entered into by CCH to protect against volatility of future cash flows and hedge a portion of the variable interest payments on its credit facility (the “CCH Credit Facility”).

In June 2019, we entered into the CCH Interest Rate Forward Start Derivatives to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH, which is anticipated by the end of 2020.

Cheniere Partners previously had interest rate swaps (“CQP Interest Rate Derivatives” and, collectively with the CCH Interest Rate Derivatives and the CCH Interest Rate Forward Start Derivatives, the “Interest Rate Derivatives”) to hedge a portion of the variable interest payments on its credit facilities, which were terminated in October 2018.

As of ~~June 30, 2019,~~March 31, 2020, we had the following Interest Rate Derivatives outstanding:

~~Initial~~ Notional ~~Amount~~Amounts

~~Maximum Notional Amount~~

March 31, 2020

December 31, 2019

Effective Date

Maturity Date

Weighted Average Fixed Interest Rate Paid

Variable Interest Rate Received

CCH Interest Rate Derivatives

$~~29 million~~4.7 billion

$~~4.7~~4.5 billion

May 20, 2015

May 31, 2022

2.30%

One-month LIBOR

CCH Interest Rate Forward Start Derivatives

$~~1.0 billion~~750 million

~~June~~September 30, 2020

~~September 30,~~December 31, 2030

~~2.11%~~2.06%

Three-month LIBOR

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

The following table shows the fair value and location of the Interest Rate Derivatives on our Consolidated Balance Sheets (in millions):


	June 30, 2019									December 31, 2018						March 31, 2020									December 31, 2019
	CCH Interest Rate Derivatives			CCH Interest Rate Forward Start Derivatives			Total			CCH Interest Rate Derivatives		CCH Interest Rate Forward Start Derivatives		Total		CCH Interest Rate Derivatives			CCH Interest Rate Forward Start Derivatives			Total			CCH Interest Rate Derivatives			CCH Interest Rate Forward Start Derivatives			Total
Consolidated Balance Sheet Location
Derivative assets	$	—		$	—		$	—		$	10	$	—	$	10
Non-current derivative assets	—			—			—			8		—		8
Total derivative assets	—			—			—			18		—		18

Derivative liabilities	(21		)	—			(21		)	—		—		—		$	(92	)	$	(92	)	$	(184	)	$	(32	)	$	(8	)	$	(40	)
Non-current derivative liabilities	(67		)	(7		)	(74		)	—		—		—		(105		)	—			(105		)	(49		)	—			(49		)
Total derivative liabilities	(88		)	(7		)	(95		)	—		—		—		$	(197	)	$	(92	)	$	(289	)	$	(81	)	$	(8	)	$	(89	)

Derivative asset (liability), net	$	(88	)	$	(7	)	$	(95	)	$	18	$	—	$	18

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the changes in the fair value and settlements of our Interest Rate Derivatives recorded in interest rate derivative ~~gain (loss),~~loss, net on our Consolidated Statements of Operations during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
CCH Interest Rate Derivatives gain (loss) $ (67 ) $ 29
$ (102 ) $ 98
CCH Interest Rate Forward Start Derivatives loss (7 ) —
(7 ) —
CQP Interest Rate Derivatives gain —
3
—
11



	Three Months Ended March 31,
	2020			2019
CCH Interest Rate Derivatives loss	$	(123	)	$	(35	)
CCH Interest Rate Forward Start Derivatives loss	(85		)	—

Commodity Derivatives

SPL, CCL and CCL Stage III have entered into physical natural gas supply contracts and associated economic hedges to purchase natural gas for the commissioning and operation of the ~~SPL Project, the CCL Project~~Liquefaction Projects and potential future development of Corpus Christi Stage 3, respectively, which are primarily indexed to the natural gas market and international LNG indices. The remaining terms of the index-based physical natural gas supply contracts range up to approximately 15 years, some of which commence upon the satisfaction of certain ~~conditions precedent.~~events or states of affairs.

We have entered into, and may from time to time enter into, financial LNG Trading Derivatives in the form of swaps, forwards, options or futures to economically hedge exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG. We have entered into LNG Trading Derivatives to secure a fixed price position to minimize future cash flow variability associated with LNG purchase and sale transactions.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

The following table shows the fair value and location of our Liquefaction Supply Derivatives and LNG Trading Derivatives (collectively, “Commodity Derivatives”) on our Consolidated Balance Sheets (in millions, except notional amount):


	June 30, 2019									December 31, 2018									March 31, 2020									December 31, 2019
	Liquefaction Supply Derivatives (1)			LNG Trading Derivatives (2)			Total			Liquefaction Supply Derivatives (1)			LNG Trading Derivatives (2)			Total			Liquefaction Supply Derivatives (1)			LNG Trading Derivatives (2)			Total			Liquefaction Supply Derivatives (1)			LNG Trading Derivatives (2)			Total
Consolidated Balance Sheet Location
Derivative assets	$	24		$	92		$	116		$	13		$	24		$	37		$	113		$	190		$	303		$	93		$	225		$	318
Non-current derivative assets	94			9			103			46			—			46			665			35			700			174			—			174
Total derivative assets	118			101			219			59			24			83			778			225			1,003			267			225			492

Derivative liabilities	(13		)	(50		)	(63		)	(79		)	(48		)	(127		)	(19		)	(40		)	(59		)	(16		)	(60		)	(76		)
Non-current derivative liabilities	(15		)	(4		)	(19		)	(22		)	—			(22		)	(81		)	—			(81		)	(102		)	—			(102		)
Total derivative liabilities	(28		)	(54		)	(82		)	(101		)	(48		)	(149		)	(100		)	(40		)	(140		)	(118		)	(60		)	(178		)

Derivative asset (liability), net	$	90		$	47		$	137		$	(42	)	$	(24	)	$	(66	)
Derivative asset, net																			$	678		$	185		$	863		$	149		$	165		$	314

Notional amount, net (in TBtu) (3)	6,781			50						5,832			12						10,988			22						9,177			4

(1)

Does not include collateral ~~calls~~posted with counterparties by us of $6$11 million and $5$7 million for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively. Includes derivative assets of ~~$2 million and $2 million and non-current assets of $1~~$4 million and $3 million as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively, and non-current assets of $2 million as of both March 31, 2020 and December 31, 2019 for a natural gas supply ~~contract~~contracts that SPL and CCL ~~has~~have with a related ~~party.~~parties.


(2)	Does not include collateral posted with counterparties by us of ~~$15~~$11 million and $9$5 million deposited for such contracts, which are included in other current assets in our Consolidated Balance Sheets as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively.

(3)

~~SPL had secured up to approximately 3,437~~Includes 198 TBtu and ~~3,464~~120 TBtu as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018, respectively. CCL had secured up to approximately 2,787 TBtu and 2,801 TBtu of natural gas feedstock through~~2019, respectively, for natural gas supply contracts ~~as of June 30, 2019~~that SPL and ~~December 31, 2018, respectively, of which 57 TBtu and 55 TBtu, respectively, were for a natural gas supply contract~~ CCL ~~has~~have with a related ~~party. Corpus Christi Stage 3 had secured up to approximately 754 TBtu of natural gas feedstock through natural gas supply contracts as of June 30, 2019.~~parties.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the changes in the fair value, settlements and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):


	Consolidated Statements of Operations Location (1)	Three Months Ended June 30,						Six Months Ended June 30,						Consolidated Statements of Operations Location (1)	Three Months Ended March 31,
	Consolidated Statements of Operations Location (1)	2019			2018			2019			2018			Consolidated Statements of Operations Location (1)	2020			2019
LNG Trading Derivatives gain (loss)	LNG revenues	$	94		$	(76	)	$	158		$	(70	)
LNG Trading Derivatives gain														LNG revenues	$	140		$	64
LNG Trading Derivatives loss	Cost of sales	(51		)	—			(51		)	—			Cost of sales	(34		)	—
Liquefaction Supply Derivatives gain (loss) (2)	LNG revenues	(1		)	—			1			—			LNG revenues	(1		)	2
Liquefaction Supply Derivatives gain (loss) (2)(3)	Cost of sales	57			(3		)	139			(53		)
Liquefaction Supply Derivatives gain (2)(3)														Cost of sales	537			82


(1)	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)	Does not include the realized value associated with derivative instruments that settle through physical delivery.

(3)

~~Includes $24~~CCL recorded $23 million and ~~$36~~$10 million ~~that CCL recorded~~ in cost of sales under a natural gas supply contract with a related party during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019, respectively, including $1 million of Liquefaction Supply Derivatives gain and $2 million of Liquefaction Supply Derivatives loss, respectively. ~~Of this amount, $4~~As of March 31, 2020 and December 31, 2019, $7 million ~~was~~and $3 million, respectively, were included in accrued liabilities ~~as of June 30, 2019. CCL did not have any transactions during the three and six months ended June 30, 2018 under~~related to this contract.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

FX Derivatives

Cheniere Marketing has entered into FX Derivatives to protect against the volatility in future cash flows attributable to changes in international currency exchange rates. The FX Derivatives economically hedge the foreign currency exposure arising from cash flows expended for both physical and financial LNG transactions.

The following table shows the fair value and location of our FX Derivatives on our Consolidated Balance Sheets (in millions):


		Fair Value Measurements as of							Fair Value Measurements as of
	Consolidated Balance Sheet Location	June 30, 2019			December 31, 2018			Consolidated Balance Sheet Location	March 31, 2020			December 31, 2019
FX Derivatives	Derivative assets	$	11		$	16		Derivative assets	$	19		$	5
FX Derivatives	Derivative liabilities	—			(1		)	Non-current derivative assets	5			—
FX Derivatives	Non-current derivative liabilities	(1		)	—			Derivative liabilities	(1		)	(1		)

The total notional amount of our FX Derivatives was ~~$942~~$496 million and ~~$379~~$827 million as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively.

The following table shows the changes in the fair value, settlements and location of our FX Derivatives recorded on our Consolidated Statements of Operations during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):

Three Months Ended June 30, Six Months Ended June 30,
Consolidated Statements of Operations Location 2019 2018 2019 2018
FX Derivatives gain LNG revenues $ —
$ 12
$ 9
$ 10



		Three Months Ended March 31,
	Consolidated Statements of Operations Location	2020		2019
FX Derivatives gain	LNG revenues	$	25	$	9

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Consolidated Balance Sheet Presentation

Our derivative instruments are presented on a net basis on our Consolidated Balance Sheets as described above. The following table shows the fair value of our derivatives outstanding on a gross and net basis (in millions):


	Gross Amounts Recognized			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amounts Presented in the Consolidated Balance Sheets				Gross Amounts Recognized				Gross Amounts Offset in the Consolidated Balance Sheets			Net Amounts Presented in the Consolidated Balance Sheets
Offsetting Derivative Assets (Liabilities)
As of June 30, 2019
As of March 31, 2020
CCH Interest Rate Derivatives	$	(88	)		$	—		$	(88	)		$	(197	)		$	—		$	(197	)
CCH Interest Rate Forward Start Derivatives	(7		)	—			(7		)		(92		)		—			(92		)
Liquefaction Supply Derivatives	121			(3		)	118				796				(18		)	778
Liquefaction Supply Derivatives	(35		)	7			(28		)		(104		)		4			(100		)
LNG Trading Derivatives	109			(8		)	101				225				—			225
LNG Trading Derivatives	(62		)	8			(54		)		(47		)		7			(40		)
FX Derivatives	21			(10		)	11				27				(3		)	24
FX Derivatives	(11		)	10			(1		)		(1		)		—			(1		)
As of December 31, 2018
As of December 31, 2019
CCH Interest Rate Derivatives	$	19		$	(1	)	$	18			$	(81	)		$	—		$	(81	)
CCH Interest Rate Forward Start Derivatives											(8		)		—			(8		)
Liquefaction Supply Derivatives	95			(36		)	59				281				(14		)	267
Liquefaction Supply Derivatives	(121		)	20			(101		)		(126		)		8			(118		)
LNG Trading Derivatives	112			(88		)	24				229				(4		)	225
LNG Trading Derivatives	(92		)	44			(48		)		(60		)		—			(60		)
FX Derivatives	30			(14		)	16				9				(4		)	5
FX Derivatives	(2		)	1			(1		)		(6		)		5			(1		)

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE 7—OTHER NON-CURRENT ASSETS

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, other non-current assets, net consisted of the following (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Advances made to municipalities for water system enhancements	$	89	$	90	$	86	$	87
Advances and other asset conveyances to third parties to support LNG terminals	55		54		60		55
Advances made under EPC and non-EPC contracts					7		29
Equity method investments					197		108
Debt issuance costs and debt discount, net					48		45
Tax-related payments and receivables	21		21		20		20
Equity method investments	124		94
Advances made under EPC and non-EPC contracts	11		14
Other	37		32		58		44
Total other non-current assets, net	$	337	$	305	$	476	$	388

Equity Method Investments

Our equity method investments consist of interests in privately-held companies. In 2017, we acquired an equity interest in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline Company, LLC (“Midship Pipeline”). Midship Pipeline is currently constructing an approximately 200-mile natural gas pipeline project (the “Midship Project”) that connects production in the Anadarko Basin to Gulf Coast markets. Construction of the Midship Project commenced in the first quarter of 2019.

Subsequent to Midship Project obtaining its financing in the form of credit facilities, in conjunction with existing equity, Midship Holdings is able to finance its current activities without additional subordinated financial support. As a result of the total equity investment at risk being sufficient to finance its activities, Midship Holdings is no longer a variable interest entity. We continue to report Midship Holdings, which we account for as an equity method ~~investment due~~investment. See Note 8—Other Non-Current Assets of our Notes to Consolidated Financial Statements in our ~~ability to exercise significant influence over~~annual report on Form 10-K for the ~~operating and financial policies of Midship Holdings through our non-controlling voting rights on its board of managers.~~ year ended December 31, 2019 for further information.

Our investment in Midship Holdings, net of impairment losses, was ~~$117~~$195 million and ~~$85~~$105 million at ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively.

Cheniere LNG O&M Services, LLC (“O&M Services”), our wholly owned subsidiary provides the development, construction, operation and maintenance services associated with the Midship Project pursuant to agreements in which O&M Services receives an agreed upon fee and reimbursement of costs incurred. O&M Services recorded $3 million ~~in each of the three months ended June 30, 2019 and 2018 and $7 million~~ and $4 million in the ~~six~~three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively, of other revenues and $2 million and $4$3 million of accounts

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

receivable as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively, for services provided to Midship Pipeline under these agreements. CCL has entered into a transportation precedent agreement and a negotiated rate agreement with Midship Pipeline to secure firm pipeline transportation capacity for a period of 10 years following commencement of the Midship Project. In ~~May 2018,~~March 2020, CCH and CCL ~~issued~~entered into a ~~letter of credit to~~guaranty agreement whereby CCH absolutely and irrevocably guarantees CCL’s obligation under the transportation precedent agreement with Midship ~~Pipeline for drawings up to an aggregate maximum amount of $16 million. Midship Pipeline had not made any drawings on this letter of credit as of June 30, 2019.~~Pipeline.

NOTE 8—NON-CONTROLLING INTEREST AND VARIABLE INTEREST ENTITY

We own a 48.6% limited partner interest in Cheniere Partners in the form of 104.5 million common units and 135.4 million subordinated units, with the remaining non-controlling interest held by Blackstone CQP Holdco LP (“Blackstone CQP Holdco”) and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. Cheniere Partners is accounted for as a consolidated variable interest entity. See Note ~~10—~~9—Non-Controlling Interest and Variable Interest ~~Entities~~Entity of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019 for further information.

The following table presents the summarized assets and liabilities (in millions) of Cheniere Partners, our consolidated VIE, which are included in our Consolidated Balance Sheets. The assets in the table below may only be used to settle obligations of Cheniere Partners. In addition, there is no recourse to us for the consolidated VIE’s liabilities. The assets and liabilities in the table below include third-party assets and liabilities of Cheniere Partners only and exclude intercompany balances that eliminate in consolidation.



	March 31,		December 31,
	2020		2019
ASSETS
Current assets
Cash and cash equivalents	$	1,734	$	1,781
Restricted cash	109		181
Accounts and other receivables	259		297
Other current assets	160		184
Total current assets	2,262		2,443

Property, plant and equipment, net	16,476		16,368
Other non-current assets, net	309		309
Total assets	$	19,047	$	19,120

LIABILITIES
Current liabilities
Accrued liabilities	$	569	$	709
Current debt	1,996		—
Other current liabilities	120		210
Total current liabilities	2,685		919

Long-term debt, net	15,591		17,579
Other non-current liabilities	88		104
Total liabilities	$	18,364	$	18,602

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 9—ACCRUED LIABILITIES

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, accrued liabilities consisted of the following (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Interest costs and related debt fees	$	405	$	233	$	380	$	293
Accrued natural gas purchases	402		610		318		460
LNG terminals and related pipeline costs	630		125		120		327
Compensation and benefits	58		117		42		115
Accrued LNG inventory	3		14		14		6
Other accrued liabilities	74		70		48		80
Total accrued liabilities	$	1,572	$	1,169	$	922	$	1,281

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 10—DEBT

As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, our debt consisted of the following (in millions):


	June 30,			December 31,			March 31,			December 31,
	2019			2018			2020			2019
Long-term debt:
SPL
5.625% Senior Secured Notes due 2021 (“2021 SPL Senior Notes”)	$	2,000		$	2,000		$	—		$	2,000
6.25% Senior Secured Notes due 2022 (“2022 SPL Senior Notes”)	1,000			1,000			1,000			1,000
5.625% Senior Secured Notes due 2023 (“2023 SPL Senior Notes”)	1,500			1,500			1,500			1,500
5.75% Senior Secured Notes due 2024 (“2024 SPL Senior Notes”)	2,000			2,000			2,000			2,000
5.625% Senior Secured Notes due 2025 (“2025 SPL Senior Notes”)	2,000			2,000			2,000			2,000
5.875% Senior Secured Notes due 2026 (“2026 SPL Senior Notes”)	1,500			1,500			1,500			1,500
5.00% Senior Secured Notes due 2027 (“2027 SPL Senior Notes”)	1,500			1,500			1,500			1,500
4.200% Senior Secured Notes due 2028 (“2028 SPL Senior Notes”)	1,350			1,350			1,350			1,350
5.00% Senior Secured Notes due 2037 (“2037 SPL Senior Notes”)	800			800			800			800
$1.2 billion SPL Working Capital Facility executed in 2020 (“2020 SPL Working Capital Facility”)							—			—
Cheniere Partners
5.250% Senior Notes due 2025 (“2025 CQP Senior Notes”)	1,500			1,500			1,500			1,500
5.625% Senior Notes due 2026 (“2026 CQP Senior Notes”)	1,100			1,100			1,100			1,100
2016 CQP Credit Facilities	—			—
2019 CQP Credit Facilities	649			—
4.500% Senior Notes due 2029 (“2029 CQP Senior Notes”)							1,500			1,500
CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”)							—			—
CCH
7.000% Senior Secured Notes due 2024 (“2024 CCH Senior Notes”)	1,250			1,250			1,250			1,250
5.875% Senior Secured Notes due 2025 (“2025 CCH Senior Notes”)	1,500			1,500			1,500			1,500
5.125% Senior Secured Notes due 2027 (“2027 CCH Senior Notes”)	1,500			1,500			1,500			1,500
4.80% Senior Secured Notes due 2039 (“4.80% CCH Senior Notes”)							727			727
3.925% Senior Secured Notes due 2039 (“3.925% CCH Senior Notes”)							475			475
3.700% Senior Secured Notes due 2029 (“2029 CCH Senior Notes”)							1,500			1,500
CCH Credit Facility	6,138			5,156			3,283			3,283
CCH HoldCo II
11.0% Convertible Senior Secured Notes due 2025 (“2025 CCH HoldCo II Convertible Senior Notes”)	1,536			1,455			1,278			1,578
Cheniere
4.875% Convertible Unsecured Notes due 2021 (“2021 Cheniere Convertible Unsecured Notes”)	1,248			1,218			1,278			1,278
4.25% Convertible Senior Notes due 2045 (“2045 Cheniere Convertible Senior Notes”)	625			625			625			625
$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”)	—			—			455			—
Unamortized premium, discount and debt issuance costs, net	(752		)	(775		)	(681		)	(692		)
Total long-term debt, net	29,944			28,179			28,940			30,774

Current debt:
$1.2 billion SPL Working Capital Facility (“SPL Working Capital Facility”)	—			—
2021 SPL Senior Notes							2,000			—
$1.2 billion SPL Working Capital Facility executed in 2015 (“2015 SPL Working Capital Facility”)							—			—
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)	—			168			141			—
Cheniere Marketing trade finance facilities	—			71			—			—
Unamortized premium, discount and debt issuance costs, net							(4		)	—
Total current debt	—			239			2,137			—

Total debt, net	$	29,944		$	28,418		$	31,077		$	30,774

~~2019 Debt Issuances and Terminations~~

~~2016 CQP Credit Facilities~~

In May 2019, the remaining commitments under the 2016 CQP Credit Facilities were terminated. There were no write-offs of debt issuance costs associated with the termination of the 2016 CQP Credit Facilities.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

~~2019 CQP Credit Facilities~~2020 Material Debt Activities

2020 SPL Working Capital Facility

In ~~May 2019, Cheniere Partners~~March 2020, SPL entered into the ~~$1.5~~2020 SPL Working Capital Facility with aggregate commitments of $1.2 billion, ~~2019 CQP Credit Facilities,~~ which ~~consist of a $750 million term loan (“CQP Term Facility”) and a $750 million revolving credit facility (“CQP Revolving Facility”). Borrowings under~~replaced the ~~2019 CQP Credit Facilities will~~2015 SPL Working Capital Facility. The 2020 SPL Working Capital Facility is intended to be used for loans to ~~fund the development~~SPL (“SPL Revolving Loans”), swing line loans to SPL (“SPL Swing Line Loans”) and ~~construction of Train 6 of the SPL Project and subject to a sublimit, for general corporate purposes. The CQP Revolving Facility is also available for~~ the issuance of letters of ~~credit.~~

credit on behalf of SPL, primarily for (1) the refinancing of the 2015 SPL Working Capital Facility, (2) fees and expenses related to the 2020 SPL Working Capital Facility, (3) SPL’s gas purchase obligations and (4) SPL and certain of its future subsidiaries’ general corporate purposes. SPL may, from time to time, request increases in the commitments under the 2020 SPL Working Capital Facility of up to $800 million.

Loans under the ~~2019 CQP Credit Facilities will~~2020 SPL Working Capital Facility accrue interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the senior facility agent’s published prime rate, the federal funds ~~effective~~ rate, as published by the Federal Reserve Bank of New York, plus 0.50%, and ~~the adjusted one-month~~one month LIBOR plus ~~1.0%~~0.50%), plus the applicable margin. ~~Under the CQP Term Facility, the~~The applicable margin for LIBOR loans under the 2020 SPL Working Capital Facility is ~~1.50%~~1.125% to 1.750% per annum (depending on the then-current rating of SPL), and the applicable margin for base rate loans under the 2020 SPL Working Capital Facility is ~~0.50%~~0.125% to 0.750% per annum in each case with a 0.25% step-up beginning on May 29, 2022. Under the CQP Revolving Facility, the applicable margin for LIBOR loans is 1.25% to 2.125% per annum, and the applicable margin for base rate loans is 0.25% to 1.125% per annum, in each case depending(depending on the then-current rating of ~~Cheniere Partners.~~SPL). Interest on LIBOR loans is due and payable at the end of each applicable LIBOR period, ~~(and at the end of every three-month period within the LIBOR period, if any),~~ and interest on base rate loans is due and payable at the end of each ~~calendar~~fiscal quarter.

~~Cheniere Partners incurred $20 million of discounts and debt issuance costs in conjunction with the entry into the 2019 CQP Credit Facilities. Cheniere Partners~~SPL pays a commitment fee equal to an annual rate of ~~30%~~0.1% to 0.3% (depending on the then-current rating of SPL), which accrues on the ~~margin for LIBOR loans multiplied by the average~~ daily amount of the ~~undrawn~~total commitment ~~payable quarterly in arrears.~~less the sum of (1) the outstanding principal amount of SPL Revolving Loans, (2) letters of credit issued and (3) the outstanding principal amount of SPL Swing Line Loans. If draws are made upon a letter of credit issued under the 2020 SPL Working Capital Facility and SPL does not elect for such draw to be deemed an SPL LC Loan (an “SPL LC Draw”), SPL is required to pay the full amount of the SPL LC Draw on or prior to noon eastern time on the business day of the SPL LC Draw. An SPL LC Draw accrues interest at the base rate plus the applicable margin. As of March 31, 2020, 0 SPL LC Draws had been made upon any letters of credit issued under the 2020 SPL Working Capital Facility.

The ~~2019 CQP Credit Facilities mature~~2020 SPL Working Capital Facility matures on May 29, 2024. The principal of any loans under the 2019 CQP Credit Facilities must be repaid in quarterly installments commencing on May 29, 2023 based on an amortization schedule. Any outstanding balanceMarch 19, 2025, but may be ~~repaid, in whole or in part, at any time without premium or penalty, except~~extended with consent of the lenders. The 2020 SPL Working Capital Facility provides for ~~interest hedging and interest rate breakage costs.~~ mandatory prepayments under customary circumstances.

The ~~2019 CQP Credit Facilities contain~~2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative ~~covenants,~~covenants. SPL is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, satisfaction of a 12-month forward-looking and ~~limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions~~backward-looking 1.25:1.00 debt service reserve ratio test. The obligations of SPL under the 2020 SPL Working Capital Facility are ~~satisfied.~~

~~The 2019 CQP Credit Facilities are unconditionally guaranteed~~secured by ~~each subsidiary~~substantially all of ~~Cheniere Partners other than~~the assets of SPL ~~Sabine Pass LNG-LP, LLC and certain subsidiaries of Cheniere Partners owning other development projects,~~ as well as ~~certain other specified subsidiaries and members~~a pledge of all of the ~~foregoing entities.~~membership interests in SPL and certain future subsidiaries of SPL on a pari passu basis by a first priority lien with the SPL Senior Notes.

2025 CCH HoldCo II Convertible Senior Notes

In February 2020, the amended and restated note purchase agreement for the 2025 CCH HoldCo II Convertible Senior Notes was amended to allow CCH HoldCo II the option to redeem all or a portion of the outstanding notes with cash at a price of $1,080 per $1,000 principal amount, at the time of any CCH HoldCo II- or noteholder-initiated conversion through September 2, 2020. In March 2020, CCH HoldCo II redeemed an aggregate outstanding principal amount of $300 million with cash. CCH HoldCo II retains the ability to convert the 2025 CCH HoldCo II Convertible Senior Notes into our common stock at a conversion price equal to the lower of (1) a 10% discount to the average of the daily volume-weighted average price (“VWAP”) of our common stock for the 90 trading day period prior to the date on which notice of conversion is provided and (2) a 10% discount to the closing price of our common stock on the trading day preceding the date on which notice of conversion is provided. The noteholders retain the ability to request conversion into our common stock at a conversion price equal to the average of the daily VWAP of our common stock for the 90 trading day period preceding the date on which notice of requested conversion is provided. Conversions remain subject to various limitations and conditions.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Credit Facilities

Below is a summary of our credit facilities outstanding as of ~~June 30, 2019~~March 31, 2020 (in millions):


	SPL Working Capital Facility (1)		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility		2020 SPL Working Capital Facility		2019 CQP Credit Facilities		CCH Credit Facility		CCH Working Capital Facility		Cheniere Revolving Credit Facility
Original facility size	$	1,200	$	1,500	$	8,404	$	350	$	750	$	1,200	$	1,500	$	8,404	$	350	$	750
Incremental commitments	—		—		1,566		850		500		—		—		1,566		850		500
Less:
Outstanding balance	—		649		6,138		—		—		—		—		3,283		141		455
Commitments prepaid or terminated	—		—		3,832		—		—		—		750		6,687		—		—
Letters of credit issued	415		—		—		338		—		414		—		—		399		365
Available commitment	$	785	$	851	$	—	$	862	$	1,250	$	786	$	750	$	—	$	660	$	430

Interest rate on outstanding balance	LIBOR plus 1.75% or base rate plus 0.75%		(2)		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Interest rate on available balance											LIBOR plus 1.125% - 1.750% or base rate plus 0.125% - 0.750%		LIBOR plus 1.25% - 2.125% or base rate plus 0.25% - 1.125%		LIBOR plus 1.75% or base rate plus 0.75%		LIBOR plus 1.25% - 1.75% or base rate plus 0.25% - 0.75%		LIBOR plus 1.75% - 2.50% or base rate plus 0.75% - 1.50%
Weighted average interest rate of outstanding balance	n/a		3.92%		4.15%		n/a		n/a		n/a		n/a		2.74%		2.77%		2.70%
Maturity date	December 31, 2020		May 29, 2024		June 30, 2024		June 29, 2023		December 23, 2022		March 19, 2025		May 29, 2024		June 30, 2024		June 29, 2023		December 13, 2022


~~(1)~~	The SPL Working Capital Facility was amended in May 2019 in connection with commercialization and financing of Train 6 of the SPL Project. All terms of the SPL Working Capital Facility substantially remained unchanged.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~


~~(2)~~	LIBOR plus 1.50% or base rate plus 0.50%, with a 0.25% step-up beginning on May 29, 2022 for the CQP Term Facility. LIBOR plus 1.25% to 2.125% or base rate plus 0.25% to 1.125%, depending on the then-current rating of Cheniere Partners for the CQP Revolving Facility.

Convertible Notes

Below is a summary of our convertible notes outstanding as of ~~June 30, 2019~~March 31, 2020 (in millions):


	2021 Cheniere Convertible Unsecured Notes			2025 CCH HoldCo II Convertible Senior Notes			2045 Cheniere Convertible Senior Notes			2021 Cheniere Convertible Unsecured Notes			2025 CCH HoldCo II Convertible Senior Notes			2045 Cheniere Convertible Senior Notes
Aggregate original principal	$	1,000		$	1,000		$	625		$	1,000		$	1,000		$	625
Add: interest paid-in-kind										278			578			—
Less: aggregate principal redeemed										—			(300		)	—
Aggregate remaining principal										$	1,278		$	1,278		$	625

Debt component, net of discount and debt issuance costs	$	1,172		$	1,519		$	311		$	1,230		$	1,250		$	315
Equity component	$	210		$	—		$	194		$	211		$	—		$	194
Interest payment method	Paid-in-kind			Paid-in-kind (1)			Cash			Paid-in-kind			Paid-in-kind / cash (1)			Cash
Conversion by us (2)	—			(3)			(4)			—			(3)			(4)
Conversion by holders (2)	(5)			(6)			(7)			(5)			(3)			(6)
Conversion basis	Cash and/or stock			Stock			Cash and/or stock			Cash and/or stock			Cash and/or stock			Cash and/or stock
Conversion value in excess of principal	$	—		$	—		$	—		$	—		n/a			$	—
Maturity date	May 28, 2021			May 13, 2025			March 15, 2045			May 28, 2021			May 13, 2025			March 15, 2045
Contractual interest rate	4.875		%	11.0		%	4.25		%	4.875		%	11.0		%	4.25		%
Effective interest rate (8)	8.4		%	11.9		%	9.4		%
Remaining debt discount and debt issuance costs amortization period (9)	1.9 years			1.3 years			25.7 years
Effective interest rate (7)										8.2		%	12.2		%	9.4		%
Remaining debt discount and debt issuance costs amortization period (8)										1.2 years			0.5 years			25.0 years


(1)	Prior to the substantial completion of Train 2 of the CCL Project in August 2019, interest ~~will be~~was paid entirely in kind. Following ~~this date,~~substantial completion, the interest ~~generally must be~~has been paid in cash; however, a portion of the interest may, in the future, be paid in kind under certain specified circumstances.


(2)	Conversion is subject to various limitations and conditions.

(3)

Convertible into cash or stock at our option on or after ~~the later of~~ March 1, 2020 until September 2, 2020, and ~~the substantial completion of Train~~into stock upon conversion notice by us or note holders after September 2, ~~of the CCL Project,~~2020, provided that our market capitalization is not less than $10.0 billion (“Eligible Conversion Date”). The conversion price for stock is the lower of (1) a 10% discount to the average of the ~~daily volume-weighted average price (“VWAP”)~~VWAP of our common stock for the 90 trading day period prior to the date notice is provided, and (2) a ~~10% discount to the closing price of our common stock on the trading day preceding the date notice is provided.~~

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

10% discount to the closing price of our common stock on the trading day preceding the date notice is provided. The conversion price for cash is $1,080 per $1,000 principal amount of the notes. In March 2020, we delivered our first notice to convert notes in an aggregate outstanding principal amount of $300 million into cash.


(4)	Redeemable at any time after March 15, 2020 at a redemption price payable in cash equal to the accreted amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date.


(5)	Initially convertible at $93.64 (subject to adjustment upon the occurrence of certain specified events), provided that the closing price of our common stock is greater than or equal to the conversion price on the conversion date.


(6)	Convertible on or after the six-month anniversary of the Eligible Conversion Date, provided that our total market capitalization is not less than $10.0 billion, at a price equal to the average of the daily VWAP of our common stock for the 90 trading day period prior to the date on which notice of conversion is provided.

~~(7)~~

Prior to December 15, 2044, convertible only under certain circumstances as specified in the indenture; thereafter, holders may convert their notes regardless of these circumstances. The conversion rate will initially equal 7.2265 shares of our common stock per $1,000 principal amount of the 2045 Cheniere Convertible Senior Notes, which corresponds to an initial conversion price of approximately $138.38 per share of our common stock (subject to adjustment upon the occurrence of certain specified events).


~~(8)~~(7)	Rate to accrete the discounted carrying value of the convertible notes to the face value over the remaining amortization period.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~


~~(9)~~(8)	We amortize any debt discount and debt issuance costs using the effective interest over the period through contractual maturity except for the 2025 CCH HoldCo II Convertible Senior Notes, which are amortized through the date they are first convertible by holders into our common stock.

Restrictive Debt Covenants

As of ~~June 30, 2019,~~March 31, 2020, each of our issuers was in compliance with all covenants related to their respective debt agreements.

Interest Expense

Total interest expense, including interest expense related to our convertible notes, consisted of the following (in millions):


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Interest cost on convertible notes:
Interest per contractual rate	$	64		$	58		$	126		$	116		$	63		$	62
Amortization of debt discount	9			8			19			16			14			10
Amortization of debt issuance costs	3			2			6			4			3			3
Total interest cost related to convertible notes	76			68			151			136			80			75
Interest cost on debt and finance leases excluding convertible notes	382			344			755			680			391			373
Total interest cost	458			412			906			816			471			448
Capitalized interest	(86		)	(196		)	(287		)	(384		)	(59		)	(201		)
Total interest expense, net	$	372		$	216		$	619		$	432		$	412		$	247

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Fair Value Disclosures

The following table shows the carrying amount ~~which is net of unamortized premium, discount and debt issuance costs,~~ and estimated fair value of our debt (in millions):


	June 30, 2019				December 31, 2018				March 31, 2020				December 31, 2019
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
Senior notes (1)	$	19,483	$	21,499	$	19,466	$	19,901	$	22,700	$	20,805	$	22,700	$	24,650
2037 SPL Senior Notes (2)	791		912		791		817		800		709		800		934
4.80% CCH Senior Notes (2)									727		594		727		830
3.925% CCH Senior Notes (2)									475		350		475		495
Credit facilities (3)	6,668		6,668		5,294		5,294		3,879		3,879		3,283		3,283
2021 Cheniere Convertible Unsecured Notes (2)	1,172		1,302		1,126		1,236		1,278		1,248		1,278		1,312
2025 CCH HoldCo II Convertible Senior Notes (2)	1,519		1,771		1,432		1,612		1,278		1,406		1,578		1,807
2045 Cheniere Convertible Senior Notes (4)	311		489		310		431		625		281		625		498

(1)

Includes ~~2021~~the SPL Senior Notes ~~2022~~except the 2037 SPL Senior Notes, ~~2023 SPL Senior Notes, 2024 SPL Senior Notes, 2025 SPL Senior Notes, 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes, 2025~~the CQP Senior Notes ~~2026 CQP Senior Notes, 2024 CCH Senior Notes, 2025 CCH Senior Notes~~ and ~~2027~~the 144A CCH Senior Notes. 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 our stock price and interest rates based on debt issued by parties with comparable credit ratings to us and inputs that are not observable in the market.

(3)

Includes 2015 SPL Working Capital Facility, ~~2016 CQP Credit Facilities,~~2020 SPL Working Capital Facility, 2019 CQP Credit Facilities, CCH Credit Facility, CCH Working Capital Facility, Cheniere Revolving Credit Facility and Cheniere Marketing trade finance facilities. The Level 3 estimated fair value approximates the principal amount because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.


(4)	The Level 1 estimated fair value was based on unadjusted quoted prices in active markets for identical liabilities that we had the ability to access at the measurement date.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE 11—LEASES

Our leased assets consist primarily of (1) LNG vessel time charters (“vessel charters”), (2) tug vessels, (3) office space and facilities and (4) land sites, all of which are classified as operating leases except for our tug vessels at the Corpus Christi LNG terminal, which are classified as finance leases.

ASC 842 requires a lessee to recognize leases on its balance sheet by recording a lease liability representing the obligation to make future lease payments and a right-of-use asset representing the right to use the underlying asset for the lease term. As our leases generally do not provide an implicit rate, in order to calculate the lease liability, we discounted our expected future lease payments using our relevant subsidiary’s incremental borrowing rate at the later of January 1, 2019 or the commencement date of the lease. The incremental borrowing rate is an estimate of the rate of interest that a given subsidiary would have to pay to borrow on a collateralized basis over a similar term to that of the lease term.

Many of our leases contain renewal options exercisable at our sole discretion. Options to renew a lease are included in the lease term and recognized as part of the right-of-use asset and lease liability only to the extent they are reasonably certain to be exercised, such as when necessary to satisfy obligations that existed at the execution of the lease or when the non-renewal would otherwise result in an economic penalty.

We have elected the practical expedient to omit leases with an initial term of 12 months or less (“short-term lease”) from recognition on the balance sheet. We recognize short-term lease payments on a straight-line basis over the lease term and variable payments under short-term leases in the period in which the obligation is incurred.

Certain of our leases contain non-lease components which are not separated from the lease components when calculating the right-of-use asset and lease liability per our use of the practical expedient to combine both components of an arrangement for all classes of leased assets.

~~Certain of our leases also contain variable payments, such as inflation, that are not included when calculating the right-of-use asset and lease liability unless the payments are in-substance fixed.~~

We recognize lease expense for operating leases on a straight-line basis over the lease term. We recognize lease expense for finance leases as the sum of the amortization of the right-of-use assets on a straight-line basis and the interest on lease liabilities using the effective interest method over the lease term.

The following table shows the classification and location of our right-of-use assets and lease liabilities on our Consolidated Balance Sheets (in millions):


	Consolidated Balance Sheet Location	June 30, 2019		Consolidated Balance Sheet Location	March 31, 2020		December 31, 2019
Right-of-use assets—Operating	Operating lease assets, net	$	502	Operating lease assets, net	$	350	$	439
Right-of-use assets—Financing	Property, plant and equipment, net	58		Property, plant and equipment, net	55		56
Total right-of-use assets		$	560		$	405	$	495

Current operating lease liabilities	Current operating lease liabilities	$	292	Current operating lease liabilities	$	178	$	236
Current finance lease liabilities	Other current liabilities	1		Other current liabilities	1		1
Non-current operating lease liabilities	Non-current operating lease liabilities	202		Non-current operating lease liabilities	164		189
Non-current finance lease liabilities	Non-current finance lease liabilities	58		Non-current finance lease liabilities	58		58
Total lease liabilities		$	553		$	401	$	484

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table shows the classification and location of our lease cost on our Consolidated Statements of Operations (in millions):


						Consolidated Statement of Operations Location	Three Months Ended March 31,
	Consolidated Statement of Operations Location	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019		Consolidated Statement of Operations Location	2020		2019
Operating lease cost (1)	Operating costs and expenses (2)	$	140	$	277	Operating costs and expenses (2)	$	141	$	137
Finance lease cost:
Amortization of right-of-use assets	Depreciation and amortization expense	1		2		Depreciation and amortization expense	1		1
Interest on lease liabilities	Interest expense, net of capitalized interest	3		5		Interest expense, net of capitalized interest	2		2
Total lease cost		$	144	$	284		$	144	$	140


(1)	Includes ~~$46~~$35 million and ~~$93~~$47 million of short-term lease costs during the three months ended March 31, 2020 and ~~$8 million~~2019, respectively, and ~~$13~~$5 million of variable lease costs ~~incurred~~paid to the lessor during each of the three ~~and six~~ months ended ~~June 30, 2019, respectively.~~March 31, 2020 and 2019.


(2)	Presented in cost of sales, operating and maintenance expense or selling, general and administrative expense consistent with the nature of the asset under lease.

Future annual minimum lease payments for operating and finance leases as of ~~June 30, 2019~~March 31, 2020 are as follows (in millions):


Years Ending December 31,	Operating Leases (1)			Finance Leases			Operating Leases (1)			Finance Leases
2019	$	192		$	5
2020	167			10			$	158		$	8
2021	39			10			58			10
2022	19			10			23			10
2023	19			10			22			10
2024							22			10
Thereafter	166			146			166			136
Total lease payments	602			191			449			184
Less: Interest	(108		)	(132		)	(107		)	(125		)
Present value of lease liabilities	$	494		$	59		$	342		$	59


(1)	Does not include ~~$1.6~~$2.0 billion of legally binding minimum lease payments primarily for vessel charters which were executed as of ~~June 30, 2019~~March 31, 2020 but will commence in future period primarily ~~between 2020 and 2021~~in the next two years and have fixed minimum lease terms of up to seven years.

Future annual minimum lease payments for operating and capital leases as of December 31, 2018, prepared in accordance with accounting standards prior to the adoption of ASC 842, were as follows (in millions):

Years Ending December 31, Operating Leases (1) Capital Leases (2)
2019 (3) $ 380
$ 5
2020 184
5
2021 238
5
2022 264
5
2023 264
5
Thereafter 999
73
Total lease payments 2,329
98
Less: Interest —
(39 )
Present value of lease liabilities $ 2,329
$ 59


~~(1)~~	~~Includes certain lease option renewals that are reasonably assured and payments for certain non-lease components~~. ~~Also includes $79 million in payments for short-term leases and $1.6 billion in payments for LNG vessel charters which were previously executed but will commence primarily between 2020 and 2021.~~


~~(2)~~	~~Does not include payments for non-lease components of $98 million.~~


~~(3)~~	~~Does not include $43 million in aggregate payments we will receive from our LNG vessel subcharters.~~

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

The following table shows the weighted-average remaining lease term (in years) and the weighted-average discount rate for our operating leases and finance leases:



	March 31, 2020		December 31, 2019
	Operating Leases	Finance Leases	Operating Leases	Finance Leases
Weighted-average remaining lease term (in years)	9.8	18.4	8.4	18.7
Weighted-average discount rate (1)	5.0%	16.2%	5.2%	16.2%

June 30, 2019
Operating Leases Finance Leases
Weighted-average remaining lease term (in years) 7.2 19.3
Weighted-average discount rate (1) 5.4% 16.2%


(1)	The finance leases commenced prior to the adoption of ~~ASC 842.~~the current leasing standard under GAAP. In accordance with previous accounting guidance, the implied rate is based on the fair value of the underlying assets.

The following table includes other quantitative information for our operating and finance leases (in millions):


			Three Months Ended March 31,
	Six Months Ended June 30, 2019		2020		2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	174	$	94	$	90
Operating cash flows from finance leases	5		2		2
Financing cash flows from finance leases	—		—		—
Right-of-use assets obtained in exchange for new operating lease liabilities	106		8		64

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

LNG Vessel Subcharters

From time to time, we sublease certain LNG vessels under charter to third parties while retaining our existing obligation to the original lessor. We have elected the practical expedient for lessors to combine lease and non-lease components and since the lease component is the predominant component of each arrangement, these subleases are accounted for as operating leases. The subleases have lease terms of up to one year and many contain short-term renewal options exercisable at the discretion of the third party. As of ~~June 30,~~March 31, 2020 and December 31, 2019, we had ~~$13~~$3 million and $9 million in future minimum sublease payments to be received from LNG vessel subcharters, respectively, which will be recognized entirely within ~~2019. We recognize fixed sublease income on a straight-line basis over the lease term of the sublease while variable sublease income is recognized when earned.~~2020. We recognized ~~$31~~$52 million and ~~$68~~$37 million of sublease income, including $5$15 million and ~~$10~~$5 million of variable lease payments, during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019, respectively, in other revenues on our Consolidated Statements of Operations.

NOTE 12—REVENUES FROM CONTRACTS WITH CUSTOMERS

The following table represents a disaggregation of revenue earned from contracts with customers during the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):


	Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended March 31,
	2019		2018			2019		2018			2020		2019
LNG revenues(1)	$	2,080	$	1,516		$	4,147	$	3,668		$	2,404	$	2,068
Regasification revenues	67		65			133		130			67		66
Other revenues	21		13			36		23			22		15
Total revenues from customers	2,168		1,594			4,316		3,821			2,493		2,149
Net derivative gains (losses) (1)	93		(64		)	169		(60		)
Other revenues (2)	31		13			68		24
Net derivative gains (2)											164		75
Other (3)											52		37
Total revenues	$	2,292	$	1,543		$	4,553	$	3,785		$	2,709	$	2,261

(1)

LNG revenues include revenues for LNG cargoes in which our customers exercised their contractual right to not take delivery but remained obligated to pay fixed fees irrespective of such election. Revenue associated with canceled LNG cargoes is generally recognized upon notice of customer cancellation because our customers have no contractual right to take delivery of canceled LNG cargoes in future periods and our performance obligations with respect to such canceled LNG cargoes have been satisfied.


(2)	See Note 6—Derivative Instruments for additional information about our derivatives.


~~(2)~~(3)	Includes revenues from LNG vessel subcharters. See Note 11—Leases for additional information about our subleases.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

Contract Assets and Liabilities

The following table shows our contract assets, which ~~we classify~~are classified as other non-current assets, net on our Consolidated Balance Sheets (in millions):

June 30, December 31,
2019 2018
Contract assets $ 8
$ —



	March 31,		December 31,
	2020		2019
Contract assets	$	34	$	18

Contract assets represent our right to consideration for transferring goods or services to the customer under the terms of a sales contract when the associated consideration is not yet due. Changes in contract assets during the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 were primarily attributable to revenue recognized due to the delivery of LNG under certain SPAs for which the associated consideration was not yet due.

The following table reflects the changes in our contract liabilities, which we classify as deferred revenue on our Consolidated Balance Sheets (in millions):


	Six Months Ended June 30, 2019			Three Months Ended March 31, 2020
Deferred revenues, beginning of period	$	139		$	161
Cash received but not yet recognized	136			94
Revenue recognized from prior period deferral	(139		)	(161		)
Deferred revenues, end of period	$	136		$	94

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Transaction Price Allocated to Future Performance Obligations

Because many of our sales contracts have long-term durations, we are contractually entitled to significant future consideration which we have not yet recognized as revenue. The following table discloses the aggregate amount of the transaction price that is allocated to performance obligations that have not yet been satisfied as of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018:~~2019:


	June 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)	Unsatisfied Transaction Price (in billions)		Weighted Average Recognition Timing (years) (1)
LNG revenues	$	108.4	11	$	106.6	11	$	105.4	11	$	106.4	11
Regasification revenues	2.5		5	2.6		6	2.3		5	2.4		5
Total revenues	$	110.9		$	109.2		$	107.7		$	108.8

(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.


~~(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 and TUAs. 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 table above excludes substantially all variable consideration under our SPAs and TUAs.~~ 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 ~~52%~~42% and ~~55%~~58% of our LNG revenues from contracts with a duration of over one year during the three months ended ~~June 30,~~March 31, 2020 and 2019, respectively, were related to variable consideration received from customers. During each of the three months ended March 31, 2020 and ~~2018, respectively, and~~2019, approximately ~~55%~~3% of our ~~LNG~~regasification revenues were related to variable consideration received from ~~contracts with a duration of over one year during~~customers.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

each of the six months ended June 30, 2019 and 2018, were related to variable consideration received from customers. During each of the three and six months ended June 30, 2019 and 2018, approximately 3% of our regasification revenues were related to variable consideration received from customers.

We have entered 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.

NOTE 13—INCOME TAXES

We recorded an income tax ~~benefit~~provision of ~~zero~~$131 million and $3 million during the three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and an income tax provision of $3 million and $12 million during the six months ended June 30, 2019 and 2018,~~ respectively. ~~Changes in the income tax recorded between comparative periods are primarily attributable to changes in the income earned and tax transfer pricing applied to our U.K. integrated marketing function.~~

The effective tax ~~rates during~~rate for the three ~~and six~~ months ended ~~June 30, 2019 and 2018 were~~March 31, 2020 was 17.8%, which is lower than the 21% federal statutory rate ~~during~~primarily due to income allocated to non-controlling interest that is not taxable to Cheniere, partially offset by a one-time discrete event related to an internal tax restructuring. The discrete item resulted in expense of $38 million for the three months ended March 31, 2020. The effective tax rate for the three months ended March 31, 2019 ~~and 2018 interim periods~~was 0.9%, which is lower than the 21% federal statutory rate primarily ~~as a result of~~due to maintaining a valuation allowance against our federal ~~and state net~~ deferred tax assets. Due to historical losses and other available evidence related to our ability to generate taxable income, we continue to maintain a valuation allowance against our federal and state net deferred tax assets at June 30, 2019.

NOTE 14—SHARE-BASED COMPENSATION

We have granted restricted stock shares, restricted stock units, performance stock units and phantom units to employees and non-employee directors under the 2011 Incentive Plan, as amended (the “2011 Plan”) and the 2015 Employee Inducement Incentive Plan.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

For the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, we granted ~~1.3~~1.2 million restricted stock units and ~~0.2~~0.3 million performance stock units at target performance under the 2011 Plan to certain employees. Additionally, 0.2 million incremental shares of our common stock were issued based on performance results from previously-granted performance stock unit awards. Restricted stock units are stock awards that vest over a service period of three years and entitle the holder to receive shares of our common stock upon vesting, subject to restrictions on transfer and to a risk of forfeiture if the recipient terminates employment with us prior to the lapse of the restrictions. Performance stock units provide for cliff vesting after a period of three years with payouts based on metrics dependent upon market and performance achieved over the period from January 1, ~~2019~~2020 through December 31, ~~2021~~2022 compared to pre-established performance targets. The settlement amounts of the awards are based on market and performance metrics which include cumulative distributable cash flow per share, and in certain circumstances, absolute total shareholder return (“~~TSR”~~ATSR”) of our common stock. Where applicable, the compensation for performance stock units is based on fair value assigned to the market metric of ~~TSR~~ATSR using a Monte Carlo model upon grant, which remains constant through the vesting period, and a performance metric, which will vary due to changing estimates regarding the expected achievement of the performance metric of cumulative distributable cash flow per share. The number of shares that may be earned at the end of the vesting period ranges from ~~25%~~0% up to 300% of the target award ~~amount if the threshold performance is met.~~amount. Both restricted stock units and performance stock units will be settled in Cheniere common stock (on a one-for-one basis) and are classified as equity awards.

Total share-based compensation consisted of the following (in millions):


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Share-based compensation costs, pre-tax:
Equity awards	$	32		$	22		$	61		$	39		$	30		$	29
Liability awards	2			15			5			32			—			3
Total share-based compensation	34			37			66			71			30			32
Capitalized share-based compensation	(1		)	(7		)	(5		)	(13		)	(1		)	(4		)
Total share-based compensation expense	$	33		$	30		$	61		$	58		$	29		$	28
Tax benefit associated with share-based compensation expense	$	—		$	—		$	1		$	2		$	18		$	1

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

NOTE 15—NET INCOME ~~(LOSS)~~ PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

Basic net income ~~(loss)~~ per share attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net income ~~(loss)~~ attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS reflects potential dilution and is computed by dividing net income ~~(loss)~~ attributable to common stockholders by the weighted average number of common shares outstanding during the period increased by the number of additional common shares that would have been outstanding if the potential common shares had been issued. The dilutive effect of unvested stock is calculated using the treasury-stock method and the dilutive effect of convertible securities is calculated using the if-converted method.

The following table reconciles basic and diluted weighted average common shares outstanding for the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions, except per share data):


	Three Months Ended June 30,						Six Months Ended June 30,				Three Months Ended March 31,
	2019			2018			2019		2018		2020		2019
Weighted average common shares outstanding:
Basic	257.4			242.8			257.3		239.2		253.0		257.1
Dilutive unvested stock	—			—			1.3		2.5		1.1		1.4
Dilutive convertible securities											45.5		—
Diluted	257.4			242.8			258.6		241.7		299.6		258.5

Basic net income (loss) per share attributable to common stockholders	$	(0.44	)	$	(0.07	)	$	0.11	$	1.42
Diluted net income (loss) per share attributable to common stockholders	$	(0.44	)	$	(0.07	)	$	0.11	$	1.40
Basic net income per share attributable to common stockholders											$	1.48	$	0.55
Diluted net income per share attributable to common stockholders											$	1.43	$	0.54

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Potentially dilutive securities that were not included in the diluted net income ~~(loss)~~ per share computations because their effects would have been anti-dilutive were as follows (in millions):


	Three Months Ended June 30,		Six Months Ended June 30,		Three Months Ended March 31,
	2019	2018	2019	2018	2020	2019
Unvested stock (1)	3.8	5.2	3.8	2.6	2.1	2.4
Convertible notes (2)	17.8	17.2	17.8	17.2	—	17.7
Total potentially dilutive common shares	21.6	22.4	21.6	19.8	2.1	20.1


(1)	Does not include 0.7 million shares and 0.6 million shares for ~~each of~~ the three ~~and six~~ months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 0.4 million shares for each of the three and six months ended June 30, 2018~~respectively, of unvested stock because the performance conditions had not yet been satisfied as of ~~June 30, 2019 and 2018, respectively.~~the respective dates.

(2)

Includes number of shares in aggregate issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes and the 2045 Cheniere Convertible Senior ~~Notes. There were no shares included in the computation of diluted net income (loss) per share~~Notes for all periods presented and additionally the 2025 CCH HoldCo II Convertible Senior Notes ~~because substantive non-market-based contingencies underlying~~for the ~~eligible conversion date have not been met as~~three months ended March 31, 2020, following the substantial completion of ~~June 30,~~Train 2 of the CCL Project in August 2019.

NOTE 16—SHARE REPURCHASE PROGRAM

As of March 31, 2020, we had up to $596 million of the share repurchase program available. Under the share repurchase program, repurchases can be made from time to time using a variety of methods, which may include open market purchases, privately negotiated transactions or otherwise, all in accordance with the rules of the SEC and other applicable legal requirements. The timing and amount of any shares of our common stock that are repurchased under the share repurchase program will be determined by our management based on market conditions and other factors. The share repurchase program does not obligate us to acquire any particular amount of common stock, and may be modified, suspended or discontinued at any time or from time to time at our discretion.

NOTE 17—COMMITMENTS AND CONTINGENCIES

We have various contractual obligations which are recorded as liabilities in our Consolidated Financial Statements. Other items, such as certain purchase commitments and other executed contracts which do not meet the definition of a liability as of ~~June 30, 2019,~~March 31, 2020, are not recognized as liabilities but require disclosures in our Consolidated Financial Statements.

Environmental and Regulatory Matters

Our LNG terminals and pipelines are subject to extensive regulation under federal, state and local statutes, rules, regulations and laws. These laws require that we engage in consultations with appropriate federal and state agencies and that we obtain and maintain applicable permits and other authorizations. Failure to comply with such laws could result in legal proceedings, which may include substantial penalties. We believe that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our results of operations, financial condition or cash flows.

Legal Proceedings

We are, and may in the future be, involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. While the results of these litigation matters and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

~~Parallax Litigation~~

In 2015, our wholly owned subsidiary, Cheniere LNG Terminals, LLC (“CLNGT”), entered into discussions with Parallax Enterprises, LLC (“Parallax Enterprises”) regarding the potential joint development of two liquefaction plants in Louisiana (the “Potential Liquefaction Transactions”). While the parties negotiated regarding the Potential Liquefaction Transactions, CLNGT loaned Parallax Enterprises approximately $46 million, as reflected in a secured note dated April 23, 2015, as amended on June 30, 2015, September 30, 2015 and November 4, 2015 (the “Secured Note”). The Secured Note was secured by all assets of Parallax Enterprises and its subsidiary entities. On June 30, 2015, Parallax Enterprises’ parent entity, Parallax Energy LLC (“Parallax Energy”), executed a Pledge and Guarantee Agreement further securing repayment of the Secured Note by providing a parent guaranty and a pledge of all of the equity of Parallax Enterprises in satisfaction of the Secured Note (the “Pledge Agreement”). CLNGT and Parallax Enterprises never executed a definitive agreement to pursue the Potential Liquefaction Transactions. The Secured Note matured on December 11, 2015, and Parallax Enterprises failed to make payment. On February 3, 2016, CLNGT filed an action against Parallax Energy, Parallax Enterprises and certain of Parallax Enterprises’ subsidiary entities, styled Cause No. 4:16-cv-00286, Cheniere LNG Terminals, LLC v. Parallax Energy LLC, et al., in the United States District Court for the Southern District of Texas (the “Texas Federal Suit”). CLNGT asserted claims in the Texas Federal Suit for (1) recovery of all amounts due under the Secured Note and (2) declaratory relief establishing that CLNGT is entitled to enforce its rights under the Secured Note and Pledge Agreement in accordance with each instrument’s terms and that CLNGT has no obligations of any sort to Parallax Enterprises concerning the Potential Liquefaction Transactions. On March 11, 2016, Parallax Enterprises and the other defendants in the Texas Federal Suit moved to dismiss the suit for lack of subject matter jurisdiction. On August 2, 2016, the court denied the defendants’ motion to dismiss without prejudice and permitted the parties to pursue jurisdictional discovery.

On March 11, 2016, Parallax Enterprises filed a suit against us and CLNGT styled Civil Action No. 62-810, Parallax Enterprises LLP v. Cheniere Energy, Inc. and Cheniere LNG Terminals, LLC, in the 25th Judicial District Court of Plaquemines Parish, Louisiana (the “Louisiana Suit”), wherein Parallax Enterprises asserted claims for breach of contract, fraudulent inducement, negligent misrepresentation, detrimental reliance, unjust enrichment and violation of the Louisiana Unfair Trade Practices Act. Parallax Enterprises predicated its claims in the Louisiana Suit on an allegation that we and CLNGT breached a purported agreement to jointly develop the Potential Liquefaction Transactions. Parallax Enterprises sought $400 million in alleged economic damages and rescission of the Secured Note. On April 15, 2016, we and CLNGT removed the Louisiana Suit to the United States District Court for the Eastern District of Louisiana, which subsequently transferred the Louisiana Suit to the United States District Court for the Southern District of Texas, where it was assigned Civil Action No. 4:16-cv-01628 and transferred to the same judge presiding over the Texas Federal Suit for coordinated handling. On August 22, 2016, Parallax Enterprises voluntarily dismissed all claims asserted against CLNGT and us in the Louisiana Suit without prejudice to refiling.

On July 27, 2017, the Parallax entities named as defendants in the Texas Federal Suit reurged their motion to dismiss and simultaneously filed counterclaims against CLNGT and third party claims against us for breach of contract, breach of fiduciary duty, promissory estoppel, quantum meruit and fraudulent inducement of the Secured Note and Pledge Agreement, based on substantially the same factual allegations Parallax Enterprises made in the Louisiana Suit. These Parallax entities also simultaneously filed an action styled Cause No. 2017-49685, Parallax Enterprises, LLC, et al. v. Cheniere Energy, Inc., et al., in the 61st District Court of Harris County, Texas (the “Texas State Suit”), which asserts substantially the same claims these entities asserted in the Texas Federal Suit. On July 31, 2017, CLNGT withdrew its opposition to the dismissal of the Texas Federal Suit without prejudice on jurisdictional grounds and the federal court subsequently dismissed the Texas Federal Suit without prejudice. We and CLNGT simultaneously filed an answer and counterclaims in the Texas State Suit, asserting the same claims CLNGT had previously asserted in the Texas Federal Suit. Additionally, CLNGT filed third party claims against Parallax principals Martin Houston, Christopher Bowen Daniels, Howard Candelet and Mark Evans, as well as Tellurian Investments, Inc., Driftwood LNG, LLC, Driftwood LNG Pipeline LLC and Tellurian Services LLC, formerly known as Parallax Services LLC, including claims for tortious interference with CLNGT’s collateral rights under the Secured Note and Pledge Agreement, fraudulent transfer, conspiracy/aiding and abetting. Discovery in the Texas State Suit is ongoing. Trial is currently set for February 2020.

~~On February 15, 2019, we filed an action with CLNGT against Charif Souki, our former Chairman of the Board and Chief Executive Officer, styled, Cause No. 2019-11529,~~ ~~Cheniere Energy, Inc. and Cheniere LNG Terminals, LLC v. Charif Souki~~, in the 55th District Court of Harris County, Texas, which asserts claims of breach of fiduciary duties, fraudulent transfer, tortious interference with CLNGT’s collateral rights under the Secured Note and Pledge Agreement and conspiracy/aiding and abetting. On April 29, 2019, the court consolidated the Souki matter with the earlier filed pending case against Parallax, Tellurian and the individual defendants in the Texas State Suit.

~~CHENIERE ENERGY, INC. AND SUBSIDIARIES~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED~~

~~(unaudited)~~

~~We do not expect that the resolution of any of the foregoing litigation will have a material adverse impact on our financial results.~~

NOTE ~~17—~~18—CUSTOMER CONCENTRATION

The following table shows customers with revenues of 10% or greater of total revenues from external customers and customers with accounts receivable balances of 10% or greater of total accounts receivable from external customers:


	Percentage of Total Revenues from External Customers				Percentage of Accounts Receivable from External Customers		Percentage of Total Revenues from External Customers		Percentage of Accounts Receivable from External Customers
	Three Months Ended June 30,		Six Months Ended June 30,		June 30,	December 31,	Three Months Ended March 31,		March 31,	December 31,
	2019	2018	2019	2018	2019	2018	2020	2019	2020	2019
Customer A	17%	21%	18%	19%	11%	21%	16%	20%	12%	13%
Customer B	11%	17%	11%	14%	15%	14%	*	12%	*	*
Customer C	11%	18%	12%	22%	15%	18%	*	12%	15%	13%
Customer D	12%	16%	13%	11%	14%	*	*	14%	*	*
Customer E	*	*	*	*	13%	*
Customer F	*	*	*	*	*	10%

* Less than 10%

NOTE ~~18—~~19—SUPPLEMENTAL CASH FLOW INFORMATION

The following table provides supplemental disclosure of cash flow information (in millions):


	Six Months Ended June 30,				Three Months Ended March 31,
	2019		2018		2020		2019
Cash paid during the period for interest on debt and finance leases, net of amounts capitalized	$	271	$	282
Cash paid during the period for interest on debt, net of amounts capitalized					$	295	$	108
Cash paid for income taxes	20		4		1		20

The balance in property, plant and equipment, net funded with accounts payable and accrued liabilities was ~~$958~~$255 million and ~~$935~~$509 million as of ~~June 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively.

~~See~~ ~~Note 11—Leases~~ ~~for our supplemental cash flow information related to our leases.~~


ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Information Regarding Forward-Looking Statements

This quarterly report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical or present facts or conditions, included herein or incorporated herein by reference are “forward-looking statements.” Included among “forward-looking statements” are, among other things:

statements that we expect to commence or complete construction of our proposed LNG terminals, liquefaction facilities, pipeline facilities or other projects, or any expansions or portions thereof, by certain dates, or at all;

statements regarding future levels of domestic and international natural gas production, supply or consumption or future levels of LNG imports into or exports from North America and other countries worldwide or purchases of natural gas, regardless of the source of such information, or the transportation or other infrastructure or demand for and prices related to natural gas, LNG or other hydrocarbon products;

statements regarding any financing transactions or arrangements, or our ability to enter into such transactions;

statements regarding the amount and timing of share repurchases;

statements relating to the construction of our Trains and pipelines, including statements concerning the engagement of any EPC contractor or other contractor and the anticipated terms and provisions of any agreement with any EPC or other contractor, and anticipated costs related thereto;

statements regarding any SPA or other agreement to be entered into or performed substantially in the future, including any revenues anticipated to be received and the anticipated timing thereof, and statements regarding the amounts of total LNG regasification, natural gas liquefaction or storage capacities that are, or may become, subject to contracts;

statements regarding counterparties to our commercial contracts, construction contracts, and other contracts;

statements regarding our planned development and construction of additional Trains ~~and~~or pipelines, including the financing of such Trains or pipelines;

statements that our Trains, when completed, will have certain characteristics, including amounts of liquefaction capacities;

statements regarding our business strategy, our strengths, our business and operation plans or any other plans, forecasts, projections, or objectives, including anticipated revenues, capital expenditures, maintenance and operating costs and cash flows, any or all of which are subject to change;

statements regarding legislative, governmental, regulatory, administrative or other public body actions, approvals, requirements, permits, applications, filings, investigations, proceedings or decisions;

statements regarding our anticipated LNG and natural gas marketing activities;

statements regarding the outbreak of ~~volumes expected to be made available to~~COVID-19 and its impact on our ~~integrated marketing function;~~business and operating results, including any customers not taking delivery of LNG cargoes, the ongoing credit worthiness of our contractual counterparties, any disruptions in our operations or construction of our Trains and the health and safety of our employees, and on our customers, the global economy and the demand for LNG; and


•	any other statements that relate to non-historical or future information.

All of these types of statements, other than statements of historical or present facts or conditions, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “achieve,” “anticipate,” “believe,” “contemplate,” “continue,” “estimate,” “expect,” “intend,” “plan,” “potential,” “predict,” “project,” “pursue,” “target,” the negative of such terms or other comparable terminology. The forward-looking statements contained in this quarterly report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe that such estimates are reasonable, they are inherently uncertain and involve a number of risks and uncertainties beyond our control. In addition, assumptions may prove to be inaccurate. We caution that the forward-looking

statements contained in this quarterly report are not guarantees of future performance and that such statements may not be realized or the forward-looking statements or events may not occur. Actual results may differ materially from those anticipated or implied in forward-looking statements as a result of a variety of factors described in this quarterly report and in the other reports and other information that we file with the SEC, including those discussed under “Risk Factors” in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. These forward-looking statements speak only as of the date made, and other than

as required by law, we undertake no obligation to update or revise any forward-looking statement or provide reasons why actual results may differ, whether as a result of new information, future events or otherwise.

Introduction

The following discussion and analysis presents management’s view of our business, financial condition and overall performance and should be read in conjunction with our Consolidated Financial Statements and the accompanying notes. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future. Our discussion and analysis includes the following subjects:

Overview of Business

Overview of Significant Events

Impact of COVID-19 and Market Environment

Liquidity and Capital Resources

Results of Operations

Off-Balance Sheet Arrangements

Summary of Critical Accounting Estimates

Recent Accounting Standards

Overview of Business

Cheniere, a Delaware corporation, is a Houston-based energy infrastructure company primarily engaged in LNG-related businesses. ~~Our vision is to~~We provide clean, secure and affordable LNG to integrated energy companies, utilities and energy trading companies around the world. We aspire to ~~the world, while responsibly~~conduct our business in a safe and responsible manner, delivering a reliable, competitive and integrated source of LNG ~~in a safe and rewarding work environment.~~to our customers. We own and operate the Sabine Pass LNG terminal in Louisiana, one of the largest LNG production facilities in the world, through our ownership interest in and management agreements with Cheniere Partners, which is a publicly traded limited partnership that we created in 2007. As of ~~June 30, 2019,~~March 31, 2020, we owned 100% of the general partner interest and 48.6% of the limited partner interest in Cheniere Partners. We also own and operate the Corpus Christi LNG terminal in Texas, which is wholly owned by us. The liquefaction of natural gas into LNG allows it to be shipped economically from the United States where natural gas is abundant and inexpensive to produce to our international customers in areas where natural gas demand and infrastructure exist.

The Sabine Pass LNG terminal is located in Cameron Parish, Louisiana, on the Sabine-Neches Waterway less than four miles from the Gulf Coast. Cheniere Partners, through its subsidiary SPL, is ~~in various stages of constructing and~~currently operating ~~six~~five natural gas liquefaction ~~facilities~~Trains and is constructing one additional Train for a total production capacity of approximately 30 mtpa of LNG (the “SPL Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, SPL. Trains 1 through 5 are operational and Train 6 is under construction. Each Train is expected to have a nominal production capacity, which is prior to adjusting for planned maintenance, production reliability, potential overdesign and debottlenecking opportunities, of approximately 4.5 mtpa of LNG per Train.terminal. The Sabine Pass LNG terminal has operational regasification facilities owned by Cheniere Partners’ ~~wholly owned~~ subsidiary, SPLNG, that include pre-existing infrastructure of five LNG storage tanks with aggregate capacity of approximately ~~16.9~~17 Bcfe, two marine berths that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately ~~4.0~~4 Bcf/d. Cheniere Partners also owns a 94-mile pipeline through its subsidiary, CTPL, that interconnects the Sabine Pass LNG terminal with a number of large interstate ~~pipelines through a wholly owned subsidiary, CTPL.~~pipelines.

We also own ~~and operate a second natural gas liquefaction and export facility at~~ the Corpus Christi LNG terminal near Corpus Christi, Texas, and ~~operate~~are currently operating two Trains and are constructing one additional Train for a total production capacity of approximately 15 mtpa of LNG. Additionally, we are operating a 23-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 ~~liquefaction facilities,~~Trains, the “CCL Project”) through our ~~wholly owned~~ subsidiaries CCL and CCP, respectively. The CCL Project, ~~is being developed in stages with the first phase being three Trains (“Phase 1”),~~once fully constructed, will contain three LNG storage tanks with aggregate capacity of approximately ~~10.1~~10 Bcfe and two marine berths that can each accommodate vessels with nominal capacity of up to 266,000 cubic meters. The first stage (“Stage 1”) includes Trains 1 and 2, two LNG storage tanks, one complete marine berth and a second partial berth and all of the CCL Project’s necessary infrastructure facilities. The second stage (“Stage 2”) includes Train 3, one LNG storage tank and the completion of the second partial berth. Train 1 is operational, Train 2 is undergoing commissioning and Train 3 is under construction. Each Train is expected to have a nominal production capacity, which is prior to adjusting for planned maintenance, production reliability, potential overdesign and debottlenecking opportunities, of approximately 4.5 mtpa of LNG per Train.

We have contracted approximately 85% of the ~~expected aggregate nominal~~total production capacity from the SPL Project and the CCL Project (collectively, the “Liquefaction Projects”) on a ~~long-term~~term basis. This includes volumes contracted under SPAs in which the customers are required to pay a fixed fee with respect to the contracted volumes irrespective of their election to cancel or suspend deliveries of LNG cargoes, as well as volumes contracted under integrated production marketing (“IPM”) gas supply agreements.

Additionally, separate from the CCH Group, we are developing an expansion of the Corpus Christi LNG terminal adjacent to the CCL Project (“Corpus Christi Stage 3”) ~~and filed an application with FERC in June 2018~~through our subsidiary CCL Stage III for up to seven midscale Trains with an expected ~~aggregate nominal~~total production capacity of approximately ~~9.5~~10 mtpa of LNG. We received approval from FERC in November 2019 to site, construct and ~~one LNG storage tank.~~

~~We have made an equity investment in Midship Holdings, LLC (“Midship Holdings”), which manages~~operate the business and affairs of Midship Pipeline Company, LLC (“Midship Pipeline”). Midship Pipeline is constructing a pipeline (the “Midship Project”) with expected capacity of up to 1.44 million Dekatherms per day that will connect new gas production in the Anadarko Basin to Gulf Coast markets, including markets serving the Liquefaction Projects. Construction of the Midship Project commenced in the first quarter of 2019.expansion project.

Overview of Significant Events

Our significant ~~accomplishments~~events since January 1, ~~2019~~2020 and through the filing date of this Form 10-Q include the following:

Strategic

In June 2019, our board of directors (the “Board”) appointed Michele A. Evans to serve as a member of the Board. Ms. Evans was also appointed to the Audit Committee and the Governance and Nominating Committee of the Board.

In May 2019, our wholly owned subsidiary CCL Stage III entered into an integrated production marketing transaction with Apache Corporation to purchase 140,000 MMBtu per day of natural gas, for a term of approximately 15 years, at a price based on international LNG indices, net of a fixed liquefaction fee and certain costs incurred by Cheniere.

In May 2019, the board of directors of the general partner of Cheniere Partners made a positive FID with respect to Train 6 of the SPL Project and issued a full notice to proceed with construction to Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) in June 2019.

In March 2019, we received a positive Environmental Assessment from the FERC relating to Corpus Christi Stage 3 and anticipate receiving all remaining necessary regulatory approvals for the project by the end of 2019.

~~In February 2019,~~April 2020, Midship Pipeline Company, LLC, in which we ~~hold~~have an ~~indirect~~ equity ~~interest, issued full notice to proceed to construct~~investment, placed into service the Midship natural gas pipeline and related compression and interconnect ~~facilities following receipt of final Notice to Proceed from the FERC and obtaining financing to construct the Midship Project.~~facilities.

Operational

As of ~~July 31, 2019, over 750~~April 27, 2020, more than 1,100 cumulative LNG cargoes totaling over 75 million tonnes of LNG have been produced, loaded and exported from the Liquefaction Projects.

Financial

In ~~June 2019, first LNG production from Train 2~~March 2020, SPL entered into a $1.2 billion Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “2020 SPL Working Capital Facility”), which refinanced its previous working capital facility, reduced the ~~CCL Project occurred,~~interest rate and extended the ~~first commissioning cargo from Train 2 was exported.~~maturity date to March 2025.

In February ~~2019~~2020, the amended and ~~March 2019, CCL and SPL achieved substantial completion of Train 1 of the CCL Project and Train 5 of the SPL Project, respectively, and commenced operating activities.~~

~~Financial~~

In June 2019, we announced a capital allocation framework which prioritizes investments in the growth of our liquefaction platform, improvement of consolidated leverage metrics, and a return of excess capital to shareholders under a three-year, $1.0 billion share repurchase program.

~~In June 2019, the date of first commercial delivery was reached under the 20-year SPAs with Endesa S.A. and PT Pertamina (Persero) relating to Train 1 of the CCL Project.~~

~~In June 2019, CCH and its subsidiaries, as guarantors, entered into a~~restated note purchase agreement ~~(“CCH Note Purchase Agreement”) with Allianz Global Investors GmbH to issue an aggregate principal amount of $727 million of 4.80%~~for the 11.0% Convertible Senior Secured Notes due ~~2039~~2025 (the ~~“2039~~“2025 CCH HoldCo II Convertible Senior Notes”)~~, with closing and funding of~~ was amended to allow CCH HoldCo II the ~~2039 CCH Senior Notes conditional in part on the 2039 CCH Senior Notes receiving at least two investment grade ratings within 18 months of the date of the CCH Note Purchase Agreement.~~

In May 2019, Cheniere Partners entered into five-year, $1.5 billion credit facilities (the “2019 CQP Credit Facilities”), which consist of a $750 million delayed draw term loan (“CQP Term Facility”) and a $750 million revolving credit facility (“CQP Revolving Facility”),option to ~~fund~~redeem all or a portion of the ~~development and construction~~outstanding notes with cash at a price of ~~Train 6, a third LNG berth and supporting infrastructure~~$1,080 per $1,000 principal amount, at the ~~SPL Project.~~time of any CCH HoldCo II- or noteholder-initiated conversion through September 2, 2020. In March 2020, CCH HoldCo II redeemed an aggregate outstanding principal amount of $300 million with cash.

Impact of COVID-19 and Market Environment

The business environment in which we operate has been impacted by the recent downturn in the energy market as well as the outbreak of COVID-19 and its progression into a pandemic in March 2020. As a result of these developments, our growth estimates for LNG in 2020 have moderated from previous expectations. Annual LNG demand grew by 13% in 2019 to approximately 360 mtpa. In a report published in the month of April 2020, IHS Markit projected LNG demand in 2020 to reach 363 mtpa, down from a pre-COVID-19 estimate of approximately 377 mtpa. This implies a year-over-year rate of growth of approximately 0.8% in 2020 compared to the implied 4.7% pre-COVID-19 year-over-year growth estimate. While worldwide demand increased by approximately 10% during the three months ended March 31, 2020 compared to the comparable period of 2019, we expect to potentially see year-over-year declines in some future quarters as reduced economic activity affects LNG demand and high storage inventory levels reduce the need for imports. The robust LNG supply additions over the past several years, along with warmer winters and now strict virus containment measures, have exerted downward pressure on global gas prices. As an example, the Dutch Title Transfer Facility (“TTF”), a virtual trading point for natural gas in the Netherlands, averaged $3.35 during the quarter ended March 31, 2020, 51% lower than the comparable period of 2019, while the Japan Korean Marker (“JKM”), an LNG benchmark price assessment for spot physical cargoes delivered ex-ship into certain key markets in Asia, averaged $4.82 during the three months ended March 31, 2020, 43% lower than the comparable period of 2019. As a result of the weaker LNG market environment,

as well as customer-specific variables, we have recently experienced an increase in the number of LNG cargoes for which our customers have notified us they will not take delivery. While this may impact our expected LNG production, we do not expect it to have a material impact on our forecasted financial results for 2020, due to the highly contracted nature of our business and the fact that customers continue to be obligated to pay fixed fees for cargoes in relation to which they have exercised their contractual right to cancel. Revenue associated with canceled LNG cargoes is generally recognized upon notice of customer cancellation. During the three months ended March 31, 2020, we recognized revenue of approximately $53 million associated with canceled LNG cargoes.

In addition, in response to the COVID-19 pandemic, we have modified certain business and workforce practices to protect the safety and welfare of our employees who continue to work at our facilities and offices worldwide, as well as implemented certain mitigation efforts to ensure business continuity. In March ~~2019,~~2020, we began consulting with a medical advisor, and implemented social distancing through revised shift schedules, work from home policies and designated remote work locations where appropriate, restricted non-essential business travel and began requiring self-screening for employees and contractors. In April 2020, we began utilizing temporary on-site housing for our workforce at our facilities, implemented temperature testing, incorporated medical and social workers to support employees, enforced prior self-isolation and screening for on-site housing and implemented marine operations with zero contact during loading activities. These measures have resulted in increased costs, which we expect to continue until the ~~date~~risks associated with the COVID-19 pandemic diminish. As of ~~first commercial delivery was reached under the 20-year SPA with BG Gulf Coast LNG, LLC relating to Train 4~~April 28, 2020, we have incurred approximately $30 million of ~~the SPL Project.~~such costs.

Liquidity and Capital Resources

Although results are consolidated for financial reporting, Cheniere, Cheniere Partners, SPL and the CCH Group operate with independent capital structures. Our capital requirements include capital and investment expenditures, repayment of long-term debt and repurchase of our shares. We expect the cash needs for at least the next twelve months will be met for each of these independent capital structures as follows:

SPL through project debt and borrowings, operating cash flows and equity contributions from Cheniere Partners;

Cheniere Partners through operating cash flows from SPLNG, SPL and CTPL and debt or equity offerings;

CCH Group through operating cash flows from CCL and CCP, project debt and borrowings and equity contributions from Cheniere; and

Cheniere through ~~project financing,~~ existing unrestricted cash, debt and equity offerings by us or our subsidiaries, operating cash flows, borrowings, services fees from our subsidiaries and distributions from our investment in Cheniere Partners.

The following table provides a summary of our liquidity position at ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Cash and cash equivalents(1)	$	2,279	$	981	$	2,399	$	2,474
Restricted cash designated for the following purposes:
SPL Project	596		756		109		181
Cheniere Partners and cash held by guarantor subsidiaries	—		785
CCL Project	279		289		94		80
Other	286		345		227		259
Available commitments under the following credit facilities:
$1.2 billion SPL Working Capital Facility (“SPL Working Capital Facility”)	785		775
$1.5 billion 2019 CQP Credit Facilities	851		—
$2.8 billion Cheniere Partners’ Credit Facilities (“2016 CQP Credit Facilities”)	—		115
Amended and restated CCH Credit Facility (“CCH Credit Facility”)	—		982
$1.2 billion Amended and Restated SPL Working Capital Facility (“2015 SPL Working Capital Facility”)					—		786
2020 SPL Working Capital Facility					786		—
CQP Credit Facilities executed in 2019 (“2019 CQP Credit Facilities”)					750		750
$1.2 billion CCH Working Capital Facility (“CCH Working Capital Facility”)	862		716		660		729
$1.25 billion Cheniere Revolving Credit Facility (“Cheniere Revolving Credit Facility”)	1,250		1,250		430		665

(1)

Amounts presented include balances held by our consolidated variable interest entity (“VIE”), Cheniere Partners as discussed in Note 8—Non-controlling Interest and Variable Interest Entity of our Notes to Consolidated Financial Statements. As of March 31, 2020 and December 31, 2019, assets of Cheniere Partners, which are included in our Consolidated Balance Sheets, included $1.7 billion and $1.8 billion, respectively, of cash and cash equivalents.

For additional information regarding our debt agreements, see Note 10—Debt of our Notes to Consolidated Financial Statements in this quarterly report and Note ~~12—~~11—Debt of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019.

~~Cheniere~~

~~Convertible Notes~~

In November 2014, we issued an aggregate principal amount of $1.0 billion of Convertible Unsecured Notes due 2021 (the “2021 Cheniere Convertible Unsecured Notes”). The 2021 Cheniere Convertible Unsecured Notes are convertible at the option of the holder into our common stock at the then applicable conversion rate, provided that the closing price of our common stock is greater than or equal to the conversion price on the date of conversion. In March 2015, we issued $625 million aggregate

principal amount of 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”). We have the right, at our option, at any time after March 15, 2020, to redeem all or any part of the 2045 Cheniere Convertible Senior Notes at a redemption price equal to the accreted amount of the 2045 Cheniere Convertible Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to such redemption date. We have the option to satisfy the conversion obligation for the 2021 Cheniere Convertible Unsecured Notes and the 2045 Cheniere Convertible Senior Notes with cash, common stock or a combination thereof.

~~Cheniere Revolving Credit Facility~~

In December 2018, we amended and restated the Cheniere Revolving Credit Facility to increase total commitments under the Cheniere Revolving Credit Facility from $750 million to $1.25 billion. The Cheniere Revolving Credit Facility is intended to fund, through loans and letters of credit, equity capital contributions to CCH HoldCo II and its subsidiaries for the development of the CCL Project and, provided that certain conditions are met, for general corporate purposes.

The Cheniere Revolving Credit Facility matures on December 13, 2022 and contains representations, warranties and affirmative and negative covenants customary for companies like us with lenders of the type participating in the Cheniere Revolving Credit Facility that limit our ability to make restricted payments, including distributions, unless certain conditions are satisfied, as well as limitations on indebtedness, guarantees, hedging, liens, investments and affiliate transactions. Under the Cheniere Revolving Credit Facility, we are required to ensure that the sum of our unrestricted cash and the amount of undrawn commitments under the Cheniere Revolving Credit Facility is at least equal to the lesser of (1) 20% of the commitments under the Cheniere Revolving Credit Facility and (2) $200 million (the “Liquidity Covenant”).

From and after the time at which certain specified conditions are met (the “Trigger Point”), we will have increased flexibility under the Cheniere Revolving Credit Facility to, among other things, (1) make restricted payments and (2) raise incremental commitments. The Trigger Point will occur once (1) completion has occurred for each of Train 1 of the CCL Project (as defined in the CCH Indenture) and Train 5 of the SPL Project (as defined in SPL’s common terms agreement), which has occurred in February 2019 and March 2019, respectively; (2) the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit under the Cheniere Revolving Credit Facility is less than or equal to 10% of aggregate commitments under the Cheniere Revolving Credit Facility and (3) we elect on a go-forward basis to be governed by a non-consolidated leverage ratio covenant not to exceed 5.75:1.00 (the “Springing Leverage Covenant”), which following such election will apply at any time that the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit under the Cheniere Revolving Credit Facility is greater than 30% of aggregate commitments under the Cheniere Revolving Credit Facility. Following the Trigger Point, at any time that the Springing Leverage Covenant is in effect, the Liquidity Covenant will not apply.

The Cheniere Revolving Credit Facility is secured by a first priority security interest (subject to permitted liens and other customary exceptions) in substantially all of our assets, including our interests in our direct subsidiaries (excluding CCH HoldCo II and certain other subsidiaries).

~~Cash Receipts from Subsidiaries~~

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. As of June 30, 2019, we owned a 48.6% limited partner interest in Cheniere Partners in the form of 104.5 million common units and 135.4 million subordinated units. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. We are eligible to receive quarterly equity distributions from Cheniere Partners related to our ownership interests and our incentive distribution rights.

We also receive fees for providing management services to some of our subsidiaries. We received $36 million and $38 million in total service fees from these subsidiaries during each of the six months ended June 30, 2019 and 2018, respectively.

~~Share Repurchase Authorization~~

On June 3, 2019, we announced that our Board authorized a 3-year, $1.0 billion share repurchase program. During the three months ended June 30, 2019, we repurchased an aggregate of 44,600 shares of our common stock for $3 million, for a weighted average price per share of $68.30. As of June 30, 2019, we had $997 million of the share repurchase authorization available. Under the share repurchase program, repurchases can be made from time to time using a variety of methods, which may include open market purchases, privately negotiated transactions or otherwise, all in accordance with the rules of the SEC and other

applicable legal requirements. The timing and amount of any shares of our common stock that are repurchased under the share repurchase program will be determined by our management based on market conditions and other factors.

~~Cheniere Partners~~

~~CQP Senior Notes~~

The $1.5 billion of 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”) and $1.1 billion of 5.625% Senior Notes due 2026 (the “2026 CQP Senior Notes”) (collectively, the “CQP Senior Notes”) are jointly and severally guaranteed by each of Cheniere Partners’ subsidiaries other than SPL (the “CQP Guarantors”) and, subject to certain conditions governing its guarantee, Sabine Pass LP. The CQP Senior Notes are governed by the same base indenture (the “CQP Base Indenture”). The 2025 CQP Senior Notes are further governed by the First Supplemental Indenture (together with the CQP Base Indenture, the “2025 CQP Notes Indenture”) and the 2026 CQP Senior Notes are further governed by the Second Supplemental Indenture (together with the CQP Base Indenture, the “2026 CQP Notes Indenture”). The 2025 CQP Notes Indenture and the 2026 CQP Notes Indenture contain customary terms and events of default and certain covenants that, among other things, limit the ability of Cheniere Partners and the CQP Guarantors to incur liens and sell assets, enter into transactions with affiliates, enter into sale-leaseback transactions and consolidate, merge or sell, lease or otherwise dispose of all or substantially all of the applicable entity’s properties or assets.

At any time prior to October 1, 2020 for the 2025 CQP Senior Notes and October 1, 2021 for the 2026 CQP Senior Notes, Cheniere Partners may redeem all or a part of the applicable CQP Senior Notes at a redemption price equal to 100% of the aggregate principal amount of the CQP Senior Notes redeemed, plus the “applicable premium” set forth in the respective indentures governing the CQP Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. In addition, at any time prior to October 1, 2020 for the 2025 CQP Senior Notes and October 1, 2021 for the 2026 CQP Senior Notes, Cheniere Partners may redeem up to 35% of the aggregate principal amount of the CQP Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 105.250% of the aggregate principal amount of the 2025 CQP Senior Notes and 105.625% of the aggregate principal amount of the 2026 CQP Senior Notes redeemed, plus accrued and unpaid interest, if any, to the date of redemption. Cheniere Partners also may at any time on or after October 1, 2020 through the maturity date of October 1, 2025 for the 2025 CQP Senior Notes and October 1, 2021 through the maturity date of October 1, 2026 for the 2026 CQP Senior Notes, redeem the CQP Senior Notes, in whole or in part, at the redemption prices set forth in the respective indentures governing the CQP Senior Notes.

The CQP Senior Notes are Cheniere Partners’ senior obligations, ranking equally in right of payment with Cheniere Partners’ other existing and future unsubordinated debt and senior to any of its future subordinated debt. After applying the proceeds from the 2026 CQP Senior Notes, the CQP Senior Notes became unsecured. In the event that the aggregate amount of Cheniere Partners’ secured indebtedness and the secured indebtedness of the CQP Guarantors (other than the CQP Senior Notes or any other series of notes issued under the CQP Base Indenture) outstanding at any one time exceeds the greater of (1) $1.5 billion and (2) 10% of net tangible assets, the CQP Senior Notes will be secured to the same extent as such obligations under the 2019 CQP Credit Facilities. The obligations under the 2019 CQP Credit Facilities are secured on a first-priority basis (subject to permitted encumbrances) with liens on substantially all the existing and future tangible and intangible assets and rights of Cheniere Partners and the CQP Guarantors and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities). The liens securing the CQP Senior Notes, if applicable, will be shared equally and ratably (subject to permitted liens) with the holders of other senior secured obligations, which include the 2019 CQP Credit Facilities obligations and any future additional senior secured debt obligations.

~~2016 CQP Credit Facilities~~

~~In May 2019, the remaining commitments under the 2016 CQP Credit Facilities were terminated.~~

~~2019 CQP Credit Facilities~~

In May 2019, Cheniere Partners entered into the 2019 CQP Credit Facilities, which consist of a $750 million term loan (“CQP Term Facility”) and a $750 million revolving credit facility (“CQP Revolving Facility”). Borrowings under the 2019 CQP Credit Facilities will be used to fund the development and construction of Train 6 of the SPL Project and subject to a sublimit, for general corporate purposes. The CQP Revolving Facility is also available for the issuance of letters of credit.

Loans under the 2019 CQP Credit Facilities will accrue interest at a variable rate per annum equal to LIBOR or the base rate (equal to the highest of the prime rate, the federal funds effective rate, as published by the Federal Reserve Bank of New York, plus 0.50%, and the adjusted one-month LIBOR plus 1.0%), plus the applicable margin. Under the CQP Term Facility, the applicable margin for LIBOR loans is 1.50% per annum, and the applicable margin for base rate loans is 0.50% per annum, in each case with a 0.25% step-up beginning on May 29, 2022. Under the CQP Revolving Facility, the applicable margin for LIBOR loans is 1.25% to 2.125% per annum, and the applicable margin for base rate loans is 0.25% to 1.125% per annum, in each case depending on the then-current rating of Cheniere Partners. Interest on LIBOR loans is due and payable at the end of each applicable LIBOR period (and at the end of every three month period within the LIBOR period, if any), and interest on base rate loans is due and payable at the end of each calendar quarter.

~~Cheniere Partners pays a commitment fee equal to an annual rate of 30% of the margin for LIBOR loans multiplied by the average daily amount of the undrawn commitment, payable quarterly in arrears.~~

The 2019 CQP Credit Facilities mature on May 29, 2024. The principal of any loans under the 2019 CQP Credit Facilities must be repaid in quarterly installments commencing on May 29, 2023 based on an amortization schedule. Any outstanding balance may be repaid, in whole or in part, at any time without premium or penalty, except for interest hedging and interest rate breakage costs. The 2019 CQP Credit Facilities contain conditions precedent for extensions of credit, as well as customary affirmative and negative covenants, and limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions are satisfied.

The 2019 CQP Credit Facilities are unconditionally guaranteed by each subsidiary of Cheniere Partners other than SPL, Sabine Pass LNG-LP, LLC and certain subsidiaries of Cheniere Partners owning other development projects, as well as certain other specified subsidiaries and members of the foregoing entities.

Sabine Pass LNG Terminal

Liquefaction Facilities

WeThe SPL Project is one of the largest LNG production facilities in the world. Through Cheniere Partners, we are ~~in various stages of constructing~~currently operating five Trains and ~~operating~~two marine berths at the SPL Project ~~at the Sabine Pass LNG terminal adjacent to the existing regasification facilities.~~and are constructing one additional Train. We have received authorization from the FERC to site, construct and operate Trains 1 through 6.6, as well as for the construction of a third marine berth. We have achieved substantial completion of the first five Trains ~~1, 2, 3, 4 and 5~~ of the SPL Project and commenced commercial operating activities for each Train at various times starting in May ~~2016, September 2016, March 2017, October 2017 and March 2019, respectively.~~2016. The following table summarizes the project completion and construction status of Train 6 of the SPL Project as of ~~June 30, 2019:~~March 31, 2020:



		SPL Train 6
Overall project completion percentage		~~32.4%~~53.9%
Completion percentage of:
Engineering		~~74.1%~~93.8%
Procurement		~~48.2%~~78.4%
Subcontract work		~~30.7%~~39.5%
Construction		~~2.1%~~15.0%
Date of expected substantial completion		1H 2023

The following orders have been issued by the DOE authorizing the export of domestically produced LNG by vessel from the Sabine Pass LNG terminal:

Trains 1 through 4—FTA countries for a 30-year term, which commenced onin May ~~15,~~ 2016, and non-FTA countries for a 20-year term, which commenced onin June 3, 2016, in an amount up to a combined total of the equivalent of 16 mtpa (approximately 803 Bcf/yr of natural gas).

Trains 1 through 4—FTA countries for a 25-year term and non-FTA countries for a 20-year term, both of which commenced in December 2018, in an amount up to a combined total of the equivalent of approximately 203 Bcf/yr of natural gas (approximately 4 mtpa).

Trains 5 and 6—FTA countries and non-FTA countries for a 20-year term, which partially commenced in June 2019 and the remainder commenced in September 2019, in an amount up to a combined total of 503.3 Bcf/yr of natural gas (approximately 10 mtpa).

In each case, the terms of these authorizations ~~begin~~began on the earlier of the date of first export thereunder or the date specified in the particular ~~order, which ranges from five to 10 years from the date the order was issued.~~order. In addition, SPL received an order

providing for a three-year makeup period with respect to each of the non-FTA orders for LNG volumes SPL was authorized but unable to export during any portion of the initial 20-year export period of such order.

~~In January 2018, the~~The DOE issued ~~orders~~an order authorizing SPL to export domestically produced LNG by vessel from the Sabine Pass LNG terminal to FTA countries and non-FTA countries over a two-year period commencing January ~~2018,~~2020, in an aggregate amount up to the equivalent of 600 Bcf of natural gas (however, exports under this order, when combined with exports under the orders above, may not exceed 1,509 Bcf/yr).

An application was filed in September 2019 seeking authorization to make additional exports from the SPL Project to FTA countries for a 25-year term and to non-FTA countries for a 20-year term in an amount up to the equivalent of approximately 153 Bcf/yr of natural gas, for a total SPL Project export capacity of approximately 1,662 Bcf/yr. The terms of the authorizations are requested to commence on the date of first commercial export from the SPL Project of the volumes contemplated in the application. In April 2020, the DOE issued an order authorizing SPL to export to FTA countries related to this application, but has not yet issued an order authorizing SPL to export to non-FTA countries for the corresponding LNG volume. A corresponding application for authorization to increase the total LNG production capacity of the SPL Project from the currently authorized level to approximately 1,662 Bcf/yr was also submitted to the FERC and is currently pending.

Customers

SPL has entered into fixed price long-term SPAs generally with terms of ~~at least~~ 20 years (plus extension rights) with eight third parties for Trains 1 through 6 of the SPL ~~Project, including an agreement anticipated to be assigned from Cheniere Marketing.~~Project. Under these SPAs, the customers will purchase LNG from SPL on a free on board (“FOB”) basis for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG generally equal to approximately 115% of Henry Hub. ~~In certain circumstances, the~~The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under SPL’s SPAs. We refer to the fee component that is applicable only in connection with LNG cargo deliveries as the variable fee component of the price under SPL’s SPAs. The variable fees under SPL’s SPAs were generally sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation ~~related to,~~ and ~~operating and maintenance costs~~liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery of a specified Train.

In aggregate, the annual fixed fee portion to be paid by the third-party SPA customers is approximately ~~$2.3~~$2.9 billion for Trains 1 through ~~4 and increasing~~5. After giving effect to ~~$2.9~~an SPA that Cheniere has committed to provide to SPL by the end of 2020, the annual fixed fee portion to be paid by the third-party SPA customers would increase to at least $3.3 billion, which is expected to occur upon the date of first commercial delivery of Train 5,6.

In addition, Cheniere Marketing has agreements with ~~the applicable fixed fees starting from the date~~SPL to purchase, at Cheniere Marketing’s option, any LNG produced by SPL in excess of ~~first commercial delivery from the applicable Train, as specified in each SPA.~~that required for other customers. See Marketing section for additional information regarding agreements entered into by Cheniere Marketing.

Natural Gas Transportation, Storage and Supply

To ensure SPL is able to transport adequate natural gas feedstock to the Sabine Pass LNG terminal, it has entered into transportation precedent and other agreements to secure firm pipeline transportation capacity with CTPL and third-party pipeline companies. SPL has entered into firm storage services agreements with third parties to assist in managing variability in natural gas needs for the SPL Project. SPL has also entered into enabling agreements and long-term natural gas supply contracts with third parties in order to secure natural gas feedstock for the SPL Project. As of ~~June 30, 2019,~~March 31, 2020, SPL had secured up to approximately ~~3,437~~5,300 TBtu of natural gas feedstock through long-term and short-term natural gas supply ~~contracts.~~

contracts with remaining terms that range up to 10 years, a portion of which is subject to conditions precedent.

Construction

SPL entered into lump sum turnkey contracts with Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) for the engineering, procurement and construction of Trains 1 through 6 of the SPL Project, under which Bechtel charges a lump sum for all work performed and generally bears project cost, ~~risk~~schedule and performance risks unless certain specified events occur, in which case Bechtel may cause SPL to enter into a change order, or SPL agrees with Bechtel to a change order.

The total contract price of the EPC contract for Train 6 of the SPL Project is approximately $2.5 billion, including estimated costs for an optional third marine berth.

As of March 31, 2020, we have incurred $1.3 billion under this contract.

Regasification Facilities

The Sabine Pass LNG terminal has operational regasification capacity of approximately ~~4.0~~4 Bcf/d and aggregate LNG storage capacity of approximately ~~16.9~~17 Bcfe. Approximately ~~2.0~~2 Bcf/d of the regasification capacity at the Sabine Pass LNG terminal has been reserved under two long-term third-party TUAs, under which SPLNG’s customers are required to pay fixed monthly fees, whether or not they use the LNG terminal. Each of Total ~~Gas & Power North America, Inc. (“Total”)~~ and Chevron U.S.A. Inc. (“Chevron”) has reserved approximately ~~1.0~~1 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually, prior to inflation adjustments, for 20 years that commenced

in 2009. Total S.A. has guaranteed Total’s obligations under its TUA up to $2.5 billion, subject to certain exceptions, and Chevron Corporation has guaranteed Chevron’s obligations under its TUA up to 80% of the fees payable by Chevron.

The remaining approximately ~~2.0~~2 Bcf/d of capacity has been reserved under a TUA by SPL. SPL is obligated to make monthly capacity payments to SPLNG aggregating approximately $250 million annually, prior to inflation adjustments, continuing until at least May 2036. SPL entered into a partial TUA assignment agreement with Total, whereby upon substantial completion of Train 5 of the SPL Project, SPL gained access to substantially all of Total’s capacity and other services provided under Total’s TUA with SPLNG. This agreement provides SPL with additional berthing and storage capacity at the Sabine Pass LNG terminal that may be used to provide increased flexibility in managing LNG cargo loading and unloading activity, permit SPL to more flexibly manage its LNG storage capacity and accommodate the development of Train 6. Notwithstanding any arrangements between Total and SPL, payments required to be made by Total to SPLNG will continue to be made by Total to SPLNG in accordance with its TUA. During the three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018,~~ SPL recorded $32 million and $7.5 ~~million, respectively, and during the six months ended June 30, 2019 and 2018, SPL recorded $40 million and $15~~ million, respectively, as operating and maintenance expense under this partial TUA assignment agreement.

Under each of these TUAs, SPLNG is entitled to retain 2% of the LNG delivered to the Sabine Pass LNG terminal.

Capital Resources

We currently expect that SPL’s capital resources requirements with respect to the SPL Project will be financed through project debt and borrowings, cash flows under the SPAs and equity contributions from Cheniere Partners. We believe that with the net proceeds of borrowings, available commitments under the 2020 SPL Working Capital Facility, 2019 CQP Credit Facilities, ~~and~~ cash flows from operations and equity contributions from Cheniere Partners, weSPL will have adequate financial resources available to meet ~~our~~its currently anticipated capital, operating and debt service requirements with respect to Trains 1 through 6 of the SPL Project. SPL began generating cash flows from operations from the SPL Project in May 2016, when Train 1 achieved substantial completion and initiated operating activities. Trains 2, 3, 4 and 5 subsequently achieved substantial completion in September 2016, March 2017, October 2017 and March 2019, respectively. We realized offsets to LNG terminal costs of $74 million in the six months ended June 30, 2019, respectively, that were related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of Train 5 of the SPL Project during the testing phase for its construction. We did not realize any offsets to LNG terminal costs in the three months ended June 30, 2019 and the three and six months ended June 30, 2018. Additionally, SPLNG generates cash flows from the TUAs, as discussed above.

The following table provides a summary of our capital resources from borrowings and available commitments for the Sabine Pass LNG Terminal, excluding equity contributions to our subsidiaries and cash flows from operations (as described in Sources and Uses of Cash), at ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Senior notes (1)	$	16,250	$	16,250	$	17,750	$	17,750
Credit facilities outstanding balance (2)	649		—		—		—
Letters of credit issued (3)	415		425		414		414
Available commitments under credit facilities (3)	1,636		775		1,536		1,536
Total capital resources from borrowings and available commitments (4)	$	18,950	$	17,450	$	19,700	$	19,700

(1)

Includes SPL’s 5.625% Senior Secured Notes due 2021, 6.25% Senior Secured Notes due 2022, 5.625% Senior Secured Notes due 2023, 5.75% Senior Secured Notes due 2024, 5.625% Senior Secured Notes due 2025, 5.875% Senior Secured Notes due 2026 (the “2026 SPL Senior Notes”), 5.00% Senior Secured Notes due 2027 (the “2027 SPL Senior Notes”), 4.200% Senior Secured Notes due 2028 (the “2028 SPL Senior Notes”) and 5.00% Senior Secured Notes due 2037 (the “2037 SPL Senior Notes”) (collectively, the “SPL Senior Notes”) ~~and Cheniere Partners’~~, as well as CQP’s $1.5 billion of 5.250% Senior Notes due 2025 (the “2025 CQP Senior Notes”), $1.1 billion of 5.625% Senior Notes ~~and~~due 2026 (the “2026 CQP Senior ~~Notes.~~Notes”) and the 4.500% Senior Notes due 2029 (the “2029 CQP Senior Notes”) (collectively, the “CQP Senior Notes”).


(2)	Includes outstanding balances under the 2015 SPL Working Capital Facility, 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities, inclusive of any portion of the 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities that may be used for general corporate purposes.


(3)	Consists of 2015 SPL Working Capital Facility, 2020 SPL Working Capital Facility and 2019 CQP Credit Facilities. Balance at December 31, 2018 did not include the letters of credit issued or available commitments under the terminated 2016 CQP Credit Facilities, which were not specifically for the Sabine Pass LNG Terminal.


(4)	Does not include equity contributions that may be available from Cheniere’s ~~additional~~ borrowings ~~from the 2021 Cheniere Convertible Unsecured Notes and the 2045 Cheniere Convertible Senior Notes,~~under its convertible notes, which may be used for the Sabine Pass LNG Terminal.

For additional information regarding our debt agreements related to the Sabine Pass LNG Terminal, see Note 10—Debt of our Notes to Consolidated Financial Statements in this quarterly report and Note ~~12—~~11—Debt of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, ~~2018.~~2019.

SPL Senior Notes

The SPL Senior Notes are secured on a pari passu first-priority basis by a security interest in all of the membership interests in SPL and substantially all of SPL’s assets.

At any time prior to three months before the respective dates of maturity for each series of the SPL Senior Notes (except for the 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes and 2037 SPL Senior Notes, in which case the time period is six months before the respective dates of maturity), SPL may redeem all or part of such series of the SPL Senior Notes at a redemption price equal to the “make-whole” price (except for the 2037 SPL Senior Notes, in which case the redemption price is equal to the “optional redemption” price) set forth in the respective indentures governing the SPL Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. SPL may also, at any time within three months of the respective maturity dates for each series of the SPL Senior Notes (except for the 2026 SPL Senior Notes, 2027 SPL Senior Notes, 2028 SPL Senior Notes and 2037 SPL Senior Notes, in which case the time period is within six months of the respective dates of maturity), redeem all or part of such series of the SPL Senior Notes at a redemption price equal to 100% of the principal amount of such series of the SPL Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

Both the indenture governing the 2037 SPL Senior Notes (the “2037 SPL Senior Notes Indenture”) and the common indenture governing the remainder of the SPL Senior Notes (the “SPL Indenture”) include restrictive covenants. SPL may incur additional indebtedness in the future, including by issuing additional notes, and such indebtedness could be at higher interest rates and have different maturity dates and more restrictive covenants than the current outstanding indebtedness of SPL, including the SPL Senior Notes and the 2020 SPL Working Capital Facility. Under the 2037 SPL Senior Notes Indenture and the SPL Indenture, SPL may not make any distributions until, among other requirements, deposits are made into debt service reserve accounts as required and a debt service coverage ratio test of 1.25:1.00 is satisfied. Semi-annual principal payments for the 2037 SPL Senior Notes are due on March 15 and September 15 of each year beginning September 15, ~~2025.~~

2025 and are fully amortizing according to a fixed sculpted amortization schedule.

2015 SPL Working Capital Facility

In ~~September~~March 2020, SPL terminated the remaining commitments under the 2015 SPL Working Capital Facility. As of December 31, 2019, SPL had $786 million of available commitments, $414 million aggregate amount of issued letters of credit and no outstanding borrowings under the 2015 SPL Working Capital Facility.

2020 SPL Working Capital Facility

In March 2020, SPL entered into the 2020 SPL Working Capital Facility with aggregate commitments of $1.2 billion, which replaced the 2015 SPL Working Capital Facility. The 2020 SPL Working Capital Facility is intended to be used for loans to SPL, (“swing line loans to SPL ~~Working Capital Loans”),~~and the issuance of letters of credit on behalf of SPL, ~~as well as for swing line loans to SPL (“SPL Swing Line Loans”),~~ primarily for ~~certain working capital requirements~~(1) the refinancing of the 2015 SPL Working Capital Facility, (2) fees and expenses related to ~~developing~~the 2020 SPL Working Capital Facility, (3) SPL’s gas purchase obligations and ~~placing into operation the~~(4) SPL ~~Project.~~and certain of its future subsidiaries’ general corporate purposes. SPL may, from time to time, request increases in the commitments under the 2020 SPL Working Capital Facility of up to ~~$760 million and, upon the completion of the debt financing of Train 6 of the SPL Project, request an incremental increase in commitments of up to an additional $390~~$800 million. As of ~~June 30, 2019 and December~~March 31, ~~2018,~~2020, SPL had ~~$785 million and $775~~$786 million of available commitments, ~~and $415 million and $425~~$414 million aggregate amount of issued letters of credit and no outstanding borrowings under the 2020 SPL Working Capital ~~Facility, respectively. SPL did not have any amounts outstanding under the SPL Working Capital Facility as of both June 30, 2019 and December 31, 2018.~~

Facility.

The 2020 SPL Working Capital Facility matures on ~~December~~March 19, 2025, but may be extended with consent of the lenders. The 2020 SPL Working Capital Facility provides for mandatory prepayments under customary circumstances.

The 2020 SPL Working Capital Facility contains customary conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. SPL is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, satisfaction of a 12-month forward-looking and backward-looking 1.25:1.00 debt service reserve ratio test. The obligations of SPL under the 2020 SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as a pledge of all of the membership interests in SPL and certain future subsidiaries of SPL on a pari passu basis by a first priority lien with the SPL Senior Notes.

Cheniere Partners

CQP Senior Notes

The CQP Senior Notes are jointly and severally guaranteed by each of Cheniere Partners’ subsidiaries other than SPL and, subject to certain conditions governing its guarantee, Sabine Pass LP (the “CQP Guarantors”). The CQP Senior Notes are governed by the same base indenture (the “CQP Base Indenture”). The 2025 CQP Senior Notes are further governed by the First Supplemental Indenture, the 2026 CQP Senior Notes are further governed by the Second Supplemental Indenture and the 2029 CQP Senior Notes are further governed by the Third Supplemental Indenture. The indentures governing the CQP Senior Notes contain customary terms and events of default and certain covenants that, among other things, limit the ability of Cheniere Partners and the CQP Guarantors to incur liens and sell assets, enter into transactions with affiliates, enter into sale-leaseback transactions and consolidate, merge or sell, lease or otherwise dispose of all or substantially all of the applicable entity’s properties or assets.

At any time prior to October 1, 2020 for the 2025 CQP Senior Notes, October 1, 2021 for the 2026 CQP Senior Notes and October 1, 2024 for the 2029 CQP Senior Notes, Cheniere Partners may redeem all or a part of the applicable CQP Senior Notes at a redemption price equal to 100% of the aggregate principal amount of the CQP Senior Notes redeemed, plus the “applicable premium” set forth in the respective indentures governing the CQP Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. In addition, at any time prior to October 1, 2020 for the 2025 CQP Senior Notes, October 1, 2021 for the 2026 CQP Senior Notes and October 1, 2024 for the 2029 CQP Senior Notes, Cheniere Partners may redeem up to 35% of the aggregate principal amount of the CQP Senior Notes with an amount of cash not greater than the net cash proceeds from certain equity offerings at a redemption price equal to 105.250% of the aggregate principal amount of the 2025 CQP Senior Notes, 105.625% of the aggregate principal amount of the 2026 CQP Senior Notes and 104.5% of the aggregate principal amount of the 2029 CQP Senior Notes redeemed, plus accrued and unpaid interest, if any, to the date of redemption. Cheniere Partners also may at any time on or after October 1, 2020 through the maturity date of October 1, 2025 for the 2025 CQP Senior Notes, October 1, 2021 through the maturity date of October 1, 2026 for the 2026 CQP Senior Notes and October 1, 2024 through the maturity date of October 1, 2029 for the 2029 CQP Senior Notes, redeem the CQP Senior Notes, in whole or in part, at the redemption prices set forth in the respective indentures governing the CQP Senior Notes.

The CQP Senior Notes are Cheniere Partners’ senior obligations, ranking equally in right of payment with Cheniere Partners’ other existing and future unsubordinated debt and senior to any of its future subordinated debt. In the event that the aggregate amount of Cheniere Partners’ secured indebtedness and the secured indebtedness of the CQP Guarantors (other than the CQP Senior Notes or any other series of notes issued under the CQP Base Indenture) outstanding at any one time exceeds the greater of (1) $1.5 billion and (2) 10% of net tangible assets, the CQP Senior Notes will be secured to the same extent as such obligations under the 2019 CQP Credit Facilities. The obligations under the 2019 CQP Credit Facilities are secured on a first-priority basis (subject to permitted encumbrances) with liens on substantially all the existing and future tangible and intangible assets and rights of Cheniere Partners and the CQP Guarantors and equity interests in the CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities). The liens securing the CQP Senior Notes, if applicable, will be shared equally and ratably (subject to permitted liens) with the holders of other senior secured obligations, which include the 2019 CQP Credit Facilities obligations and any future additional senior secured debt obligations.

2019 CQP Credit Facilities

In May 2019, Cheniere Partners entered into the 2019 CQP Credit Facilities, which consisted of the $750 million term loan (“CQP Term Facility”), which was prepaid and terminated upon issuance of the 2029 CQP Senior Notes in September 2019, and the $750 million revolving credit facility (“CQP Revolving Facility”). Borrowings under the 2019 CQP Credit Facilities will be used to fund the development and construction of Train 6 of the SPL Project and for general corporate purposes, subject to a sublimit, and the 2019 CQP Credit Facilities are also available for the issuance of letters of credit. As of both March 31, 2020 and December 31, 2019, CQP had $750 million of available commitments and no letters of credit issued or loans outstanding under the 2019 CQP Credit Facilities.

The 2019 CQP Credit Facilities mature on May 29, 2024. Any outstanding balance may be repaid, in whole or in part, at any time without premium or penalty, upon three business days’ notice. Loans deemed made in connection with a draw upon a letter of credit have a term of up to one year. SPL Swing Line Loans terminate upon the earliest of (1) the maturity date or earlier termination of the SPL Working Capital Facility, (2) the date 15 days after such SPL Swing Line Loan is made and (3) the first borrowing dateexcept for a SPL Working Capital Loan or SPL Swing Line Loan occurring at least three business days following the date the SPL Swing Line Loan is made. SPL is required to reduce the aggregate outstanding principal amount of all SPL Working Capital Loans to zero for a period of five consecutive business days at least once each year.

interest rate breakage costs. The ~~SPL Working Capital Facility contains~~2019 CQP Credit Facilities contain conditions precedent for extensions of credit, as well as customary affirmative and negative ~~covenants.~~ covenants, and limit Cheniere Partners’ ability to make restricted payments, including distributions, to once per fiscal quarter and one true-up per fiscal quarter as long as certain conditions are satisfied.

The ~~obligations of SPL under the SPL Working Capital Facility~~2019 CQP Credit Facilities are unconditionally guaranteed and secured by a first priority lien (subject to permitted encumbrances) on substantially all of Cheniere Partners’ and the CQP Guarantors’ existing and future tangible and intangible assets ~~of SPL as well as all of the membership~~and rights and equity interests in ~~SPL on a~~ ~~pari passu~~ ~~basis with~~ the ~~SPL Senior Notes.~~CQP Guarantors (except, in each case, for certain excluded properties set forth in the 2019 CQP Credit Facilities).

Corpus Christi LNG Terminal

Liquefaction Facilities

We are ~~in various stages of constructing~~currently operating two Trains and ~~operating~~one marine berth at the CCL Project ~~at the Corpus Christi LNG terminal.~~and are constructing one additional Train and marine berth. We have received authorization from the FERC to site, construct and operate ~~Stages~~Trains 1 through 3 of the CCL Project. We completed construction of Trains 1 and 2 of the CCL ~~Project. We achieved substantial completion of Train 1 of the CCL~~ Project and commenced commercial operating activities in February ~~2019.~~2019 and August 2019, respectively. The following table summarizes the ~~overall~~ project completion and construction status of Train 3 of the CCL Project, including the related infrastructure, as of ~~June 30, 2019:~~March 31, 2020:

CCL Stage 1 CCL Stage 2
Overall project completion percentage 99.5% 62.4%
Completion percentage of:
Engineering 100% 94.3%
Procurement 100% 92.5%
Subcontract work 96.4% 12.2%
Construction 99.2% 29.2%
Expected date of substantial completion Train 2 3Q 2019 Train 3 2H 2021



		CCL Train 3
Overall project completion percentage		83.7%
Completion percentage of:
Engineering		99.2%
Procurement		99.6%
Subcontract work		69.5%
Construction		63.0%
Expected date of substantial completion		1H 2021

Separate from the CCH Group, we are also developing Corpus Christi Stage 3 through our subsidiary CCL Stage III, adjacent to the CCL Project. We ~~filed an application with the~~received approval from FERC in ~~June 2018 for~~November 2019 to site, construct and operate seven midscale Trains with an expected ~~aggregate nominal~~total production capacity of approximately ~~9.5~~10 mtpa ~~and one LNG storage tank.~~of LNG.

The following orders have been issued by the DOE authorizing the export of domestically produced LNG by vessel from the Corpus Christi LNG terminal:

CCL Project—FTA countries for a 25-year term and to non-FTA countries for a 20-year term, both of which commenced in June 2019, up to a combined total of the equivalent of 767 Bcf/yr (approximately 15 mtpa) of natural gas.

Corpus Christi Stage 3—FTA countries for a 25-year term and to non-FTA countries for a 20-year term in an amount equivalent to ~~514~~582.14 Bcf/yr (approximately 1011 mtpa) of natural gas (the “Stage 3 FTA”). The application for authorization to export that same 514 Bcf/yr of domestically produced LNG by vessel to non-FTA countries is currently pending before the DOE (the “Stage 3 Non-FTA”).gas.

In each case, the terms of these authorizations begin on the earlier of the date of first export thereunder or the date specified in the particular order, which ranges from seven to 10 years from the date the order was issued.

~~In June 2018, we requested that DOE vacate~~An application was filed in September 2019 to authorize additional exports from the ~~Stage 3 FTA and permit us to withdraw the pending Stage 3 Non-FTA. These requests were made due to certain changes to Corpus Christi Stage 3.~~

In conjunction with the submission in June 2018 of our FERC application for Corpus Christi Stage 3, we submitted a new application for long-term multi-contract authorization to export up to a combined total of 582.14 Bcf/yr (approximately 11.45 mtpa) of natural gasCCL Project to FTA countries for a 25-year term and to non-FTA countries for a 20-year ~~term.~~term in an amount up to the equivalent of approximately 108 Bcf/yr of natural gas, for a total CCL Project export of 875.16 Bcf/yr. The ~~term~~terms of ~~each authorization is expected~~the authorizations are requested to ~~begin~~commence on ~~the earlier of~~ the date of first commercial export ~~of LNG produced by Corpus Christi Stage 3 or the date which is seven years~~ from the ~~issuance~~CCL Project of ~~such authorizations.~~the volumes contemplated in the application. The application is currently pending before DOE.

Customers

CCL has entered into fixed price long-term SPAs generally with terms of 20 years (plus extension rights) with nine third parties for Trains 1 through 3 of the CCL Project. Under these SPAs, the customers will purchase LNG from CCL on a FOB basis for a price consisting of a fixed fee per MMBtu of LNG (a portion of which is subject to annual adjustment for inflation) plus a variable fee per MMBtu of LNG equal to approximately 115% of Henry Hub. ~~In certain circumstances, the~~The customers may elect to cancel or suspend deliveries of LNG cargoes, with advance notice as governed by each respective SPA, in which case the customers would still be required to pay the fixed fee with respect to the contracted volumes that are not delivered as a result of such cancellation or suspension. We refer to the fee component that is applicable regardless of a cancellation or suspension of LNG cargo deliveries under the SPAs as the fixed fee component of the price under our SPAs. We refer to the fee component that is applicable only in connection with LNG cargo deliveries as the variable fee component of the price under our ~~SPAs~~.SPAs. The variable fee under CCL’s

SPAs entered into in connection with the development of the CCL Project was sized at the time of entry into each SPA with the intent to cover the costs of gas purchases and transportation ~~related to,~~ and ~~operating and maintenance costs~~liquefaction fuel to produce the LNG to be sold under each such SPA. The SPAs and contracted

volumes to be made available under the SPAs are not tied to a specific Train; however, the term of each SPA generally commences upon the date of first commercial delivery for the applicable Train, as specified in each SPA.

In aggregate, the minimum fixed fee portion to be paid by the third-party SPA customers is approximately $550 million for Train 1, increasing to approximately $1.4 billion upon the date of first commercial delivery for Train 2 and further increasing to approximately $1.8 billion following the substantial completion of Train 3 of the CCL Project.

In addition, Cheniere Marketing has ~~entered into SPAs~~agreements with CCL to ~~purchase~~purchase: (1) 15 TBtu per annum of LNG ~~and~~with an approximate term of 23 years, (2) any LNG produced by CCL in excess of that required for other customers at Cheniere Marketing’s ~~option.~~option and (3) 0.85 mtpa of LNG with a term of up to seven years associated with the IPM gas supply agreement between CCL and EOG. See Marketing section for additional information regarding agreements entered into by Cheniere Marketing.

Natural Gas Transportation, Storage and Supply

To ensure CCL is able to transport adequate natural gas feedstock to the Corpus Christi LNG terminal, it has entered into transportation precedent agreements to secure firm pipeline transportation capacity with CCP and certain third-party pipeline companies. CCL has entered into a firm storage services agreement with a third party to assist in managing variability in natural gas needs for the CCL Project. CCL has also entered into enabling agreements and long-term natural gas supply contracts with third parties, and will continue to enter into such agreements, in order to secure natural gas feedstock for the CCL Project. As of ~~June 30, 2019,~~March 31, 2020, CCL had secured up to approximately ~~2,787~~3,182 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to 10 years, a portion of which is subject to the achievement of certain project milestones and other conditions precedent.

CCL Stage III has also entered into long-term natural gas supply contracts with third parties, and anticipates continuing to enter into such agreements, in order to secure natural gas feedstock for Corpus Christi Stage 3. As of March 31, 2020, CCL Stage III had secured up to approximately 2,361 TBtu of natural gas feedstock through long-term natural gas supply contracts with remaining terms that range up to approximately 15 years, which is subject to the achievement of certain project milestones and other conditions precedent.

A portion of the natural gas feedstock transactions for CCL and CCL Stage III are IPM transactions, in which the natural gas producers are paid based on a global gas market price less a fixed liquefaction fee and certain costs incurred by us.

Construction

CCL entered into separate lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of ~~Stages~~Trains 1 ~~and 2~~through 3 of the CCL Project under which Bechtel charges a lump sum for all work performed and generally bears project cost, ~~risk~~schedule and performance risks unless certain specified events occur, in which case Bechtel may cause CCL to enter into a change order, or CCL agrees with Bechtel to a change order.

The total contract ~~prices~~price of the EPC contract for ~~Stage 1 and the EPC contract for Stage 2,~~Train 3, which ~~do not include the Corpus Christi Pipeline, are~~is currently under construction, is approximately ~~$7.8 billion and~~ $2.4 billion, ~~respectively,~~ reflecting amounts incurred under change orders through ~~June 30, 2019. Total expected capital costs~~March 31, 2020. As of March 31, 2020, we have incurred $2.1 billion under this contract.

Final Investment Decision for ~~Trains 1 through~~Corpus Christi Stage 3 are estimated to be between $11.0 billion and $12.0 billion before financing costs and between $15.0 billion and $16.0 billion after financing costs including, in each case, estimated owner’s costs and contingencies.

FID for Corpus Christi Stage 3 will be subject to, among other things, entering into an EPC contract, obtaining additional commercial support for the project and securing the necessary financing arrangements.

Pipeline Facilities

In ~~December 2014,~~November 2019, the FERC ~~issued a certificate of public convenience and necessity under Section 7(c) of the Natural Gas Act of 1938, as amended, authorizing~~authorized CCP to construct and operate the pipeline for Corpus Christi ~~Pipeline.~~Stage 3. The ~~Corpus Christi Pipeline is~~pipeline will be designed to transport ~~2.25~~1.5 Bcf/d of natural gas feedstock required by ~~the CCL Project~~Corpus Christi Stage 3 from the existing regional natural gas pipeline grid. ~~The construction of the Corpus Christi Pipeline was completed in the second quarter of 2018.~~

Capital Resources

The CCH Group expects to finance the construction costs of the CCL Project from one or more of the following: ~~project financing,~~ operating cash flows from CCL and CCP, project debt and equity contributions from Cheniere. We realized offsets to LNG terminal costs of $128 million in the six months ended June 30, 2019 that were related to the sale of commissioning cargoes because these amounts were earned or loaded prior to the start of commercial operations of Train 1 during the testing phase for its construction. We did not realize any offsets to LNG terminal costs in the three months ended June 30, 2019. The following table provides a summary of the capital resources of the CCH Group from borrowings and available commitments for the CCL Project, excluding equity contributions from Cheniere, at ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 (in millions):


	June 30,		December 31,		March 31,		December 31,
	2019		2018		2020		2019
Senior notes (1)	$	4,250	$	4,250	$	6,952	$	6,952
11.0% Convertible Senior Secured Notes due 2025 (2)	1,000		1,000		700		1,000
Credit facilities outstanding balance (3)	6,138		5,324		3,424		3,283
Letters of credit issued (3)	338		316		399		471
Available commitments under credit facilities (3)	862		1,698		660		729
Total capital resources from borrowings and available commitments (4)	$	12,588	$	12,588	$	12,135	$	12,435

(1)

Includes CCH’s 7.000% Senior Secured Notes due 2024 (the “2024 CCH Senior Notes”), 5.875% Senior Secured Notes due 2025 (the “2025 CCH Senior Notes”) ~~and~~, 5.125% Senior Secured Notes due 2027 (the “2027 CCH Senior Notes”), 3.700% Senior Secured Notes due 2029 (the "2029 CCH Senior Notes"), 4.80% Senior Secured Notes due 2039 (the “4.80% CCH Senior Notes”) and 3.925% Senior Secured Notes due 2039 (the "3.925% CCH Senior Notes") (collectively, the “CCH Senior Notes”).


(2)	Aggregate original principal amount before debt discount and debt issuance ~~costs.~~costs and interest paid-in-kind.


(3)	Includes CCH’s amended and restated credit facility (“CCH Credit ~~Facility~~Facility”) and CCH Working Capital Facility.


(4)	Does not include equity contributions that may be available from Cheniere’s ~~additional~~ borrowings ~~from~~under the 4.875% Convertible Unsecured Notes due 2021 (the “2021 Cheniere Convertible Unsecured Notes”), 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior ~~Notes~~Notes”) and Cheniere Revolving Credit Facility, which may be used for the CCL Project.

~~For additional information regarding our debt agreements related to the CCL Project, see~~ ~~Note 10—Debt~~ ~~of our Notes to Consolidated Financial Statements in this quarterly report and~~ ~~Note 12—Debt~~ ~~of our Notes to Consolidated Financial Statements in our annual report on Form 10-K for the year ended December 31, 2018.~~

2025 CCH HoldCo II Convertible Senior Notes

In May 2015, CCH HoldCo II issued $1.0 billion aggregate principal amount of ~~11.0% Convertible Senior Secured Notes due~~the 2025 ~~(the “2025~~ CCH HoldCo II Convertible Senior ~~Notes”)~~Notes on a private placement basis. The 2025 CCH HoldCo II Convertible Senior Notes are convertible at the option of CCH HoldCo II or the holders on or after March 1, 2020 and September 1, 2020, respectively, provided the total market capitalization of Cheniere at that ~~various~~time is not less than $10.0 billion and certain other conditions are ~~met.~~satisfied. CCH HoldCo II is restricted from making distributions to Cheniere under agreements governing its indebtedness generally until, among other requirements, ~~Trains 1 and 2 of the CCL Project are in commercial operation and~~ a historical debt service coverage ratio and a projected fixed debt service coverage ratio of 1.20:1.00 are achieved. The 2025 CCH HoldCo II Convertible Senior Notes are secured by a pledge by us of 100% of the equity interests in CCH HoldCo II, and a pledge by CCH HoldCo II of 100% of the equity interests in CCH HoldCo I. In addition, the 2025 CCH HoldCo II Convertible Senior Notes are secured by a security interest in the account into which all distributions from CCH HoldCo I to CCH HoldCo II must be deposited.

In May 2018, the amended and restated note purchase agreement under which the 2025 CCH HoldCo II Convertible Senior Notes were issued was subsequently amended in connection with commercialization and financing of Train 3 of the CCL Project and to provide the note holders with certain prepayment rights related thereto consistent with those under the CCH Credit Facility. All terms of the 2025 CCH HoldCo II Convertible Senior Notes substantially remained unchanged.

our common stock for the 90 trading day period preceding the date on which notice of requested conversion is provided. Conversions remain subject to various limitations and conditions.

CCH Senior Notes

The CCH Senior Notes are jointly and severally guaranteed by CCH’s subsidiaries, CCL, CCP and Corpus Christi Pipeline GP, LLC ~~(the~~(each a “CCH Guarantor” and collectively, the “CCH Guarantors”). The ~~indenture~~indentures governing the CCH Senior Notes ~~(the “CCH Indenture”) contains~~contain customary terms and events of default and certain covenants that, among other things, limit CCH’s ability and the ability of CCH’s restricted subsidiaries to: incur additional indebtedness or issue preferred stock; make certain investments or pay dividends or distributions on membership interests or subordinated indebtedness or purchase, redeem or retire membership interests; sell or transfer assets, including membership or partnership interests of CCH’s restricted subsidiaries; restrict dividends or other payments by restricted subsidiaries to CCH or any of CCH’s restricted subsidiaries; incur liens; enter into transactions with affiliates; dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of the properties or assets of CCH and its restricted subsidiaries taken as a

whole; or permit any CCH Guarantor to dissolve, liquidate, consolidate, merge, sell or lease all or substantially all of its properties and assets. The covenants included in the respective indentures that govern the CCH Senior Notes are subject to a number of important limitations and exceptions.

The CCH Senior Notes are CCH’s senior secured obligations, ranking senior in right of payment to any and all of CCH’s future indebtedness that is subordinated to the CCH Senior Notes and equal in right of payment with CCH’s other existing and future indebtedness that is senior and secured by the same collateral securing the CCH Senior Notes. The CCH Senior Notes are secured by a first-priority security interest in substantially all of CCH’s and the CCH Guarantors’ assets.

At any time prior to six months before the respective dates of maturity for each ~~series~~ of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes at a redemption price equal to the “make-whole” price set forth in the ~~CCH Indenture,~~appropriate indenture, plus accrued and unpaid interest, if any, to the date of redemption. ~~CCH also may at~~At any time within six months of the respective dates of maturity for each ~~series~~ of the CCH Senior Notes, CCH may redeem all or part of such series of the CCH Senior Notes, in whole or in part, at a redemption price equal to 100% of the principal amount of the CCH Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the date of redemption.

CCH Credit Facility

In May 2018, CCH amended and restated the CCH Credit Facility to increase total commitments under the CCH Credit Facility from $4.6 billion to $6.1 billion. The obligations of CCH under the CCH Credit Facility are secured by a first priority lien on substantially all of the assets of CCH and its subsidiaries and by a pledge by CCH HoldCo I of its limited liability company interests in CCH. As of ~~June 30, 2019~~both March 31, 2020 and December 31, ~~2018,~~2019, CCH had ~~zero and $1.0 billion of~~no available commitments and ~~$6.1 billion and $5.2~~$3.3 billion of loans outstanding under the CCH Credit ~~Facility, respectively.~~Facility.

The CCH Credit Facility matures on June 30, 2024, with principal payments due quarterly commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following the completion of the CCL Project as defined in the common terms agreement and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train of the CCL Project to become operational is entitled to terminate its SPA for failure to achieve the date of first commercial delivery for that agreement. Scheduled repayments will be based upon a 19-year tailored amortization, commencing the first full quarter after the completion of Trains 1 through 3 and designed to achieve a minimum projected fixed debt service coverage ratio of 1.50:1.

Under the CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt. CCH is restricted from making certain distributions under agreements governing its indebtedness generally until, among other requirements, the completion of the construction of Trains 1 through 3 of the CCL Project, funding of a debt service reserve account equal to six months of debt service and achieving a historical debt service coverage ratio and fixed projected debt service coverage ratio of at least 1.25:1.00.

CCH Working Capital Facility

In June 2018, CCH amended and restated the CCH Working Capital Facility to increase total commitments under the CCH Working Capital Facility from $350 million to $1.2 billion. The CCH Working Capital Facility is intended to be used for loans to CCH (“CCH Working Capital Loans”) and the issuance of letters of credit on behalf of CCH for certain working capital

requirements related to developing and ~~placing into operations~~operating the CCL Project and for related business purposes. Loans under the CCH Working Capital Facility are guaranteed by the CCH Guarantors. CCH may, from time to time, request increases in the commitments under the CCH Working Capital Facility of up to the maximum allowed for working capital under the Common Terms Agreement that was entered into concurrently with the CCH Credit Facility. As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, CCH had ~~$862~~$660 million and ~~$716~~$729 million of available commitments, ~~$338~~$399 million and ~~$316~~$471 million aggregate amount of issued letters of credit and ~~zero~~$141 million and ~~$168 million~~zero of loans outstanding under the CCH Working Capital Facility, respectively.

The CCH Working Capital Facility matures on June 29, 2023, and CCH may prepay the CCH Working Capital Loans and loans made in connection with a draw upon any letter of credit (“CCH LC Loans”) at any time without premium or penalty upon three business days’ notice and may re-borrow at any time. CCH LC Loans have a term of up to one year. CCH is required to reduce the aggregate outstanding principal amount of all CCH Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The CCH Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of CCH under the CCH Working Capital Facility are secured by substantially all of the assets of CCH and the CCH Guarantors as well as all of the membership interests in CCH and each of the CCH Guarantors on a pari passu basis with the CCH Senior Notes and the CCH Credit Facility.

Cheniere

~~CCH Note Purchase Agreement~~

Convertible Notes

In ~~June 2019, CCH entered into the CCH Note Purchase Agreement with Allianz Global Investors GmbH to issue~~November 2014, we issued an aggregate principal amount of ~~$727 million~~$1.0 billion of the ~~2039 CCH~~2021 Cheniere Convertible Unsecured Notes. The 2021 Cheniere Convertible Unsecured Notes are convertible at the option of the holder into our common stock at the then applicable conversion rate, provided that the closing price of our common stock is greater than or equal to the conversion price on the date of conversion. In March 2015, we issued $625 million aggregate principal amount of unsecured 2045 Cheniere Convertible Senior Notes. We have the right, at our option, at any time after March 15, 2020, to redeem all or any part of the 2045 Cheniere Convertible Senior Notes ~~which will be jointly and severally guaranteed by~~at a redemption price equal to the ~~CCH Guarantors. The conditions to closing and issuance~~accreted amount of the ~~2039 CCH~~2045 Cheniere Convertible Senior Notes ~~include~~to be redeemed, plus accrued and unpaid interest, if any, to such redemption date. We have the receipt of at least two investment grade ratings for the 2039 CCH Senior Notes, in addition to other customary conditions to closing. Pursuant to the CCH Note Purchase Agreement, CCH has up to 12 months, subject to a six-month extension at CCH’s option to satisfy the ~~conditions to closing~~conversion obligation for the 2021 Cheniere Convertible Unsecured Notes and ~~issuance. The net proceeds from~~ the ~~2039 CCH~~2045 Cheniere Convertible Senior Notes ~~will be used by CCH~~with cash, common stock or a combination thereof.

Cheniere Revolving Credit Facility

In December 2018, we amended and restated the Cheniere Revolving Credit Facility to ~~repay a portion of its outstanding term~~increase total commitments under the Cheniere Revolving Credit Facility from $750 million to $1.25 billion. The Cheniere Revolving Credit Facility is intended to fund, through loans and ~~pay fees, costs~~letters of credit, equity capital contributions to CCH HoldCo II and ~~expenses incurred~~its subsidiaries for the development of the CCL Project and, provided that certain conditions are met, for general corporate purposes. As of March 31, 2020 and December 31, 2019, we had $430 million and $665 million of available commitments, $365 million and $585 million aggregate amount of issued letters of credit and $455 million and zero of loans outstanding under the Cheniere Revolving Credit Facility, respectively.

The Cheniere Revolving Credit Facility matures on December 13, 2022 and contains representations, warranties and affirmative and negative covenants customary for companies like us with lenders of the type participating in ~~connection with~~ the ~~repayment~~Cheniere Revolving Credit Facility that limit our ability to make restricted payments, including distributions, unless certain conditions are satisfied, as well as limitations on indebtedness, guarantees, hedging, liens, investments and affiliate transactions. Under the Cheniere Revolving Credit Facility, we are required to ensure that the sum of ~~such outstanding term loans and/or~~our unrestricted cash and the ~~transactions contemplated~~amount of undrawn commitments under the Cheniere Revolving Credit Facility is at least equal to the lesser of (1) 20% of the commitments under the Cheniere Revolving Credit Facility and (2) $200 million (the “Liquidity Covenant”).

Cheniere Revolving Credit Facility and (3) we elect on a go-forward basis to be governed by a non-consolidated leverage ratio covenant not to exceed 5.75:1.00 (the “Springing Leverage Covenant”), which following such election will apply at any time that the aggregate principal amount of outstanding loans plus drawn and unreimbursed letters of credit under the Cheniere Revolving Credit Facility is greater than 30% of aggregate commitments under the Cheniere Revolving Credit Facility. Following the Trigger Point, at any time that the Springing Leverage Covenant is in effect, the Liquidity Covenant will not apply.

~~Restrictive Debt Covenants~~The Cheniere Revolving Credit Facility is secured by a first priority security interest (subject to permitted liens and other customary exceptions) in substantially all of our assets, including our interests in our direct subsidiaries (excluding CCH HoldCo II and certain other subsidiaries).

Cash Receipts from Subsidiaries

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. As of ~~June 30, 2019, each~~March 31, 2020, we owned a 48.6% limited partner interest in Cheniere Partners in the form of 104.5 million common units and 135.4 million subordinated units. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners. We are eligible to receive quarterly equity distributions from Cheniere Partners related to our ownership interests and our incentive distribution rights.

We also receive fees for providing management services to some of our ~~issuers was~~subsidiaries. We received $25 million and $20 million in ~~compliance~~total service fees from these subsidiaries during the three months ended March 31, 2020 and 2019, respectively.

Share Repurchase Program

On June 3, 2019, we announced that our Board authorized a 3-year, $1.0 billion share repurchase program. During the three months ended March 31, 2020, we repurchased an aggregate of 2.9 million shares of our common stock for $155 million, for a weighted average price per share of $53.88. As of March 31, 2020, we had up to $596 million of the share repurchase program available. Under the share repurchase program, repurchases can be made from time to time using a variety of methods, which may include open market purchases, privately negotiated transactions or otherwise, all in accordance with ~~all covenants related~~the rules of the SEC and other applicable legal requirements. The timing and amount of any shares of our common stock that are repurchased under the share repurchase program will be determined by our management based on market conditions and other factors. The share repurchase program does not obligate us to ~~their respective debt agreements.~~acquire any particular amount of common stock, and may be modified, suspended or discontinued at any time or from time to time at our discretion.

Marketing

We market and sell LNG produced by the Liquefaction Projects that is not required for other customers through our integrated marketing function. We ~~are developing~~have, and continue to develop, a portfolio of long-, medium- and short-term SPAs to transport and unload commercial LNG cargoes to locations ~~worldwide, which is~~worldwide. These volumes are expected to be primarily sourced by LNG produced by the Liquefaction Projects but supplemented by ~~volume~~volumes procured from other locations worldwide, as needed. As of ~~June 30, 2019,~~March 31, 2020, we have sold or have options to sell approximately ~~5,066~~4,856 TBtu of LNG to be delivered to customers between ~~2019~~2020 and 2045, excluding ~~volume~~volumes for ~~an agreement anticipated to~~agreements that may be assigned to SPL in the future. The cargoes have been sold either on a ~~free on board (“FOB”)~~FOB basis (delivered to the customer at the Sabine Pass LNG terminal or the Corpus Christi LNG ~~terminal)~~terminal, as applicable) or a delivered at terminal (“DAT”) basis (delivered to the customer at their LNG receiving terminal). We have chartered LNG vessels to be utilized infor cargoes sold on a DAT ~~transactions.~~basis. In addition, we have entered into a long-term agreement to sell LNG cargoes on a DAT basis that is conditioned upon the buyer achieving certain milestones.

Cheniere Marketing entered into uncommitted trade finance facilities with available commitments of $420 million as of ~~June 30, 2019,~~March 31, 2020, primarily to be used for the purchase and sale of LNG for ultimate resale in the course of its operations. The finance facilities are intended to be used for advances, guarantees or the issuance of letters of credit or standby letters of credit on behalf of Cheniere Marketing. As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, Cheniere Marketing had ~~$10~~$4 million and ~~$31~~$41 million, respectively, in standby letters of credit and guarantees outstanding under the finance facilities. As of ~~June 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, Cheniere Marketing had zero and $71 million, respectively, in loans outstanding under the finance facilities. As of March 31, 2020, there were no loans outstanding under the finance facilities. Cheniere Marketing pays interest or fees on utilized commitments.

Corporate and Other Activities

We are required to maintain corporate and general and administrative functions to serve our business activities described above. ~~We are also in various stages~~The development of ~~developing~~our sites or other projects, including infrastructure projects in support of natural gas supply and LNG demand, ~~which,~~will require, among other things, ~~will require~~ acceptable commercial and financing arrangements before we make an FID.

We have made an equity investment in Midship Holdings, LLC (“Midship Holdings”), which manages the business and affairs of Midship Pipeline. Midship Pipeline ~~which~~ is constructing ~~a pipeline~~the Midship Project with expected capacity of up to 1.44 million Dekatherms per day that will connect new gas production in the Anadarko Basin to Gulf Coast markets, including markets serving the Liquefaction Projects. Construction of the Midship Project commenced in the first quarter of 2019 and the Midship Project was placed in service in April 2020.

Restrictive Debt Covenants

As of March 31, 2020, each of our issuers was in compliance with all covenants related to their respective debt agreements.

LIBOR

The use of LIBOR is expected to be phased out by the end of 2021. It is currently unclear whether LIBOR will be utilized beyond that date or whether it will be replaced by a particular rate. We intend to continue to work with our lenders to pursue any amendments to our debt agreements that are currently subject to LIBOR and will continue to monitor, assess and plan for the phase out of LIBOR.

Sources and Uses of Cash

The following table summarizes the sources and uses of our cash, cash equivalents and restricted cash for the ~~six~~three months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions). The table presents capital expenditures on a cash basis; therefore, these amounts differ from the amounts of capital expenditures, including accruals, which are referred to elsewhere in this report. Additional discussion of these items follows the table.


	Six Months Ended June 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Operating cash flows	$	760		$	982		$	574		$	412
Investing cash flows	(1,542		)	(1,492		)	(654		)	(651		)
Financing cash flows	1,066			1,168			(85		)	94

Net increase in cash, cash equivalents and restricted cash	284			658
Net decrease in cash, cash equivalents and restricted cash							(165		)	(145		)
Cash, cash equivalents and restricted cash—beginning of period	3,156			2,613			2,994			3,156
Cash, cash equivalents and restricted cash—end of period	$	3,440		$	3,271		$	2,829		$	3,011

Operating Cash Flows

Our operating cash net inflows during the ~~six~~three months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ were ~~$760~~$574 million and ~~$982~~$412 million, respectively. The ~~$222~~$162 million ~~decrease~~increase in operating cash inflows in ~~2019~~2020 compared to ~~2018~~2019 was primarily related to increased operating costs and expenses, which were partially offset by increased cash receipts from the sale of LNG cargoes, as a result of the additional Trains that were operating at the Liquefaction Projects in 2019. In addition to Trains 1 through 4 of the SPL Project that were operational during both the six months ended June 30, 2019 and 2018, Train 5 of the SPL Project and Train 1 of the CCL Project were operational for approximately four months during the six months ended June 30, 2019.

2020.

Investing Cash Flows

Investing cash net outflows during the ~~six~~three months ended ~~June 30,~~March 31, 2020 and 2019 ~~and 2018~~ were ~~$1,542~~$654 million and ~~$1,492~~$651 million, respectively, and were primarily used to fund the construction costs for the Liquefaction Projects. These costs are capitalized as construction-in-process until achievement of substantial completion. Additionally, we invested ~~$34~~$90 million and $24 million in Midship Holdings, our equity method investment, during the ~~six~~three months ended ~~June 30, 2019.~~March 31, 2020 and 2019, respectively.

Financing Cash Flows

Financing cash net ~~inflows~~outflows during the ~~six~~three months ended ~~June 30, 2019~~March 31, 2020 were ~~$1,066~~$85 million, primarily as a result of:

$~~982~~455 million of borrowings under the ~~CCH~~Cheniere Revolving Credit Facility;

$~~649~~141 million of borrowings ~~under the 2019 CQP Credit Facilities;~~

~~$390 million of borrowings and $558 million in repayments~~ under the CCH Working Capital Facility;

$~~290~~300 million principal amount of the 2025 CCH HoldCo II Convertible Senior Notes converted into cash;

$154 million of distributions to non-controlling interest by Cheniere Partners;

$72155 million paid to repurchase approximately 3 million shares of ~~net repayments related to~~ our ~~Cheniere Marketing trade financing facilities;~~

~~$20 million of debt issuance costs primarily related to up-front fees paid upon~~common stock under the ~~closing of the 2019 CQP Credit Facilities;~~share repurchase program; and

$1439 million paid for tax withholdings for share-based compensation.

Financing cash net inflows during the ~~six~~three months ended ~~June 30, 2018~~March 31, 2019 were ~~$1.2 billion,~~$94 million, primarily as a result of:

$~~1.7 billion~~491 million of borrowings ~~and $281 million in repayments~~ under the CCH Credit Facility;

$14201 million of borrowings and $369 million in repayments under the CCH Working Capital Facility;

$~~123~~72 million of net ~~borrowings~~repayments related to our Cheniere Marketing trade financing facilities;

$46144 million of ~~debt issuance costs related to up-front fees paid for the amendment and restatement of the CCH Credit Facility and the CCH Working Capital Facility;~~

~~$8 million in debt extinguishment costs;~~

~~$288 million of~~ distributions ~~and dividends~~ to non-controlling interest by Cheniere ~~Partners and Cheniere Holdings;~~Partners; and

$812 million paid for tax withholdings for share-based compensation.

Results of Operations

The following charts summarize the number of Trains that were in operation during the year ended December 31, 2019 and the three months ended March 31, 2020 and total revenues and total LNG volumes loaded from our Liquefaction Projects (including both operational and commissioning volumes) during the three months ended March 31, 2020 and 2019:

The following table summarizes the volumes of operational and commissioning LNG cargoes that were loaded from the Liquefaction Projects, which were recognized on our Consolidated Financial Statements during the three ~~and six~~ months ended ~~June 30, 2019:~~March 31, 2020:

Three Months Ended June 30, 2019 Six Months Ended June 30, 2019
(in TBtu) Operational Commissioning Operational Commissioning
Volumes loaded during the current period 361
3
645
28
Volumes loaded during the prior period but recognized during the current period 27
—
25
3
Less: volumes loaded during the current period and in transit at the end of the period (36 ) (3 ) (36 ) (3 )
Total volumes recognized in the current period 352
—
634
28

Our consolidated net loss attributable to common stockholders was $114 million, or $0.44 per share (basic and diluted), in the three months ended June 30, 2019, compared to net loss attributable to common stockholders of $18 million, or $0.07 per share (basic and diluted), in the three months ended June 30, 2018. This $96 million increase in net loss attributable to common stockholders in 2019 was primarily attributable to decreased margins per MMBtu due to decreased pricing on LNG, increased interest expense, net of amounts capitalized, increased operating and maintenance expense, increased derivative loss, net, and increased depreciation and amortization expense, which were partially offset by decreased net income attributable to non-controlling interest.



	Three Months Ended March 31, 2020
(in TBtu)	Operational		Commissioning
Volumes loaded during the current period	455		—
Volumes loaded during the prior period but recognized during the current period	33		—
Less: volumes loaded during the current period and in transit at the end of the period	(29	)	—
Total volumes recognized in the current period	459		—

Our consolidated net income attributable to common stockholders was ~~$27~~$375 million, or ~~$0.11~~$1.48 per ~~share (basic~~share—basic and ~~diluted),~~$1.43 per share—diluted, in the ~~six~~three months ended ~~June 30, 2019,~~March 31, 2020, compared to net income attributable to common stockholders of ~~$339~~

$141 million, or ~~$1.42~~$0.55 per share—basic and ~~$1.40~~$0.54 per share—diluted, in the ~~six~~three months ended ~~June 30, 2018.~~March 31, 2019. This ~~$312~~$234 million ~~decrease~~increase in net income attributable to common stockholders in ~~2019~~2020 was primarily attributable to ~~decreased~~increased gross margins ~~per MMBtu~~ due to increased volume of LNG sold partially offset by decreased pricing on LNG and from increased ~~operating and maintenance expense, increased~~derivative gains on commodity derivatives, which were partially offset by increases in (1) interest rate derivative loss, net, ~~increased~~(2) interest expense, net of amounts capitalized, (3) income tax provision, (4) operating and ~~increased~~maintenance expense and (5) depreciation and amortization ~~expense, which were partially offset by decreased net income attributable to non-controlling interest.~~expense.

We enter into derivative instruments to manage our exposure to (1) changing interest rates, (2) commodity-related marketing and price risks and (3) foreign exchange volatility. Derivative instruments are reported at fair value on our Consolidated Financial Statements. In some cases, the underlying transactions economically hedged receive accrual accounting treatment, whereby revenues and expenses are recognized only upon delivery, receipt or realization of the underlying transaction. Because the recognition of derivative instruments at fair value has the effect of recognizing gains or losses relating to future period exposure, use of derivative instruments may increase the volatility of our results of operations based on changes in market pricing, counterparty credit risk and other relevant factors.

Revenues


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	2019		2018		Change		2019		2018		Change		2020		2019		Change
LNG revenues	$	2,173	$	1,442	$	731	$	4,316	$	3,608	$	708	$	2,568	$	2,143	$	425
Regasification revenues	67		65		2		133		130		3		67		66		1
Other revenues	52		36		16		104		47		57		74		52		22
Total revenues	$	2,292	$	1,543	$	749	$	4,553	$	3,785	$	768	$	2,709	$	2,261	$	448

We begin recognizing LNG revenues from the Liquefaction Projects following the substantial completion and the commencement of operating activities of the respective Trains. ~~In addition to~~Increased Trains ~~1 through 4 of~~in operation over the ~~SPL Project that were operational during both the six months ended June 30, 2019 and 2018, Train 5 of the SPL Project and Train 1 of the CCL Project~~

~~were operational for approximately four months during the six months ended June 30, 2019. The~~comparable period resulted in additional revenue from the increased volume of LNG sold. The increase in revenue attributable to LNG volume sold ~~following the achievement of substantial completion of these Trains in~~during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 from the comparable ~~periods~~period in ~~2018~~2019 was partially offset by decreased LNG revenues per MMBtu, which was primarily affected by ~~sales made at current~~decreased pricing on LNG and to a lesser degree, market prices realized for volumes sold by our integrated marketing function. Additionally, the increase in other revenues was primarily due to an increase in sub-chartering income. LNG revenues during the three months ended March 31, 2020 also included $53 million in revenues attributable to LNG cargoes contractually canceled by our customers, for which revenue is generally recognized upon notice of customer cancellation. We expect our LNG revenues to increase in the future upon Train 3 of the CCL Project and Train 6 of the SPL ~~Project and Trains 2 and 3 of the CCL~~ Project becoming operational.

Prior to substantial completion of a Train, amounts received from the sale of commissioning cargoes from that Train are offset against LNG terminal construction-in-process, because these amounts are earned or loaded during the testing phase for the construction of that Train. WeDuring the three months ended March 31, 2019, we realized offsets to LNG terminal costs of $202 million corresponding to 28 TBtu, ~~of LNG in the six months ended June 30, 2019~~respectively, that were related to the sale of commissioning cargoes from the Liquefaction Projects. We did not realize any offsets to LNG terminal costs induring the three months ended ~~June 30, 2019 and the three and six months ended June 30, 2018.~~March 31, 2020.

Also included in LNG revenues are gains and losses from derivative instruments ~~which include the realized value associated with a portion of derivative instruments that settle through physical delivery~~ and the sale of unutilized natural gas procured for the liquefaction process. ~~During~~We recognized revenues of $265 million and $134 million during the three months ended ~~June 30,~~March 31, 2020 and 2019, respectively, related to derivative instruments and ~~2018, we realized $183 million of gains and $34 million of losses, respectively,~~other revenues from these ~~transactions and other revenues. During the six months ended June 30, 2019 and 2018, we realized $317 million and $8 million, respectively, of gains from these transactions and other revenues.~~transactions.

The following table presents the components of LNG revenues and the corresponding LNG volumes ~~sold.~~sold:


	Three Months Ended June 30,					Six Months Ended June 30,				Three Months Ended March 31,
	2019		2018			2019		2018		2020		2019
LNG revenues (in millions):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	$	1,393	$	1,118		$	2,910	$	2,111	$	1,907	$	1,517
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	566		282			905		1,303		325		339
LNG procured from third parties	31		76			184		186		71		153
Other revenues and derivative gains (losses)	183		(34		)	317		8
Other revenues and derivative gains										265		134
Total LNG revenues	$	2,173	$	1,442		$	4,316	$	3,608	$	2,568	$	2,143

Volumes sold as LNG revenues (in TBtu):
Volumes delivered as LNG revenues (in TBtu):
LNG from the Liquefaction Projects sold under third party long-term agreements (1)	241		189			477		354		366		236
LNG from the Liquefaction Projects sold by our integrated marketing function under short-term agreements	111		41			157		149		93		46
LNG procured from third parties	5		10			23		21		14		18
Total volumes sold as LNG revenues	357		240			657		524
Total volumes delivered as LNG revenues										473		300

~~(1) Long-term agreements include agreements with tenure of 12 months or more.~~


(1)	Long-term agreements include agreements with a tenure of 12 months or more. LNG revenues include revenues with no corresponding volumes attributable to LNG cargoes contractually canceled by our customers, with revenue generally recognized upon notice of customer cancellation.

Operating costs and expenses


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended March 31,
(in millions)	2019		2018		Change		2019		2018		Change		2020		2019		Change
Cost of sales	$	1,277	$	873	$	404	$	2,491	$	2,051	$	440	$	724	$	1,214	$	(490	)
Operating and maintenance expense	295		147		148		516		287		229		316		221		95
Development expense	3		3		—		4		4		—		4		1		3
Selling, general and administrative expense	77		73		4		150		140		10		81		73		8
Depreciation and amortization expense	204		111		93		348		220		128		233		144		89
Impairment expense and loss on disposal of assets	4		—		4		6		—		6		5		2		3
Total operating costs and expenses	$	1,860	$	1,207	$	653	$	3,515	$	2,702	$	813	$	1,363	$	1,655	$	(292	)

Our total operating costs and expenses ~~increased~~decreased during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 from the three ~~and six~~ months ended ~~June 30, 2018,~~March 31, 2019, primarily as a result of ~~the increase in~~decreased cost of sales from increased derivative gains and lower pricing of natural gas feedstock, partially offset by increased operating and maintenance expense from additional operating Trains between ~~each of~~ the periods and increased ~~third-party service~~depreciation and ~~maintenance costs from additional maintenance and related activities at the SPL Project.~~amortization expense.

Cost of sales includes costs incurred directly for the production and delivery of LNG from the Liquefaction Projects, to the extent those costs are not utilized for the commissioning process. Cost of sales ~~increased~~decreased during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 from the three ~~and six~~ months ended ~~June 30, 2018~~March 31, 2019 primarily due to increased volumes of natural gas feedstock for our LNG sales as a result of substantial completion of Train 5 of the SPL Project and Train 1 of the CCL Project, partially offset by decreased pricing of natural gas feedstock, and increased vessel charter costs. Partially offsetting the increase in cost of natural gas feedstock wasderivative gains from an increase in fair value of the derivatives associated with economic hedges to secure natural gas feedstock for the Liquefaction Projects, primarily due to a favorable shift in ~~the~~ long-term forward ~~prices.~~prices relative to our hedged position. Additionally, cost of natural gas feedstock decreased between the periods due to decreased pricing, which was partially offset by increased volume. Partially offsetting these decreases was an increase in vessel charter costs. Cost of sales also includes port and canal fees, variable transportation and storage costs ~~costs associated with a portion of derivative instruments that settle through physical delivery~~ and the sale of natural gas procured for the liquefaction process and other costs to convert natural gas into LNG.

Operating and maintenance expense primarily includes costs associated with operating and maintaining the Liquefaction Projects. The increase in operating and maintenance expense during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 from the comparable 2019 period was primarily as a result of the increase in operating Trains. The increase during the three ~~and six~~ months ended ~~June 30, 2018~~March 31, 2020 from the comparable period in 2019 was primarily related to: (1) increased natural gas transportation and storage capacity demand charges from operating Train 5 of the SPL Project and ~~Train~~Trains 1 and 2 of the CCL Project following the respective substantial completions, (2) increased ~~cost of maintenance~~TUA reservation charges due to Total under the partial TUA assignment agreement and ~~related activities at the SPL Project,~~ (3) increased payroll and benefit costs from increased headcount to operate Train 5 of the SPL Project and ~~Train~~Trains 1 and 2 of the CCL Project and (4) increased TUA reservation charges paid to Total from payments under the partial TUA assignment agreement. Operating and maintenance expense also includes insurance and regulatory costs and other operating costs.Project.

Depreciation and amortization expense increased during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 from the three ~~and six~~ months ended ~~June 30, 2018~~March 31, 2019 as a result of ~~commencing operations~~an increased number of ~~Train 5 of the SPL Project and Train 1 of the CCL Project in March 2019 and February 2019, respectively, and completing construction of the Corpus Christi Pipeline in the second quarter of 2018,~~operational Trains, as the related assets began depreciating upon reaching substantial completion.

We expect our operating costs and expenses to generally increase in the future upon Train 3 of the CCL Project and Train 6 of the SPL Project ~~and Trains 2 and 3 of the CCL Project~~ achieving substantial completion, although we expect certain costs will not proportionally increase with the number of operational Trains as cost efficiencies will be realized.

Other expense (income)


	Three Months Ended June 30,									Six Months Ended June 30,									Three Months Ended March 31,
(in millions)	2019			2018			Change			2019			2018			Change			2020			2019			Change
Interest expense, net of capitalized interest	$	372		$	216		$	156		$	619		$	432		$	187		$	412		$	247		$	165
Loss on modification or extinguishment of debt	—			15			(15		)	—			15			(15		)	1			—			1
Derivative loss (gain), net	74			(32		)	106			109			(109		)	218
Other income	(16		)	(10		)	(6		)	(32		)	(17		)	(15		)
Interest rate derivative loss, net																			208			35			173
Other income, net																			(9		)	(16		)	7
Total other expense	$	430		$	189		$	241		$	696		$	321		$	375		$	612		$	266		$	346

Interest expense, net of capitalized interest, increased during the three ~~and six~~ months ended ~~June 30, 2019 compared to~~March 31, 2020 from the three ~~and six~~ months ended ~~June 30, 2018,~~March 31, 2019 as a result of increased outstanding debt (before unamortized premium, discount and debt issuance costs, net) from $27.6 billion as of June 30, 2018 to $30.7 billion as of June 30, 2019, primarily due to increased borrowings under the CCH Credit Facility, as well as a decrease in the portion of total interest costs that ~~could be capitalized~~is eligible for capitalization as additional Trains of the Liquefaction Projects completed construction between the periods. ~~For~~During the three months ended ~~June 30,~~March 31, 2020 and 2019, ~~and 2018,~~ we incurred ~~$458~~$471 million and ~~$412~~$448 million of total interest cost, respectively, of which we capitalized ~~$86~~$59 million and ~~$196~~$201 million, respectively, which was primarily related to interest costs incurred to construct the ~~construction~~remaining assets of the Liquefaction Projects. For the six months ended June 30, 2019 and 2018, we incurred $906 million and $816 million of total interest cost, respectively, of which we capitalized $287 million and $384 million, respectively, which was primarily related to the construction of the Liquefaction Projects.

Loss on modification or extinguishment of debt during the three and six months ended June 30, 2019 decreased from the comparable periods in 2018. Loss on modification or extinguishment of debt recognized in 2018 was attributable to $15 million

of debt modification and extinguishment costs relating to the incurrence of third-party fees and write-off of unamortized debt issuance costs as a result of the amendment and restatement of the CCH Credit Facility.

Derivative loss, net increased during the three ~~and six~~ months ended ~~June 30, 2019~~March 31, 2020 compared to the three ~~and six~~ months ended ~~June 30, 2018,~~March 31, 2019, primarily due to an unfavorable shift in the long-term forward LIBOR curve between the periods.

Other income, ~~increased~~net decreased during the three ~~and six~~ months ended ~~June 30, 2019 as~~March 31, 2020 compared to the three ~~and six~~ months ended ~~June 30, 2018,~~March 31, 2019, primarily due to ~~an increase~~a decrease in interest income earned on our cash and cash ~~equivalents.~~equivalents and restricted cash.

Income tax ~~benefit (provision)~~provision


	Three Months Ended June 30,								Six Months Ended June 30,									Three Months Ended March 31,
(in millions)	2019			2018			Change		2019			2018			Change			2020			2019			Change
Income before income taxes and non-controlling interest	$	2		$	147		(145	)	$	342		$	762		$	(420	)	$	734		$	340		$	394
Income tax benefit (provision)	—			3			(3	)	(3		)	(12		)	9

Income tax provision																		(131		)	(3		)	(128		)
Effective tax rate	—		%	2.0		%			0.9		%	1.6		%				17.8		%	0.9		%

~~Income~~The effective tax ~~benefit decreased $3 million during~~rate for the three months ended June 30, 2019 and income tax provision decreased $9 million during the six months ended June 30, 2019, respectively, from the comparable periods in 2018 primarily attributable to changes in the income earned and tax transfer pricing applied to our U.K. integrated marketing function. The effective tax rates during each of the three and six months ended June 30, 2019 and 2018 wereMarch 31, 2020 is lower than the 21% federal statutory rate primarily asdue to income allocated to non-controlling interest that is not taxable to Cheniere, partially offset by a ~~result~~one-time discrete event related to an internal tax restructuring. The discrete item resulted in expense of $38 million for the three months ended March 31, 2020. The effective tax rate for the three months ended March 31, 2019 is lower than the 21% federal statutory rate primarily due to maintaining a valuation allowance against our federal ~~and state net~~ deferred tax assets. ~~Given our current~~

On March 27, 2020, the Coronavirus Aid, Relief and ~~anticipated future earnings, we believe that there~~Economic (CARES) Act (“the CARES Act”) was signed into law which provides numerous tax changes in response to the COVID-19 pandemic. The most significant provision expected to impact us is ~~a reasonable possibility that within approximately 6~~the modification to ~~18 months, sufficient positive evidence may become available~~the business interest expense limitation. The CARES Act increases the adjusted taxable income limitation from 30% to 50% for business interest deductions in 2019 and 2020 and will allow us to ~~conclude that a significant portion of the valuation allowance will no longer be needed. The release of the valuation allowance would result~~deduct additional business interest expense in the recognition of certain deferred tax assets and an income tax benefit in the period the release is recorded. However, the precise timing and amount of the valuation allowance release are subject to change on the basis of the level of profitability that we are able to achieve.2020.

Net income attributable to non-controlling interest


	Three Months Ended June 30,							Six Months Ended June 30,							Three Months Ended March 31,
(in millions)	2019		2018		Change			2019		2018		Change			2020		2019		Change
Net income attributable to non-controlling interest	$	116	$	168	$	(52	)	$	312	$	411	$	(99	)	$	228	$	196	$	32

Net income attributable to non-controlling interest decreased during the three and six months ended June 30, 2019 from the three and six months ended June 30, 2018 due to the decrease of non-controlling interest as a result of our merger with Cheniere Holdings in September 2018, in which all publicly-held shares of Cheniere Holdings were canceled and the non-controlling interest in Cheniere Holdings was reduced to zero. Net income attributable to non-controlling interest also decreasedincreased during the three months ended ~~June 30, 2019~~March 31, 2020 from the three months ended ~~June 30, 2018~~March 31, 2019 primarily due to ~~the decrease~~an increase in consolidated net income recognized by Cheniere ~~Partners in which the non-controlling interests are held.~~Partners. The consolidated net income recognized by Cheniere Partners ~~decreased~~increased from ~~$281~~$385 million in the three months ended ~~June 30, 2018~~March 31, 2019 to ~~$232~~$435 million in the three months ended ~~June 30, 2019~~March 31, 2020 primarily due ~~an increase~~increased gross margins due to higher volumes of LNG, partially offset by increases in (1) interest expense, net of capitalized interest, ~~as a result of the decrease in the portion of total interest costs that could be capitalized as an additional Train of the SPL Project completed construction between the periods.~~(2) depreciation and amortization expense and (3) operating and maintenance expense.

Off-Balance Sheet Arrangements

As of ~~June 30, 2019,~~March 31, 2020, we had no transactions that met the definition of off-balance sheet arrangements that may have a current or future material effect on our consolidated financial position or operating results.

Summary of Critical Accounting Estimates

The preparation of our Consolidated Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019.

Recent Accounting Standards

For descriptions of recently issued accounting standards, see Note 1—Nature of Operations and Basis of Presentation of our Notes to Consolidated Financial Statements.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

~~Cash Investments~~

We have cash investments that we manage based on internal investment guidelines that emphasize liquidity and preservation of capital. Such cash investments are stated at historical cost, which approximates fair market value on our Consolidated Balance Sheets.

Marketing and Trading Commodity Price Risk

We have entered into commodity derivatives consisting of natural gas supply contracts for the commissioning and operation of the SPL Project, the CCL Project and potential future development of Corpus Christi Stage 3 (“Liquefaction Supply Derivatives”). We have also entered into financial derivatives to hedge the exposure to the commodity markets in which we have contractual arrangements to purchase or sell physical LNG (“LNG Trading Derivatives”). In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives and the LNG Trading Derivatives to changes in underlying commodity prices, management modeled a 10% change in the commodity price for natural gas for each delivery location and a 10% change in the commodity price for LNG, respectively, as follows (in millions):


	June 30, 2019				December 31, 2018					March 31, 2020				December 31, 2019
	Fair Value		Change in Fair Value		Fair Value			Change in Fair Value		Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
Liquefaction Supply Derivatives	$	90	$	127	$	(42	)	$	6	$	678	$	180	$	149	$	179
LNG Trading Derivatives	47		39		(24		)	9		185		2		165		22

Interest Rate Risk

We are exposed to interest rate risk primarily when we incur debt related to project financing. Interest rate risk is managed in part by replacing outstanding floating-rate debt with fixed-rate debt with varying maturities. CCH has entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the CCH Credit Facility (“CCH Interest Rate Derivatives”) and to hedge against changes in interest rates that could impact anticipated future issuance of debt by CCH (“CCH Interest Rate Forward Start Derivatives”). In order to test the sensitivity of the fair value of the CCH Interest Rate Derivatives to changes in interest rates, management modeled a 10% change in the forward one-month LIBOR curve across the remaining terms of the CCH Interest Rate Derivatives and CCH Interest Rate Forward Start Derivatives as follows (in millions):


	June 30, 2019					December 31, 2018				March 31, 2020					December 31, 2019
	Fair Value			Change in Fair Value		Fair Value		Change in Fair Value		Fair Value			Change in Fair Value		Fair Value			Change in Fair Value
CCH Interest Rate Derivatives	$	(88	)	$	25	$	18	$	37	$	(197	)	$	4	$	(81	)	$	19
CCH Interest Rate Forward Start Derivatives	(7		)	20		—		—		(92		)	9		(8		)	15

Foreign Currency Exchange Risk

We have entered into foreign currency exchange (“FX”) contracts to hedge exposure to currency risk associated with operations in countries outside of the United States (“FX Derivatives”). In order to test the sensitivity of the fair value of the FX Derivatives to changes in FX rates, management modeled a 10% change in FX rate between the U.S. dollar and the applicable foreign currencies as follows (in millions):

June 30, 2019 December 31, 2018
Fair Value Change in Fair Value Fair Value Change in Fair Value
FX Derivatives $ 10
$ 1
$ 15
$ 1



	March 31, 2020				December 31, 2019
	Fair Value		Change in Fair Value		Fair Value		Change in Fair Value
FX Derivatives	$	23	$	2	$	4	$	—

See Note 6—Derivative Instruments for additional details about our derivative instruments.


ITEM 4.	CONTROLS AND PROCEDURES

We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under the Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. As of the end of the period covered by this report, we evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer, the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-15 of the Exchange Act. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures are effective.

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

We may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. We regularly analyze current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters. ~~Other than discussed below, there~~There have been no material changes to the legal proceedings disclosed in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019.

In February 2018, the Pipeline and Hazardous Materials Safety Administration (“PHMSA”) issued a Corrective Action Order (the “CAO”) to SPL in connection with a minor LNG leak from one tank and minor vapor release from a second tank at the Sabine Pass LNG terminal. These two tanks have been taken out of operational service while we conduct analysis, repair and remediation. On April 20, 2018, SPL and PHMSA executed a Consent Agreement and Order (the “Consent Order”) that replaces and supersedes the CAO. On July 9, 2019, PHMSA and FERC issued a joint letter setting out operating conditions required to be met prior to SPL returning the tanks to service. We continue to coordinate with PHMSA and FERC to address the matters relating to the February 2018 leak, including repair approach and related analysis. We do not expect that the Consent Order and related analysis, repair and remediation will have a material adverse impact on our financial results or operations.


ITEM 1A.	RISK FACTORS

~~There~~The information presented below updates, and should be read in conjunction with, the risk factors disclosed in our annual report on Form 10-K for the year ended December 31, 2019. Except as presented below, there have been no material changes from the risk factors disclosed in our annual report on Form 10-K for the year ended December 31, ~~2018~~2019.

The outbreak of COVID-19 and volatility in the energy markets may materially and adversely affect our business, financial condition, operating results, cash flow, liquidity and prospects.

The outbreak of COVID-19 and its development into a pandemic in March 2020 have resulted in significant disruption globally. Actions taken by various governmental authorities, individuals and companies around the world to prevent the spread of COVID-19 have restricted travel, business operations, and the overall level of individual movement and in-person interaction across the globe. Additionally, recent disputes over production levels between members of the Organization of Petroleum Exporting Countries and other oil producing countries has resulted in increased volatility in oil and natural gas prices.

The extent, duration and magnitude of the COVID-19 pandemic’s effects will depend on future developments, all of which are highly uncertain and difficult to predict, including the impact of the pandemic on global and regional economies, travel, and economic activity, as well as actions taken by governments, business and individuals in response to the pandemic or any future resurgence. These developments include the impact of the COVID-19 pandemic on unemployment rates, the demand for oil and natural gas, levels of consumer confidence and the post-pandemic pace of recovery.

Many uncertainties remain with respect to the COVID-19 pandemic, and we continue to monitor the rapidly evolving situation. The COVID-19 pandemic alone or coupled with continued volatility in the energy markets may materially and adversely affect our business, financial condition, operating results, cash flow, liquidity and prospects or have the effect of heightening many of the other risks described herein and in our annual report on Form 10-K for the year ended December 31, 2019. The extent to which our business, contracts, financial condition, operating results, cash flow, liquidity and prospects are affected by the COVID-19 outbreak or volatility in the energy markets will depend on various factors beyond our control and are highly uncertain, including the duration and scope of the outbreak, decreased demand for LNG and the resulting economic effects of the outbreak of COVID-19.

Our ability to generate cash is substantially dependent upon the performance by customers under long-term contracts that we have entered into, and we could be materially and adversely affected if any significant customer fails to perform its contractual obligations for any reason.

Our future results and liquidity are substantially dependent upon performance by our customers to make payments under long-term contracts. As of March 31, 2020, SPL had SPAs with eight third-party customers, CCL had SPAs with nine third-party customers and our integrated marketing function had a limited number of SPAs with third-party customers. In addition, SPLNG had TUAs with two third-party customers. We are dependent on each customer’s continued willingness and ability to perform its obligations under its SPA or TUA. We are exposed to the credit risk of any guarantor of these customers’ obligations under their respective agreements in the event that we must seek recourse under a guaranty. As a result of the disruptions caused by the COVID-19 pandemic and the volatility in the energy markets, we believe we are exposed to heightened credit and performance risk of our customers. Additionally, some customers have indicated to us that COVID-19 has begun to impact their operations and/or may impact their operations in the future. Some of our SPA customers’ primary countries of business have experienced a significant number of COVID-19 cases and/or have been subject to government imposed lockdown or quarantine measures. Although we believe that impacts of the COVID-19 pandemic on LNG regasification facilities, downstream markets and broader energy demand do not constitute valid force majeure claims under our FOB LNG SPAs, if any significant customer fails to perform its obligations under its SPA or TUA, our business, contracts, financial condition, operating results, cash flow, liquidity and prospects

could be materially and adversely affected, even if we were ultimately successful in seeking damages from that customer or its guarantor for a breach of the agreement.

Cost overruns and delays in the completion of one or more Trains, as well as difficulties in obtaining sufficient financing to pay for such costs and delays, could have a material adverse effect on our business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

The actual construction costs of the Trains may be significantly higher than our current estimates as a result of many factors, including change orders under existing or future EPC contracts resulting from the occurrence of certain specified events that may give our EPC contractor the right to cause us to enter into change orders or resulting from changes with which we otherwise agree. We have already experienced increased costs due to change orders. As construction progresses, we may decide or be forced to submit change orders to our contractor that could result in longer construction periods, higher construction costs or both, including change orders to comply with existing or future environmental or other regulations.

The outbreak of COVID-19 and the resulting actions taken by governmental and regulatory authorities to prevent the spread of COVID-19 may cause a slow-down in the construction of one or more Trains. Our EPC contractor has advised us of voluntary proactive measures it is taking to protect employees and to mitigate risks associated with COVID-19, however, it has not indicated that there will be any changes to the project cost or schedule and is still performing its obligations under its EPC contracts. While the construction of Trains is continuing, if there was a major outbreak of COVID-19 at any construction site or the implementation of restrictions by the government that prevented construction for an extended period, we could experience significant delays in the construction of one or more Trains.

Delays in the construction of one or more Trains beyond the estimated development periods, as well as change orders to our existing EPC contracts or any future EPC contract related to additional Trains, could increase the cost of completion beyond the amounts that we estimate, which could require us to obtain additional sources of financing to fund our operations until the applicable liquefaction project is fully constructed (which could cause further delays). Our ability to obtain financing that may be needed to provide additional funding to cover increased costs will depend, in part, on factors beyond our control. Accordingly, we may not be able to obtain financing on terms that are acceptable to us, or at all. Even if we are able to obtain financing, we may have to accept terms that are disadvantageous to us or that may have a material adverse effect on our current or future business, contracts, financial condition, operating results, cash flow, liquidity and prospects.

Outbreaks of infectious diseases, such as the outbreak of COVID-19, at one or more of our facilities could adversely affect our operations.

Federal, state and local governments have enacted various measures to try to contain the outbreak of COVID-19, such as travel bans and restrictions, quarantines, shelter-in-place orders and business shutdowns. Our facilities at the Sabine Pass LNG terminal and Corpus Christi LNG terminal are critical infrastructure and have continued to operate during the outbreak, which means that we must keep our employees who operate our facilities safe and minimize unnecessary risk of exposure to the virus. In response, we have taken extra precautionary measures to protect the continued safety and welfare of our employees who continue to work at our facilities and have modified certain business and workforce practices, such as implementing work from home policies where appropriate. The measures taken to prevent an outbreak at our facilities have resulted in increased costs. If a large number of our employees in those critical facilities were to contract COVID-19 at the same time, our operations could be adversely affected.


ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Purchase of Equity Securities by the Issuer and Affiliated Purchasers

The following table summarizes stock repurchases for the three months ended ~~June 30, 2019:~~March 31, 2020:

Period Total Number of Shares Purchased (1) Average Price Paid Per Share (2) Total Number of Shares Purchased as a Part of Publicly Announced Plans Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (3)
April 1 - 30, 2019 425 $64.70 — —
May 1 - 31, 2019 13,973 $67.87 — —
June 1 - 30, 2019 45,266 $68.24 44,600 $996,954,020



Period	Total Number of Shares Purchased (1)	Average Price Paid Per Share (2)	Total Number of Shares Purchased as a Part of Publicly Announced Plans	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans (3)
January 1 - 31, 2020	689,407	$60.91	681,100	$709,400,285
February 1 - 29, 2020	961,734	$55.97	225,892	$695,992,139
March 1 - 31, 2020	1,968,384	$50.80	1,968,384	$595,952,809
Total	3,619,525	$54.11	2,875,376

(1)

Includes issued shares surrendered to us by participants in our share-based compensation plans for payment of applicable tax withholdings on the vesting of share-based compensation awards. Associated shares surrendered by participants are repurchased pursuant to ~~settle~~terms of the ~~participants’ personal tax liabilities that resulted from~~plan and award agreements and not as part of the ~~lapsing of restrictions on shares awarded to the participants under these plans.~~publicly announced share repurchase plan.


(2)	The price paid per share was based on the ~~closing~~average trading price of our common stock on the dates on which we repurchased the shares.


(3)	On June 3, 2019, we announced that our Board authorized a 3-year, $1 billion share repurchase program. For additional information, see Note 16—Share Repurchase Program.


ITEM 6.	EXHIBITS



Exhibit No.		Description
~~10.1~~10.1*		Omnibus Amendment 4 to Amended and Restated Note Purchase Agreement, Amendment to Registration Rights Agreement and Administrative Agent and Technical Agent Resignation and Appointment Agreement, dated as of February 18, 2020, by and among CCH HoldCo II, as Issuer, EIG Management Company, LLC, as resigning administrative agent and as technical agent, The Bank of New York Mellon, as collateral agent and as Successor Agent and the note holders identified therein
10.2		Amendment 5 to Amended and Restated Note Purchase Agreement, dated as of February 24, 2020, by and among CCH HoldCo II, as Issuer, the Company, EIG Management Company, LLC, as technical agent, The Bank of New York Mellon, as administrative agent and collateral agent and the note holders identified therein (Incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on February 25, 2020)
10.3		Working Capital Revolving Credit and ~~Guaranty~~Letter of Credit Reimbursement Agreement, ~~dated May 29, 2019,~~ among ~~Cheniere Partners,~~SPL, as ~~Borrower,~~borrower, certain subsidiaries of ~~Cheniere Partners,~~SPL, The Bank of Nova Scotia, as ~~Subsidiary Guarantors,~~Senior Facility Agent, Société Générale, as the Common Security Trustee, the issuing banks and lenders from time to time party thereto ~~Natixis, Société Générale, The Bank of Nova Scotia, Wells Fargo Bank, as Issuing Banks, MUFG Bank, LTD as Administrative Agent and Sole Coordinating Lead Arranger, and certain arrangers~~ and other participants (Incorporated by reference to Exhibit 10.1 to ~~Cheniere Partners’~~SPL’s Current Report on Form 8-K (SEC File No. ~~001-33366)~~333-192373), filed on ~~June 3, 2019)~~March 23, 2020)
10.2*10.4		Third Amended and Restated ~~Senior Working Capital Revolving Credit and Letter of Credit Reimbursement~~Common Terms Agreement, dated September 4, 2015, as amended by (a) Third Omnibus Amendment, dated as of May 23, 2018; (b) Fourth Omnibus Amendment, dated as of September 17, 2018; and (c) Fifth Omnibus Amendment, Consent and Waiver, dated as of May 29, 2019, among SPL, as ~~Borrower, The Bank of Nova Scotia, as Senior Issuing Bank~~borrower, the Secured Debt Holder Group Representatives party thereto, the Secured Hedge Representatives party thereto, the Secured Gas Hedge Representatives party thereto and ~~Senior Facility Agent, ABN Amro Capital USA LLC, HSBC Bank USA, National Association and ING Capital LLC, as Senior Issuing Banks,~~ Société Générale, as ~~Swing Line Lender and~~the Common Security Trustee and the ~~senior lenders party thereto from time~~Intercreditor Agent (Incorporated by reference to ~~time~~Exhibit 10.2 to SPL’s Current Report on Form 8-K (SEC File No. 333-192373), filed on March 23, 2020)
10.3*10.5		Third Amended and Restated Accounts Agreement, among SPL, certain subsidiaries of SPL, Société Générale, as the Common Security Trustee, and Citibank, N.A. as the Accounts Bank (Incorporated by reference to Exhibit 10.3 to SPL’s Current Report on Form 8-K (SEC File No. 333-192373), filed on March 23, 2020)
10.6*		Change ~~orders~~order to the ~~Fixed Price Separated~~Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the ~~Corpus Christi~~Sabine Pass LNG Stage 14 Liquefaction Facility, dated ~~as of December 6, 2013,~~November 7, 2018, by and between ~~CCL~~SPL and Bechtel Oil Gas and Chemicals, Inc.: (i) the Change Order ~~CO-00051 Fencing Scope Modifications,~~CO-00013 Cost to Comply with SPL FTZ (FTZ entries, bonded transports and receipts for AG Pipe Spools Only), dated ~~April 19, 2019 and~~February 10, 2020, (ii) the Change Order ~~CO-00052 West Jetty Manual~~CO-00014 Permanent Access Road to Third Berth, dated February 10, 2020, (iii) the Change Order CO-00015 Modifications to Schedule Bonus Language, dated February 10, 2020, (iv) the Change Order CO-00016 LNG Berth 3 LNTP No 3, dated January 31, 2020 and (v) the Change Order CO-00017 Construction Doc Fender Guards and LP Fuel Gas ~~Sampler,~~Overpressure Interlock, dated ~~April 19, 2019 (Portions of this exhibit have been omitted.)~~March 18, 2020
10.410.7		Change orders to the Amended and Restated Fixed Price Separated Turnkey Agreement for the Engineering, Procurement and Construction of the Corpus Christi Stage 2 Liquefaction Facility, dated as of December 12, 2017, between CCL and Bechtel Oil, Gas and Chemicals, Inc.: (i) the Change Order ~~CO-000013 Section 232 Steel and Aluminum Tariffs~~CO-00024 East Jetty Cooldown Line & ~~Anti-dumping (ADA) and Countervailing Duties (CVD),~~Simultaneous Ship Loading, dated ~~May 2, 2019,~~January 6, 2020, (ii) the Change Order ~~CO-00014~~CO-00025 East Jetty Manual Gas Sampler, dated January 7, 2020, (iii) the Change Order CO-00026 Study for Adding Valve Actuator for E-W Jetty Flow Segregation, dated January 8, 2020, (iv) the Change Order CO-00027 Tank B ~~Jump-over Tie-In Interface~~Isolation of Proposed Fourth In-Tank LNG Pump - Long Lead Items, dated ~~May 2, 2019 and (iii)~~January 8, 2020, (v) the Change Order ~~CO-00015 Section 232 Steel~~CO-00028 Tank B Rundown Line (Part I), dated January 31, 2020, (vi) the Change Order CO-00029 9% Nickel and ~~Aluminum Tariffs & Anti-dumping (ADA)~~Cryogenic Rebar Provisional Sum Closeout, dated February 18, 2020 and ~~Countervailing Duties (CVD) Q1_2019,~~(vii) the Change Order CO-00030 Additional Valve for Isolation in CCL Stage 2 to CCL Stage 3 from Tank B, dated ~~June 4, 2019~~February 18, 2020 (Portions of this exhibit have been ~~omitted.)~~
10.5*		Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 2 Liquefaction Facility, dated December 20, 2012, by and between SPL and Bechtel Oil Gas and Chemicals, Inc.: the Change Order CO-00045 Letter of Credit Reduction and Extension, dated June 7, 2019
10.6*		Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 4 Liquefaction Facility, dated November 7, 2018, by and between SPL and Bechtel Oil Gas and Chemicals, Inc.: the Change Order CO-00001 Modifications to Insurance Language Change Order, dated June 3, 2019omitted)
31.1*		Certification by Chief Executive Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
31.2*		Certification by Chief Financial Officer required by Rule 13a-14(a) and 15d-14(a) under the Exchange Act
32.1**		Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**		Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS*		XBRL Instance Document ~~- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.~~
101.SCH*		~~Inline~~ XBRL Taxonomy Extension Schema Document
101.CAL*		~~Inline~~ XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*		~~Inline~~ XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*		~~Inline~~ XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*		~~Inline~~ XBRL Taxonomy Extension Presentation Linkbase Document
104*		Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)



*	Filed herewith.
**	Furnished herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.



		CHENIERE ENERGY, INC.

Date:	~~August 7, 2019~~April 29, 2020	By:	/s/ Michael J. Wortley
			Michael J. Wortley
			Executive Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)

Date:	~~August 7, 2019~~April 29, 2020	By:	/s/ Leonard E. Travis
			Leonard E. Travis
			Senior Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

5455



	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Balance Sheets	3
	Consolidated Statements of Operations	4
	Consolidated Statements of Stockholders’ Equity	5
	Consolidated Statements of Cash Flows	76
	Notes to Consolidated Financial Statements	87

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3028

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	5049

Item 4.	Controls and Procedures	5150

Part II. Other Information
Item 1.	Legal Proceedings	5251

Item 1A.	Risk Factors	5251

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	5253

Item 6.	Exhibits	5354

	Signatures	5455



Years Ending December 31,	Operating Leases (1)		Capital Leases (2)
2019 (3)	$	380	$	5
2020	184		5
2021	238		5
2022	264		5
2023	264		5
Thereafter	999		73
Total lease payments	2,329		98
Less: Interest	—		(39		)
Present value of lease liabilities	$	2,329	$	59



	CCL Stage 1		CCL Stage 2
Overall project completion percentage	99.5%		62.4%
Completion percentage of:
Engineering	100%		94.3%
Procurement	100%		92.5%
Subcontract work	96.4%		12.2%
Construction	99.2%		29.2%
Expected date of substantial completion	Train 2	3Q 2019	Train 3	2H 2021