10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2015

OR

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

For the transition period fromto

CHENIERE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Delaware	001-16383	95-4352386
(State or other jurisdiction of incorporation or organization)	(Commission File Number)	(I.R.S. Employer Identification No.)
700 Milam Street, Suite 1900
Houston, Texas		77002
(Address of principal executive offices)		(Zip code)

(713) 375-5000

(Registrant’s telephone number, including area code)

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  x   No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).  Yes  x   No  ¨

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

Large accelerated filer x	Accelerated filer                    ¨
Non-accelerated filer   ¨	Smaller reporting company   ¨
(Do not check if a smaller reporting company)

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

As of October 20, 2015, the issuer had 236,032,655 shares of Common Stock outstanding.

CHENIERE ENERGY, INC.

TABLE OF CONTENTS

	Definitions	1
Part I. Financial Information
Item 1.	Consolidated Financial Statements	3
	Consolidated Balance Sheets	3
	Consolidated Statements of Operations	4
	Consolidated Statement of Stockholders’ Equity	5
	Consolidated Statements of Cash Flows	6
	Notes to Consolidated Financial Statements	7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	27
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	42
Item 4.	Controls and Procedures	43
Part II. Other Information
Item 1.	Legal Proceedings	44
Item 1A.	Risk Factors	44
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
Item 5.	Other Information	44
Item 6.	Exhibits	45
	Signatures	47

i

DEFINITIONS

As commonly used in the liquefied natural gas industry, to the extent applicable, and as used in this quarterly report, the terms listed below have the following meanings: 

Common Industry and Other Terms

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 consisting primarily of methane (CH4) that is in liquid form at near atmospheric pressure
MMBtu	million British thermal units, an energy unit
mtpa	million tonnes per annum
non-FTA countries	countries without a free trade agreement providing for national treatment for trade in natural gas and with which trade is permitted
SEC	Securities and Exchange Commission
SPA	LNG sale and purchase agreement
Train	a refrigerant compressor train used in the industrial process to convert natural gas into LNG
TUA	terminal use agreement

1

Abbreviated Organizational Structure

The following diagram depicts our abbreviated organizational structure as of September 30, 2015, 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. (NYSE MKT: LNG) and its consolidated subsidiaries, including our publicly traded subsidiaries, Cheniere Partners (NYSE MKT: CQP) and Cheniere Holdings (NYSE MKT: CQH).

2

PART I.        FINANCIAL INFORMATION

ITEM 1.    CONSOLIDATED FINANCIAL STATEMENTS

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands, except share data)

	September 30,			December 31,
	2015			2014
ASSETS	(unaudited)
Current assets
Cash and cash equivalents	$	1,340,262		$	1,747,583
Restricted cash	652,225			481,737
Accounts and interest receivable	6,645			4,419
LNG inventory	9,032			4,294
Other current assets	78,108			20,844
Total current assets	2,086,272			2,258,877
Non-current restricted cash	118,909			550,811
Property, plant and equipment, net	15,225,250			9,246,753
Debt issuance costs, net	640,399			242,323
Non-current derivative assets	30,770			11,744
Goodwill	76,819			76,819
Other non-current assets	273,840			186,356
Total assets	$	18,452,259		$	12,573,683
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	11,558		$	13,426
Accrued liabilities	457,901			169,129
Deferred revenue	26,653			26,655
Derivative liabilities	33,839			23,247
Other current liabilities	268			18
Total current liabilities	530,219			232,475
Long-term debt, net	15,835,910			9,806,084
Non-current deferred revenue	10,500			13,500
Non-current derivative liabilities	125,473			267
Other non-current liabilities	85,226			19,840
Commitments and contingencies (see Note 11)
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 September 30, 2015 and December 31, 2014
Issued and outstanding: 236.0 million shares and 236.7 million shares at September 30, 2015 and December 31, 2014, respectively	708			712
Treasury stock: 11.2 million shares and 10.6 million shares at September 30, 2015 and December 31, 2014, respectively, at cost	(337,057		)	(292,752		)
Additional paid-in-capital	3,029,317			2,776,702
Accumulated deficit	(3,332,851		)	(2,648,839		)
Total stockholders’ deficit	(639,883		)	(164,177		)
Non-controlling interest	2,504,814			2,665,694
Total equity	1,864,931			2,501,517
Total liabilities and equity	$	18,452,259		$	12,573,683

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

3

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share data)

(unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
Revenues
LNG terminal revenues	$	67,212		$	66,983		$	202,698		$	200,243
Marketing and trading revenues (losses)	(1,557		)	(499		)	(1,601		)	482
Other	404			323			1,356			1,277
Total revenues	66,059			66,807			202,453			202,002
Operating costs and expenses
Operating and maintenance expense (income)	(6,251		)	25,908			49,319			69,262
Depreciation expense	21,638			16,189			59,561			48,962
Development expense	4,935			11,544			37,640			38,919
General and administrative expense	97,332			74,255			263,205			215,783
Other	479			75			920			245
Total operating costs and expenses	118,133			127,971			410,645			373,171
Loss from operations	(52,074		)	(61,164		)	(208,192		)	(171,169		)
Other income (expense)
Interest expense, net of capitalized interest	(93,566		)	(46,884		)	(238,664		)	(130,943		)
Loss on early extinguishment of debt	—			—			(96,273		)	(114,335		)
Derivative gain (loss), net	(161,482		)	5,379			(242,123		)	(89,222		)
Other income (expense)	(39		)	(160		)	616			(39		)
Total other expense	(255,087		)	(41,665		)	(576,444		)	(334,539		)
Loss before income taxes and non-controlling interest	(307,161		)	(102,829		)	(784,636		)	(505,708		)
Income tax benefit (expense)	69			(1,971		)	(102		)	(2,147		)
Net loss	(307,092		)	(104,800		)	(784,738		)	(507,855		)
Less: net loss attributable to non-controlling interest	(9,284		)	(15,219		)	(100,726		)	(118,536		)
Net loss attributable to common stockholders	$	(297,808	)	$	(89,581	)	$	(684,012	)	$	(389,319	)
Net loss per share attributable to common stockholders—basic and diluted	$	(1.31	)	$	(0.40	)	$	(3.02	)	$	(1.74	)
Weighted average number of common shares outstanding—basic and diluted	227,126			224,309			226,648			223,710

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

4

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF STOCKHOLDERS’ EQUITY

(in thousands)

(unaudited)

	Total Stockholders’ Equity
	Common Stock					Treasury Stock				Additional Paid-in Capital		Accumulated Deficit			Non-controlling Interest			Total Equity
	Shares		Amount			Shares	Amount
Balance at December 31, 2014	236,745		$	712		10,596	$	(292,752	)	$	2,776,702	$	(2,648,839	)	$	2,665,694		$	2,501,517
Exercise of stock options	67		—			—	—			2,279		—			—			2,279
Issuances of restricted stock	19		—			—	—			—		—			—			—
Forfeitures of restricted stock	(152	)	(1		)	17	—			1		—			—			—
Share-based compensation	—		—			—	—			50,582		—			—			50,582
Shares repurchased related to share-based compensation	(635	)	(3		)	635	(44,305		)	3		—			—			(44,305		)
Excess tax benefit from share-based compensation	—		—			—	—			1,424		—			—			1,424
Equity portion of issuance of convertible notes, net	—		—			—	—			198,326		—			—			198,326
Loss attributable to non-controlling interest	—		—			—	—			—		—			(100,726		)	(100,726		)
Distributions to non-controlling interest	—		—			—	—			—		—			(60,154		)	(60,154		)
Net loss	—		—			—	—			—		(684,012		)	—			(684,012		)
Balance at September 30, 2015	236,044		$	708		11,248	$	(337,057	)	$	3,029,317	$	(3,332,851	)	$	2,504,814		$	1,864,931

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

5

CHENIERE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Nine Months Ended
	September 30,
	2015			2014
Cash flows from operating activities
Net loss	$	(784,738	)	$	(507,855	)
Adjustments to reconcile net loss to net cash used in operating activities:
Non-cash LNG inventory write-downs	17,826			23,505
Depreciation expense	59,561			48,962
Share-based compensation	90,412			84,449
Amortization of debt issuance costs and discount (premium)	36,782			10,971
Loss on early extinguishment of debt	96,273			114,335
Total losses on derivatives, net	208,769			89,286
Net cash used for settlement of derivative instruments	(94,170		)	(19,745		)
Other	1,406			(1,975		)
Changes in restricted cash for certain operating activities	92,589			102,851
Changes in operating assets and liabilities:
Accounts and interest receivable	(2,226		)	(18,899		)
LNG inventory	(22,564		)	(26,908		)
Accounts payable and accrued liabilities	10,656			62,797
Deferred revenue	(3,003		)	(2,955		)
Other, net	17,850			131
Net cash used in operating activities	(274,577		)	(41,050		)
Cash flows from investing activities
Property, plant and equipment, net	(5,747,596		)	(2,047,957		)
Use of restricted cash for the acquisition of property, plant and equipment	5,330,526			1,980,436
Other	(111,518		)	(24,113		)
Net cash used in investing activities	(528,588		)	(91,634		)
Cash flows from financing activities
Proceeds from issuances of long-term debt	6,178,000			2,584,500
Repayments of long-term debt	—			(177,000		)
Debt issuance and deferred financing costs	(519,699		)	(94,220		)
Investment in restricted cash	(5,161,701		)	(2,254,733		)
Distributions and dividends to non-controlling interest	(60,154		)	(59,478		)
Proceeds from exercise of stock options	2,279			9,502
Payments related to tax withholdings for share-based compensation	(44,305		)	(44,516		)
Other	1,424			(557		)
Net cash provided by (used in) financing activities	395,844			(36,502		)
Net decrease in cash and cash equivalents	(407,321		)	(169,186		)
Cash and cash equivalents—beginning of period	1,747,583			960,842
Cash and cash equivalents—end of period	$	1,340,262		$	791,656

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

6

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

NOTE 1—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. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.

Results of operations for the three and nine months ended September 30, 2015 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2015.

For further information, refer to the Consolidated Financial Statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2014.

NOTE 2—RESTRICTED CASH

Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. Restricted cash includes the following:

SPLNG Senior Notes Debt Service Reserve

SPLNG has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of 7.50% Senior Secured Notes due 2016 (the “2016 SPLNG Senior Notes”) and $420.0 million of 6.50% Senior Secured Notes due 2020 (the “2020 SPLNG Senior Notes” and collectively with the 2016 SPLNG Senior Notes, the “SPLNG Senior Notes”). Under the indentures governing the SPLNG Senior Notes (the “SPLNG Indentures”), except for permitted tax distributions, SPLNG may not make distributions until certain conditions are satisfied, including: (1) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (2) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the SPLNG Indentures.

As of September 30, 2015 and December 31, 2014, we classified $53.0 million and $15.0 million, respectively, as current restricted cash for the payment of current interest due. As of both September 30, 2015 and December 31, 2014, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash. These cash accounts are controlled by a collateral trustee; therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets.

SPL Reserve

During 2013, SPL entered into four credit facilities aggregating $5.9 billion(collectively, the “2013 SPL Credit Facilities”). In June 2015, SPL entered into four credit facilities aggregating $4.6 billion(collectively, the “2015 SPL Credit Facilities”), which replaced the 2013 SPL Credit Facilities. Under the terms and conditions of the 2015 SPL Credit Facilities (and previously the 2013 SPL Credit Facilities), SPL is required to deposit all cash received into reserve accounts controlled by a collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the natural gas liquefaction facilities that are being developed and constructed in Cameron Parish, Louisiana (the “SPL Project”); therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets.

During 2013, SPL issued an aggregate principal amount of $2.0 billion, before premium, of 5.625% Senior Secured Notes due 2021 (the “2021 SPL Senior Notes”), $1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 SPL Senior Notes”) and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the “Initial 2023 SPL Senior Notes”). During 2014, SPL issued an aggregate principal amount of $2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 SPL Senior Notes”) and additional 5.625% Senior Secured Notes due 2023 in an aggregate principal amount of $0.5 billion, before premium (the “Additional 2023 SPL Senior Notes” and collectively with the Initial 2023 SPL Senior Notes, the “2023 SPL Senior Notes”). In March 2015, SPL issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 SPL Senior Notes” and

7

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

collectively with the 2021 SPL Senior Notes, the 2022 SPL Senior Notes, the 2023 SPL Senior Notes and the 2024 SPL Senior Notes, the “SPL Senior Notes”). The use of cash proceeds from the SPL Senior Notes is restricted to the payment of liabilities related to the SPL Project; therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets. See Note 7—Long-Term Debt for additional details about our long-term debt.

As of September 30, 2015 and December 31, 2014, we classified $327.2 million and $155.8 million, respectively, as current restricted cash held by SPL for the payment of current liabilities, including interest payments, related to the SPL Project and zero and $457.1 million, respectively, as non-current restricted cash held by SPL for future SPL Project construction costs.

CTPL Reserve

In May 2013, CTPL entered into a $400.0 million term loan facility (the “CTPL Term Loan”). As of September 30, 2015 and December 31, 2014, we classified $11.3 million and $24.9 million, respectively, as current restricted cash held by CTPL for the payment of current liabilities and zero and $11.3 million, respectively, as non-current restricted cash held by CTPL, because the usage and withdrawal of such funds is primarily restricted to the payment of liabilities related to modifications of the 94-mile pipeline which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) in order to enable bi-directional natural gas flow, and for the payment of interest during construction of such modifications. The restricted cash reserved to pay interest during construction is controlled by a collateral agent, and can only be released by the collateral agent upon satisfaction of certain terms and conditions. CTPL is required to pay annual fees to the administrative and collateral agents.

CCH Reserve

In May 2015, CCH entered into a credit facility agreement for an aggregate commitment of approximately $11.5 billion(the “2015 CCH Credit Facility”), comprising approximately $8.4 billion linked to the first stage (“Stage 1”) of the natural gas liquefaction and export facility and pipeline facility near Corpus Christi, Texas (the “CCL Project”) and approximately $3.1 billion linked to the second stage (“Stage 2”) of the CCL Project. Stage 1 includes Trains 1 and 2, two LNG storage tanks, one complete marine berth and second partial berth and all of the project’s necessary infrastructure facilities. The pipeline facility is a 23-mile, 48” natural gas pipeline that will interconnect the Corpus Christi LNG terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline”). Stage 2 includes Train 3, one LNG storage tank and the completion of the second partial berth. Under the terms and conditions of the 2015 CCH Credit Facility, all cash reserved to pay interest during construction is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions and are classified as restricted on our Consolidated Balance Sheets. CCH is required to pay annual fees to the administrative and collateral agents. As of September 30, 2015, we classified $35.6 million and $35.7 million as current restricted cash and non-current restricted cash, respectively, held by CCH.

Other Restricted Cash

As of September 30, 2015 and December 31, 2014, $171.4 million and $250.1 million, respectively, of cash was held by SPLNG, Cheniere Partners and Cheniere Holdings that was restricted to Cheniere.  In addition, as of September 30, 2015 and December 31, 2014, $53.7 million and $35.9 million, respectively, had been classified as current restricted cash, and as of September 30, 2015 and December 31, 2014, $7.1 million and $6.3 million, respectively, had been classified as non-current restricted cash on our Consolidated Balance Sheets due to various other contractual restrictions.

8

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 3—PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consists of LNG terminal costs and fixed assets and other, as follows (in thousands):

	September 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,478,167		$	2,269,429
LNG terminal construction-in-process	12,887,040			7,155,046
LNG site and related costs, net	32,823			9,395
Accumulated depreciation	(397,758		)	(350,497		)
Total LNG terminal costs, net	15,000,272			9,083,373
Fixed assets and other
Computer and office equipment	11,197			7,464
Furniture and fixtures	16,737			10,733
Computer software	64,432			46,882
Leasehold improvements	38,573			36,067
Land	60,984			55,522
Other	65,138			36,881
Accumulated depreciation	(32,083		)	(30,169		)
Total fixed assets and other, net	224,978			163,380
Property, plant and equipment, net	$	15,225,250		$	9,246,753

NOTE 4—DERIVATIVE INSTRUMENTS

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

• commodity derivatives to hedge the exposure to price risk attributable to future: (1) sales of our LNG inventory and (2) purchases of natural gas to operate the Sabine Pass LNG terminal (“Natural Gas Derivatives”);

• commodity derivatives consisting of natural gas purchase agreements and associated economic hedges to secure natural gas feedstock for the SPL Project(“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”);

• interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 SPL Credit Facilities (and previously the 2013 SPL Credit Facilities) (“SPL Interest Rate Derivatives”); and

• interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 CCH Credit Facility(“CCH Interest Rate Derivatives” and, collectively with the SPL Interest Rate Derivatives, the “Interest Rate Derivatives”).

None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations.

9

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2015										December 31, 2014
	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
Natural Gas Derivatives asset	$	—	$	97		$	—	$	97		$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset	—		—			32,546		32,546			—		—			342		342
LNG Trading Derivatives asset	—		113			—		113			—		—			—		—
SPL Interest Rate Derivatives liability	—		(15,738		)	—		(15,738		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives liability	—		(143,092		)	—		(143,092		)	—		—			—		—

The estimated fair values of our Natural Gas Derivatives and the economic hedges related to the LNG Trading Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. We value the Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data.

The fair value of substantially all of the Liquefaction Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of the Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of the Liquefaction Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a particular Liquefaction Supply Derivatives contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, the fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. Internal fair value models that include contractual pricing with a fixed basis include fixed basis amounts for delivery at locations for which no market currently exists. Internal fair value models also include conditions precedent to the respective long-term natural gas purchase agreements. As of September 30, 2015 and December 31, 2014, some of the Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. In the absence of infrastructure to accommodate marketable physical gas flow, our internal fair value models are based on a market price that equates to our own contractual pricing due to: (1) the inactive and unobservable market and (2) conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of the Liquefaction Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas purchase agreements as of the reporting date.

10

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

There were no transfers into or out of Level 3 Liquefaction Supply Derivatives for the three and nine months ended September 30, 2015 and 2014. As all of the physical Liquefaction Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2015:

	Net Fair Value Asset (in thousands)	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$32,546	Income Approach	Basis Spread	$ (0.350) - $0.050

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 net settlement. 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.

Commodity Derivatives

We recognize all commodity derivative instruments, including our Natural Gas Derivatives, Liquefaction Supply Derivatives and LNG Trading Derivatives(collectively, “Commodity Derivatives”), as either assets or liabilities and measure those instruments at fair value.  Changes in the fair value of our Commodity Derivatives are reported in earnings.

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

	September 30, 2015										December 31, 2014
	Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total
Balance Sheet Location
Other current assets	$	97	$	2,371		$	—	$	2,468		$	219	$	76		$	—	$	295
Non-current derivative assets	—		30,657			113		30,770			—		586			—		586
Total derivative assets	97		33,028			113		33,238			219		662			—		881
Derivative liabilities	—		(349		)	—		(349		)	—		(53		)	—		(53		)
Non-current derivative liabilities	—		(133		)	—		(133		)	—		(267		)	—		(267		)
Total derivative liabilities	—		(482		)	—		(482		)	—		(320		)	—		(320		)
Derivative asset, net	$	97	$	32,546		$	113	$	32,756		$	219	$	342		$	—	$	561

(1) Does not include collateral of $5.6 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014, respectively.

11

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) shows the changes in the fair value and settlements and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

		Three Months Ended September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives loss	Marketing and trading revenues (losses)	$	(152	)	$	(525	)	$	(260	)	$	(155	)
Natural Gas Derivatives gain (loss)	Operating and maintenance expense (income)	857			194			1,317			(64		)
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense (income)	32,103			—			32,184			—
LNG Trading Derivatives gain	Marketing and trading revenues (losses)	113			—			113			—

(1) There were no physical settlements during the reporting period.

Natural Gas Derivatives

Our Natural Gas Derivatives are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our Natural Gas Derivatives activities.

Liquefaction Supply Derivatives

SPL has entered into index-based physical natural gas supply contracts and associated economic hedges to secure natural gas feedstock for the SPL Project. The terms of the physical contracts range from approximately one to seven years and commence upon the occurrence of conditions precedent, including the date of first commercial operation of specified Trains of the SPL Project. We recognize the Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of the Liquefaction Supply Derivatives are reported in earnings. As of September 30, 2015, SPL has secured up to approximately 2,156.6 millionMMBtu of natural gas feedstock through long-term natural gas purchase agreements, of which the forward notional natural gas buy position of the Liquefaction Supply Derivatives was approximately 1,244.1 millionMMBtu, which were recorded as derivatives due to minimum purchase requirements.

LNG Trading Derivatives

As of September 30, 2015, we have entered into certain LNG Trading Derivatives representing a short position of 1.5 million MMBtu, and we may from time to time enter into certain financial 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 such LNG transactions.

Interest Rate Derivatives

SPL Interest Rate Derivatives

SPL has entered into SPL Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2015 SPL Credit Facilities. The SPL Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 SPL Credit Facilities.

In March 2015, SPL settled a portion of the SPL Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Consolidated Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities as discussed in Note 7—Long-Term Debt. In May 2014, SPL settled a portion of the SPL Interest Rate Derivatives and recognized a derivative loss of $9.3 million within our Consolidated Statements of Operations in conjunction with the early termination of approximately $2.1 billion of commitments under the 2013 SPL Credit Facilities.

12

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

CCH Interest Rate Derivatives

In February 2015, CCH entered into CCH Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2015 CCH Credit Facility. The CCH Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 CCH Credit Facility. The CCH Interest Rate Derivatives have a seven-year term and were contingent upon reaching a final investment decision with respect to the CCL Project, which was reached in May 2015. Upon meeting the contingency related to the CCH Interest Rate Derivatives in May 2015, we paid $50.1 million related to contingency and syndication premiums, which is included in derivative gain (loss), net on our Consolidated Statements of Operations.

As of September 30, 2015, we had the following Interest Rate Derivatives outstanding:

	Initial Notional Amount	Maximum Notional Amount	Effective Date	Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
SPL Interest Rate Derivatives	$20.0 million	$628.8 million	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
CCH Interest Rate Derivatives	$28.8 million	$5.5 billion	May 20, 2015	May 31, 2022	2.29%	One-month LIBOR

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

	September 30, 2015									December 31, 2014
	SPL Interest Rate Derivatives			CCH Interest Rate Derivatives			Total			SPL Interest Rate Derivatives			CCH Interest Rate Derivatives		Total
Balance Sheet Location
Non-current derivative assets	$	—		$	—		$	—		$	11,158		$	—	$	11,158
Derivative liabilities	(7,039		)	(26,451		)	(33,490		)	(23,194		)	—		(23,194		)
Non-current derivative liabilities	(8,699		)	(116,641		)	(125,340		)	—			—		—
Total derivative liabilities	(15,738		)	(143,092		)	(158,830		)	(23,194		)	—		(23,194		)
Derivative liability, net	$	(15,738	)	$	(143,092	)	$	(158,830	)	$	(12,036	)	$	—	$	(12,036	)

The following table (in thousands) shows the changes in the fair value and settlements of the Interest Rate Derivatives, including contingency and syndication premiums related to the CCH Interest Rate Derivatives, recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2015			2014		2015			2014
SPL Interest Rate Derivatives gain (loss)	$	(10,872	)	$	5,379	$	(46,541	)	$	(89,222	)
CCH Interest Rate Derivatives loss	(150,610		)	—		(195,582		)	—

13

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Balance Sheet Presentation

Our Commodity Derivatives and Interest Rate Derivatives are presented on a net basis on our Consolidated Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:

	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 September 30, 2015
Natural Gas Derivatives	$	513		$	(416	)	$	97
Liquefaction Supply Derivatives	33,028			—			33,028
Liquefaction Supply Derivatives	(482		)	—			(482		)
LNG Trading Derivatives	113			—			113
SPL Interest Rate Derivatives	(15,738		)	—			(15,738		)
CCH Interest Rate Derivatives	(143,092		)	—			(143,092		)
As of December 31, 2014
Natural Gas Derivatives	223			(4		)	219
Liquefaction Supply Derivatives	662			—			662
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	11,158			—			11,158
SPL Interest Rate Derivatives	(23,194		)	—			(23,194		)

NOTE 5—NON-CONTROLLING INTEREST

Cheniere Holdings was formed by us to hold our limited partner interest in Cheniere Partners and in December 2013, completed its initial public offering. Additionally, in November 2014, Cheniere Holdings sold 10.1 million common shares at $22.76 per common share to redeem from us the same number of common shares. As of both September 30, 2015 and December 31, 2014, our ownership interest in Cheniere Holdings was 80.1%, with the remaining non-controlling interest held by the public. Cheniere Holdings owns a 55.9% limited partner interest in Cheniere Partners in the form of 12.0 million common units, 45.3 million Class B units and 135.4 million subordinated units, with the remaining non-controlling interest held by Blackstone CQP Holdco LP and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners.

NOTE 6—ACCRUED LIABILITIES

As of September 30, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	170,254	$	112,858
Compensation and benefits	83,581		6,425
Liquefaction Project costs	181,219		22,014
LNG terminal costs	5,987		1,077
Other accrued liabilities	16,860		26,755
Total accrued liabilities	$	457,901	$	169,129

14

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

NOTE 7—LONG-TERM DEBT

As of September 30, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands): 

	Interest	September 30,			December 31,
	Rate	2015			2014
Long-term debt
2016 SPLNG Senior Notes	7.500%	$	1,665,500		$	1,665,500
2020 SPLNG Senior Notes	6.500%	420,000			420,000
2021 SPL Senior Notes	5.625%	2,000,000			2,000,000
2022 SPL Senior Notes	6.250%	1,000,000			1,000,000
2023 SPL Senior Notes	5.625%	1,500,000			1,500,000
2024 SPL Senior Notes	5.750%	2,000,000			2,000,000
2025 SPL Senior Notes	5.625%	2,000,000			—
2015 SPL Credit Facilities (1)	(2)	250,000			—
2021 Cheniere Convertible Unsecured Notes	4.875%	1,028,953			1,004,469
2025 CCH HoldCo II Convertible Senior Notes	11.000%	1,003,667			—
2045 Cheniere Convertible Senior Notes	4.250%	625,000			—
CTPL Term Loan (3)	(4)	400,000			400,000
2015 CCH Credit Facility (5)	(6)	2,428,000			—
SPL Working Capital Facility (7)	(8)	—			—
Total long-term debt		16,321,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(5,477		)	(8,998		)
2021 SPL Senior Notes		9,090			10,177
2023 SPL Senior Notes		6,570			7,088
2021 Cheniere Convertible Unsecured Notes		(174,133		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(319,579		)	—
CTPL Term Loan		(1,681		)	(2,435		)
Total long-term debt, net		$	15,835,910		$	9,806,084

(1) Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the SPL Project.

(2) Variable interest rate, at SPL’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

(3) Matures on May 28, 2017 when the full amount of the outstanding principal obligations must be repaid.

(4) Variable interest rate, at CTPL’s election, is LIBOR or the base rate plus the applicable margin. CTPL has historically elected LIBOR loans, for which the applicable margin is 3.25% and is due and payable at the end of each LIBOR period.

(5) Matures on the earlier of May 13, 2022 or the second anniversary of the completion date of the first two Trains of the CCL Project.

(6) Variable interest rate, at CCH’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion of the first two Trains of the CCL Project and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion of the first two Trains of the CCL Project and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period, and interest on base rate loans is due and payable at the end of each quarter.

(7) Matures on December 31, 2020, with various terms for underlying loans, as further described below under SPL Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the SPL Working Capital Facility or the SPL LC Agreement it replaced.

(8) Variable interest rates, based on LIBOR or the base rate, as further described below under SPL Working Capital Facility.

For the three months ended September 30, 2015 and 2014, we incurred $286.0 million and $154.8 million of total interest cost, respectively, of which we capitalized and deferred $192.4 million and $107.9 million, respectively, including amortization

15

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

of debt issuance costs, primarily related to the construction of the SPL Project in both periods and additionally the CCL Project in 2015. For the nine months ended September 30, 2015 and 2014, we incurred $707.8 million and $423.8 million of total interest cost, respectively, of which we capitalized and deferred $469.2 million and $292.8 million, respectively, including amortization of debt issuance costs, primarily related to this construction.

SPLNG Senior Notes

Under the SPLNG Indentures, except for permitted tax distributions, SPLNG may not make distributions until certain conditions are satisfied as described in Note 2—Restricted Cash. During the nine months ended September 30, 2015 and 2014, SPLNG made distributions of $267.9 million and $237.7 million, respectively, after satisfying all the applicable conditions in the SPLNG Indentures.

SPL Senior Notes

In March 2015, SPL issued an aggregate principal amount of $2.0 billion of the 2025 SPL Senior Notes, for which borrowings accrue interest at a fixed rate of 5.625%. The terms of the 2025 SPL Senior Notes are governed by the same common indenture with the other SPL Senior Notes. In connection with the closing of the sale of the 2025 SPL Senior Notes, SPL entered into a Registration Rights Agreement dated March 3, 2015 (the “2025 SPL Registration Rights Agreement”). Under the terms of the 2025 SPL Registration Rights Agreement, SPL has agreed, and any future guarantors of the 2025 SPL Senior Notes will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective a registration statement within 360 days after March 3, 2015 with respect to an offer to exchange any and all of the 2025 SPL Senior Notes for a like aggregate principal amount of debt securities of SPL with terms identical in all material respects to the respective 2025 SPL Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), and that are registered under the Securities Act of 1933, as amended (the “Securities Act”). Under specified circumstances, SPL has also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 2025 SPL Senior Notes. SPL will be obligated to pay additional interest if it fails to comply with its obligations to register the 2025 SPL Senior Notes within the specified time period.

2015 SPL Credit Facilities

In June 2015, SPL entered into the 2015 SPL Credit Facilities with commitments aggregating $4.6 billion. The 2015 SPL Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the SPL Project. Borrowings under the 2015 SPL Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, SPL had $4.3 billion of available commitments and $250.0 million of outstanding borrowings under the 2015 SPL Credit Facilities.

SPL incurred $88.2 million of debt issuance costs in connection with the 2015 SPL Credit Facilities. In addition to interest, SPL is required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 SPL Credit Facilities.  The 2015 SPL Credit Facilities also require SPL to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment, or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 SPL Credit Facility. The principal of the loans made under the 2015 SPL Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the SPL Project. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2015 SPL Credit Facilities.

The 2015 SPL Credit Facilities contain conditions precedent for borrowings, as well as customary affirmative and negative covenants. The obligations of SPL under the 2015 SPL Credit Facilities are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and the Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “SPL Working Capital Facility”) described below.

Under the terms of the 2015 SPL Credit Facilities, SPL is required to hedge not less than 65% of the variable interest rate exposure of its projected outstanding borrowings, calculated on a weighted average basis in comparison to its anticipated draw of principal.

16

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

2013 SPL Credit Facilities

 In May 2013, SPL entered into the 2013 SPL Credit Facilities to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 4 of the SPL Project. As of December 31, 2014, SPL had no outstanding borrowings under the 2013 SPL Credit Facilities. In June 2015, the 2013 SPL Credit Facilities were replaced with the 2015 SPL Credit Facilities.

In March 2015, in conjunction with SPL’s issuance of the 2025 SPL Senior Notes, SPL terminated approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities. This termination and the replacement of the 2013 SPL Credit Facilities with the 2015 SPL Credit Facilities in June 2015 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 SPL Credit Facilities of $96.3 million for the nine months ended September 30, 2015.

Convertible Notes

2021 Cheniere Convertible Unsecured Notes

In November 2014, we issued an aggregate principal amount of $1.0 billion Convertible Unsecured Notes due 2021 (the “2021 Cheniere Convertible Unsecured Notes”) on a private placement basis in reliance on the exemption from registration provided for under section 4(a)(2) of the Securities Act and Regulation S promulgated thereunder. The 2021 Cheniere Convertible Unsecured Notes accrue interest at a rate of 4.875% per annum, which is payable in kind semi-annually in arrears by increasing the principal amount of the 2021 Cheniere Convertible Unsecured Notes outstanding. One year after the closing date, the 2021 Cheniere Convertible Unsecured Notes will be 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 conversion date. The initial conversion price was $93.64 and is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

Under GAAP, certain convertible debt instruments that may be settled in cash upon conversion are required to be separately accounted for as liability (debt) and equity (conversion option) components of the instrument in a manner that reflects the issuer’s non-convertible debt borrowing rate. We determined that the fair value of the debt component was $808.8 million and the residual value of the equity component was $191.2 million as of the issuance date. As of September 30, 2015 and December 31, 2014, the carrying value of the equity component was $196.1 million and $191.9 million, respectively. The debt component is accreted to the total principal amount due at maturity by amortizing the debt discount. The effective rate of interest to amortize the debt discount was approximately 9.1% and 9.2% as of September 30, 2015 and December 31, 2014, respectively, and the remaining period over which the debt discount will be amortized was 5.7 years as of September 30, 2015. As of September 30, 2015, the if-converted value of the 2021 Cheniere Convertible Unsecured Notes did not exceed the principal balance.

2025 CCH HoldCo II Convertible Senior Notes

In May 2015, CCH HoldCo II issued $1.0 billion aggregate principal amount of 11% Senior Secured Notes due 2025 (the “2025 CCH HoldCo II Convertible Senior Notes”) on a private placement basis in reliance on the exemption from registration provided for under section 4(a)(2) of the Securities Act. The 2025 CCH HoldCo II Convertible Senior Notes were issued pursuant to the amended and restated note purchase agreement entered into among CCH HoldCo II, EIG Management Company, LLC, The Bank of New York Mellon, the Company and the note purchasers. The $1.0 billion principal of the 2025 CCH HoldCo II Convertible Senior Notes will be used to partially fund costs associated with Stage 1 of the CCL Project and the Corpus Christi Pipeline. The purchasers have made commitments, which will expire on May 1, 2016, to acquire an additional $500 million of 2025 CCH HoldCo II Convertible Senior Notes(the “Second Phase Funding”) upon satisfaction of incremental customary conditions precedent related to the construction of Stage 2 of the CCL Project. The 2025 CCH HoldCo II Convertible Senior Notes bear interest at a rate of 11.0% per annum, which is payable quarterly in arrears. Prior to the substantial completion of Train 2 of the CCL Project, if the Second Phase Funding has not occurred, and to the substantial completion of Train 3 of the CCL Project following the occurrence of the Second Phase Funding, interest on the 2025 CCH HoldCo II Convertible Senior Notes will be paid entirely in kind. Following this date, the interest generally must be paid in cash; however, a portion of the interest may be paid in kind under certain specified circumstances. 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.

17

CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

At CCH HoldCo II’s option, the outstanding 2025 CCH HoldCo II Convertible Senior Notes are convertible into our common stock on or after the later of (1) 58 months from May 1, 2015, and (2) the substantial completion of Train 2 of the CCL Project and any 2025 CCH HoldCo II Convertible Senior Notes issued in connection with the Second Phase Funding will be convertible on or after the substantial completion of Train 3 of the CCL Project(in each case, the “Eligible Conversion Date”). The conversion price for 2025 CCH HoldCo II Convertible Senior Notes converted at CCH HoldCo II’s option is 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. At the option of the holders, the 2025 CCH HoldCo II Convertible Senior Notes are convertible on or after the six-month anniversary of the applicable Eligible Conversion Date at a conversion 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. Conversions are also subject to various limitations and conditions. As of September 30, 2015, the value of the 2025 CCH HoldCo II Convertible Senior Notes if converted at the holders’ option did not exceed the principal balance.

2045 Cheniere Convertible Senior Notes

In March 2015, we issued $625.0 million aggregate principal amount of 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to certain investors through a registered direct offering. The 2045 Cheniere Convertible Senior Notes were issued with an original issue discount of 20% and accrue interest at a rate of 4.25% per annum, which is payable semi-annually in arrears. 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 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. 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. The conversion rate is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

We determined that the fair value of the debt component of the 2045 Cheniere Convertible Senior Notes was $304.3 million and the residual value of the equity component was $195.7 million as of the issuance date, excluding debt issuance costs. As of September 30, 2015, the carrying value of the equity component was $194.1 million. The debt component is accreted to the total principal amount due at maturity by amortizing the debt discount. The effective rate of interest to amortize the debt discount was approximately 9.4% as of September 30, 2015, and the remaining period over which the debt discount will be amortized was 29.5 years. As of September 30, 2015, the if-converted value of the 2045 Cheniere Convertible Senior Notes did not exceed the principal balance.

Interest expense, before capitalization, related to the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes(together, the “Convertible Notes”) consisted of the following (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Interest per contractual rate	$	46,782	$	—	$	97,991	$	—
Amortization of debt discount	7,233		—		20,948		—
Amortization of debt issuance costs	1,133		—		1,748		—
Total interest expense related to the Convertible Notes	$	55,148	$	—	$	120,687	$	—

CTPL Term Loan

As of September 30, 2015, CTPL had borrowed the full amount of $400.0 million available under the CTPL Term Loan. The outstanding balance may be repaid, in whole or in part, at any time without premium or penalty.

2015 CCH Credit Facility

In May 2015, CCH entered into the 2015 CCH Credit Facility, which is being used to fund a portion of the costs associated with the development, construction, operation and maintenance of the CCL Project.  The total commitment under the 2015 CCH Credit Facility is approximately $11.5 billion, comprising approximately $8.4 billion linked to Stage 1 of the CCL Project and the

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

Corpus Christi Pipeline and approximately $3.1 billion linked to Stage 2 of the CCL Project. Borrowings under the 2015 CCH Credit Facility may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, CCH had $6.0 billion of available commitments and $2.4 billion of outstanding borrowings under the 2015 CCH Credit Facility.

CCH incurred $289.8 million of debt issuance costs in connection with the 2015 CCH Credit Facility. In addition to interest, CCH will incur a commitment fee at a rate per annum equal to 40% of the margin for LIBOR loans, multiplied by the outstanding undrawn debt commitments. The principal of the loans made under the 2015 CCH Credit Facility must be repaid in quarterly installments, commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following project completion and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train 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 project completion and designed to achieve a minimum projected fixed debt service coverage ratio of 1.55:1.

The 2015 CCH Credit Facility contains conditions precedent for borrowings, as well as customary affirmative and negative covenants. The obligations of CCH under the 2015 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.

Under the terms of the 2015 CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt.

SPL Working Capital Facility

In September 2015, SPL entered into a $1.2 billionSPL Working Capital Facility, which replaced the $325.0 million Senior Letter of Credit and Reimbursement Agreement that was entered into in April 2014 (the “SPL LC Agreement”). The SPL Working Capital Facility is intended to be used for loans to SPL (“Working Capital Loans”), the issuance of letters of credit on behalf of SPL (“Letters of Credit”), as well as for swing line loans to SPL (“Swing Line Loans”), primarily for certain working capital requirements related to developing and placing into operation the SPL Project. SPL may, from time to time, request increases in the commitments under the 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 million. As of September 30, 2015, SPL had $1.1 billion of available commitments, $127.6 million aggregate amount of issued Letters of Credit and noWorking Capital Loans, Swing Line Loans or loans deemed made in connection with a draw upon a Letter of Credit (“LC Loans” and collectively with Working Capital Loans and Swing Line Loans, the “SPL Working Capital Facility Loans”) outstanding under the SPL Working Capital Facility. As of December 31, 2014, SPL had issued letters of credit in an aggregate amount of $9.5 million, and no draws had been made upon any letters of credit issued under the SPL LC Agreement.

SPL Working Capital Facility Loans 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 one month LIBOR plus 0.50%), plus the applicable margin. The applicable margin for LIBOR SPL Working Capital Facility Loans is 1.75% per annum, and the applicable margin for base rate SPL Working Capital Facility Loans is 0.75% per annum. Interest on Swing Line Loans and LC Loans is due and payable on the date the loan becomes due. Interest on LIBOR Working Capital Loans is due and payable at the end of each applicable LIBOR period, and interest on base rate Working Capital Loans is due and payable at the end of each fiscal quarter. However, if such base rate Working Capital Loan is converted into a LIBOR Working Capital Loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date.

SPL incurred $27.5 million of debt issuance costs in connection with the SPL Working Capital Facility. SPL pays (1) a commitment fee on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans in an amount equal to an annual rate of 0.70% and (2) a Letter of Credit fee equal to an annual rate of 1.75% of the undrawn portion of all Letters of Credit issued under the SPL Working Capital Facility. If draws are made upon a Letter of Credit issued under the SPL Working Capital Facility and SPL does not elect for such draw (an “LC Draw”) to be deemed an LC Loan, SPL is required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw. An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of September 30, 2015, noLC Draws had been made upon any Letters of Credit issued under the SPL Working Capital Facility.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The SPL Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year. 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 Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. SPL is required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The SPL Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of SPL under the SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and 2015 SPL Credit Facilities.

Fair Value Disclosures

The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:

	September 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,660,023	$	1,684,923	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		410,550		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,090		1,853,386		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		930,000		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,570		1,344,614		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,765,000		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,755,000		—		—
2015 SPL Credit Facilities (2)	250,000		250,000		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	854,820		894,160		814,751		1,025,563
2025 CCH HoldCo II Convertible Senior Notes (3)	1,003,667		900,490		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	305,421		390,263		—		—
CTPL Term Loan, net of discount (2)	398,319		400,000		397,565		400,000
2015 CCH Credit Facility (2)	2,428,000		2,428,000		—		—
SPL Working Capital Facility (2)	—		—		—		—

(1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014, as applicable.

(2) 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. 

(3) 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. 

(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.

NOTE 8—INCOME TAXES

We are not presently a taxpayer for federal or state income tax purposes and have not recorded a net liability for federal or state income taxes in any of the periods included in the accompanying Consolidated Financial Statements. However, we are presently an international taxpayer and have recorded a net (benefit) of $(0.1) million and a net expense of $2.0 million for the three months ended September 30, 2015 and 2014, respectively, and a net expense of $0.1 million and $2.1 million for the nine months ended September 30, 2015 and 2014, respectively, for international income taxes.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

We experienced an ownership change within the provisions of Internal Revenue Code (“IRC”) Section 382 in 2008, 2010 and 2012. An analysis of the annual limitation on the utilization of our net operating losses (“NOLs”) was performed in accordance with IRC Section 382. It was determined that IRC Section 382 will not limit the use of our NOLs in full over the carryover period. We will continue to monitor trading activity in our shares which may cause an additional ownership change which could ultimately affect our ability to fully utilize our existing tax NOL carryforwards.

NOTE 9—SHARE-BASED COMPENSATION

We have granted stock, restricted stock, phantom units and options to purchase common stock to employees, outside directors and a consultant under the Cheniere Energy, Inc. Amended and Restated 1997 Stock Option Plan (the “1997 Plan”), Amended and Restated 2003 Stock Incentive Plan, as amended (the “2003 Plan”), 2011 Incentive Plan, as amended (the “2011 Plan”), and the 2014-2018 Long-Term Cash Incentive Program (the “2014-2018 LTIP”).

The 1997 Plan provides for the issuance of stock options to purchase up to 5.0 million shares of our common stock, all of which have been granted. Non-qualified stock options were granted to employees, contract service providers and outside directors. The 2003 Plan and 2011 Plan provide for the issuance of 21.0 million shares and 35.0 million shares, respectively, of our common stock that may be in the form of non-qualified stock options, incentive stock options, purchased stock, restricted (non-vested) stock, bonus (unrestricted) stock, stock appreciation rights, phantom units and other share-based performance awards deemed by the compensation committee of our board of directors (the “Compensation Committee”) to be consistent with the purposes of the 2003 Plan and the 2011 Plan. As of September 30, 2015, all of the shares under the 2003 Plan have been granted and 26.9 million shares, net of cancellations, have been granted under the 2011 Plan.

In April 2015, the Compensation Committee recommended and our board of directors approved the Company’s 2015 Long-Term Cash Incentive Plan, including its sub-plan, the 2014-2018 LTIP. The 2014-2018 LTIP consists of phantom units settled in cash with five consecutive annual performance periods commencing on November 1 and ending on October 31 of each year through October 31, 2018. Awards under the 2014-2018 LTIP will be subject to a three-year vesting schedule, with one third of the phantom units vesting and becoming payable on each of the first, second and third anniversaries of the date of the grant (with the exception of the initial grant for the 2014 performance period, which will vest and become payable on each of February 1, 2016, February 1, 2017 and February 1, 2018). The 2014-2018 LTIP is 100% performance-based and will reward long-term performance measured against growth in the Company’s market capitalization, referred to in the plan documents as total shareholder value (“TSV”), above certain thresholds. Under the 2014-2018 LTIP, the general pool is targeted to be awarded between 2% and 4% of the growth in TSV and the senior executive pool is capped at 2% of the growth in TSV, with the Chief Executive Officer’s compensation targeted at 50% of the senior executive pool, subject to adjustment at the discretion of the Compensation Committee. The number of phantom units comprising the senior executive pool has also been capped, and cannot exceed an amount equal to 1.5% of the shares of our common stock outstanding in any one year.

Phantom units are share-based awards granted to employees over a vesting period that entitle the grantee to receive the cash equivalent to the value of a share of our common stock upon each vesting. Phantom units are not eligible to receive quarterly distributions. The Company initially measures compensation cost based on the Company’s stock price on the grant date, which is included in accrued liabilities on our Consolidated Balance Sheets, and is adjusted quarterly for any changes in the Company’s stock price and period of service rendered. During the three and nine months ended September 30, 2015, we granted 0.1 million and 5.7 million phantom units, respectively, to employees, including units awarded under the 2014-2018 LTIP. We did not grant any phantom units to employees during the three and nine months ended September 30, 2014.

For the three months ended September 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $26.2 million and $22.5 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $1.3 million and $2.2 million, respectively. For the nine months ended September 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $92.6 million and $84.4 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $21.5 million and $6.6 million, respectively.

The total unrecognized compensation cost at September 30, 2015 relating to non-vested share-based compensation arrangements was $316.2 million, which is expected to be recognized over a weighted average period of 2.3 years.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

We received $0.4 million and $3.1 million in the three months ended September 30, 2015 and 2014, respectively, and $2.3 million and $9.5 million in the nine months ended September 30, 2015 and 2014, respectively, of proceeds from the exercise of stock options.

During the three and nine months ended September 30, 2014, we recognized zero and $10.8 million, respectively, of share-based compensation expense related to the modification of long-term commercial bonus awards resulting from an employee termination. We did not recognize any share-based compensation expense related to such modifications in the three and nine months ended September 30, 2015.

NOTE 10—NET LOSS PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

Basic net loss per share attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net 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 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 following table (in thousands, except for loss per share) reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	227,126			224,309			226,648			223,710
Dilutive common stock options (1)	—			—			—			—
Diluted	227,126			224,309			226,648			223,710
Basic and diluted net loss per share attributable to common stockholders	$	(1.31	)	$	(0.40	)	$	(3.02	)	$	(1.74	)

(1) Stock options and unvested stock of 8.6 million shares and 13.0 million shares for the three months ended September 30, 2015 and 2014, respectively, and 8.6 million shares and 12.8 million shares for the nine months ended September 30, 2015 and 2014, respectively, representing securities that could potentially dilute basic EPS in the future, were not included in the diluted net loss per share computations because their effect would have been anti-dilutive. In addition, 56.2 million shares in aggregate, issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes, as described in Note 7—Long-Term Debt, were not included in the computation of diluted net loss per share for the three and nine months ended September 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

NOTE 11—COMMITMENTS AND CONTINGENCIES

Legal Proceedings

During the second quarter of 2014, four lawsuits were filed in the Court of Chancery of the State of Delaware (the “Court”) against us and/or certain of our present and former officers and directors that challenged the manner in which abstentions were treated in connection with the stockholder vote on Amendment No. 1 to the 2011 Plan(“Amendment No. 1”), pursuant to which, among other things, the number of shares of common stock available for issuance under the 2011 Plan was increased from 10.0 million to 35.0 million shares. The lawsuits contended that abstentions should have been counted as “no” votes in tabulating the outcome of the vote and that the stockholders did not approve Amendment No. 1 when abstentions are counted as such. The lawsuits further contended that portions of the Amended and Restated Bylaws of Cheniere Energy, Inc. adopted on April 3, 2014 were invalid and that certain disclosures relating to these matters made by us were misleading. The lawsuits asserted claims for breach of contract and breach of fiduciary duty (both on a class and a derivative basis) and claims for unjust enrichment (on a derivative basis). The lawsuits sought, among other things, a declaration that the February 1, 2013 stockholder vote on Amendment No. 1 was void, disgorgement of all compensation distributed as a result of Amendment No. 1, voiding the awards made from the shares reserved pursuant to Amendment No. 1 and monetary damages. On June 16, 2014, we filed a verified application with the Court pursuant to 8 Del. C. § 205 (the “Section 205 Action”) in which we asked the Court to declare valid the issuance, pursuant

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

to the 2011 Plan, of the 25.0 million additional shares of our common stock covered by Amendment No. 1, whether occurring in the past or the future.

The parties to the above-referenced lawsuits and the Section 205 Action entered into a Stipulation and Agreement of Compromise, Settlement and Release dated December 12, 2014, subject to its terms and conditions, including receipt, among other things, of Court approval, to resolve the litigation. On March 16, 2015, the Court approved the settlement of the litigation and awarded plaintiffs’ counsel fees, which were paid by our insurers in April 2015.

Obligations under Certain Guarantee Contracts

Cheniere and certain of its subsidiaries enter into guarantee arrangements in the normal course of business to facilitate transactions with third parties. These arrangements include financial guarantees, letters of credit and debt guarantees. As of September 30, 2015 and December 31, 2014, there were no liabilities recognized under these guarantee arrangements.

NOTE 12—BUSINESS SEGMENT INFORMATION

We have two reportable segments: LNG terminal segment and LNG and natural gas marketing segment. We determine our reportable segments by identifying each segment that engaged in business activities from which it may earn revenues and incur expenses, had operating results regularly reviewed by the entities’ chief operating decision maker for purposes of resource allocation and performance assessment, and had discrete financial information. Substantially all of our revenues from external customers are attributed to the United States. Substantially all of our long-lived assets are located in the United States.

Our LNG terminal segment consists of the Sabine Pass and Corpus Christi LNG terminals. We own and operate the Sabine Pass LNG terminal located on the Sabine Pass shipping channel in Louisiana through our ownership interest in and management agreements with Cheniere Partners. We own 100% of the general partner interest in Cheniere Partners and 80.1% of the common shares of Cheniere Holdings, which owns a 55.9% limited partner interest in Cheniere Partners. We are also developing and constructing a natural gas liquefaction facility near Corpus Christi, Texas.

Our LNG and natural gas marketing segment consists of LNG and natural gas marketing activities by Cheniere Marketing. Cheniere Marketing is developing a platform for LNG sales to international markets with professional staff based in the United States, United Kingdom, Singapore and Chile.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

The following table (in thousands) summarizes revenues (losses), loss from operations and total assets for each of our reporting segments: 

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	67,212		$	(1,557	)	$	404		$	66,059
Intersegment revenues (losses) (3)	233			11,354			(11,587		)	—
Depreciation expense	16,775			320			4,543			21,638
Income (loss) from operations	27,072			(27,117		)	(52,029		)	(52,074		)
Interest expense, net of capitalized interest	(67,589		)	(14		)	(25,963		)	(93,566		)
Loss before income taxes and non-controlling interest (4)	(196,693		)	(27,665		)	(82,803		)	(307,161		)
Share-based compensation	1,316			2,051			24,084			27,451
Goodwill	76,819			—			—			76,819
Total assets	16,784,317			552,752			1,115,190			18,452,259
Expenditures for additions to long-lived assets	1,429,808			403			21,258			1,451,469
As of or for the Three Months Ended September 30, 2014
Revenues (losses) from external customers (2)	$	66,983		$	(500	)	$	324		$	66,807
Intersegment revenues (losses) (3)	607			17,262			(17,869		)	—
Depreciation expense	14,817			103			1,269			16,189
Loss from operations	(28,482		)	(6,652		)	(26,030		)	(61,164		)
Interest expense, net of capitalized interest	(46,996		)	—			112			(46,884		)
Loss before income taxes and non-controlling interest (4)	(64,886		)	(7,130		)	(30,813		)	(102,829		)
Share-based compensation	3,278			8,281			13,096			24,655
Goodwill	76,819			—			—			76,819
Total assets	10,847,861			65,536			871,919			11,785,316
Expenditures for additions to long-lived assets	695,159			486			21,895			717,540
For the Nine Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	203,324		$	(1,601	)	$	730		$	202,453
Intersegment revenues (losses) (3)	827			24,725			(25,552		)	—
Depreciation expense	47,787			764			11,010			59,561
Loss from operations	(15,324		)	(58,667		)	(134,201		)	(208,192		)
Interest expense, net of capitalized interest	(169,899		)	(14		)	(68,751		)	(238,664		)
Loss before income taxes and non-controlling interest (4)	(507,751		)	(59,871		)	(217,014		)	(784,636		)
Share-based compensation	30,233			12,138			71,736			114,107
Expenditures for additions to long-lived assets	5,964,244			2,517			70,913			6,037,674
For the Nine Months Ended September 30, 2014
Revenues from external customers (2)	$	200,243		$	482		$	1,277		$	202,002
Intersegment revenues (losses) (3)	2,113			21,336			(23,449		)	—
Depreciation expense	44,033			364			4,565			48,962
Loss from operations	(56,863		)	(33,153		)	(81,153		)	(171,169		)
Interest expense, net of capitalized interest	(131,264		)	—			321			(130,943		)
Loss before income taxes and non-controlling interest (4)	(376,363		)	(34,046		)	(95,299		)	(505,708		)
Share-based compensation	9,840			17,212			63,920			90,972
Expenditures for additions to long-lived assets	2,164,596			1,271			54,120			2,219,987

(1) Includes corporate activities, business development, oil and gas exploration, development and exploitation, strategic activities and certain intercompany eliminations. These activities have been included in the corporate and other column due to the lack of a material impact that these activities have on our Consolidated Financial Statements.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

(2) Substantially all of the LNG terminal revenues relate to regasification capacity reservation fee payments made by Total Gas & Power North America, Inc. and Chevron U.S.A. Inc. LNG and natural gas marketing and trading revenue consists primarily of the domestic marketing of natural gas imported into the Sabine Pass LNG terminal.

(3) Intersegment revenues (losses) related to our LNG and natural gas marketing segment are primarily a result of international revenue allocations using a cost plus transfer pricing methodology. These LNG and natural gas marketing segment intersegment revenues (losses) are eliminated with intersegment revenues (losses) in our Consolidated Statements of Operations.

(4) Items to reconcile loss from operations and loss before income taxes and non-controlling interest include consolidated other income (expense) amounts as presented on our Consolidated Statements of Operations primarily related to our LNG terminal segment.

NOTE 13—SUPPLEMENTAL CASH FLOW INFORMATION

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

	Nine Months Ended September 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	48,271	$	47,152
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	356,306		287,330
Non-cash conveyance of assets	13,169		—

NOTE 14—RECENT ACCOUNTING STANDARDS

In May 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on revenue recognition. The core principle of this amendment is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Earlier adoption is permitted as of annual reporting periods beginning after December 15, 2016. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.

In August 2014, the FASB issued authoritative guidance that requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. This guidance is effective for annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter, with earlier adoption permitted. The adoption of this guidance is not expected to have an impact on our Consolidated Financial Statements or related disclosures.

In February 2015, the FASB amended its guidance on consolidation analysis. This amendment primarily affects asset managers and reporting entities involved with limited partnerships or similar entities, but the analysis is relevant in the evaluation of any reporting organization’s requirement to consolidate a legal entity. This guidance changes (1) the identification of variable interests, (2) the variable interest entity characteristics for a limited partnership or similar entity and (3) the primary beneficiary determination. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.

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CHENIERE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED

(unaudited)

In April 2015, the FASB issued authoritative guidance that requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. In August 2015, the FASB further issued guidance clarifying the SEC staff’s position on presentation and subsequent measurement of debt issuance costs incurred in connection with line of credit arrangements. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance must be adopted retrospectively to each prior reporting period presented and disclosures will be required for a change in accounting principles. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Balance Sheets.

In April 2015, the FASB issued authoritative guidance that clarifies the circumstances under which a cloud computing customer would account for the arrangement as a license of internal-use software. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance may be adopted either retrospectively or prospectively to arrangements entered into, or materially modified, after the effective date. The adoption of this guidance is not expected to have an impact on our Consolidated Financial Statements or related disclosures.

In July 2015, the FASB issued revised guidance related to the measurement of inventory. Inventory would be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption permitted. This guidance should be adopted prospectively. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.

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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, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical facts, 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 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 ability to enter into such transactions;

• statements relating to the construction of our Trains, 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, 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, including the financing of such Trains;

• 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 and capital expenditures, 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; and 

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

All of these types of statements, other than statements of historical fact, are forward-looking statements. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” 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 due to factors described in this quarterly report and in the other reports and other information that we file with the SEC. These forward-looking statements speak only as of the date made, and other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

Our actual results could differ materially from those anticipated in these forward-looking statements as a result of a variety of factors, including those discussed under “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31,

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2014. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these risk factors. Other than as required under the securities laws, we assume no obligation to update or revise these forward-looking statements or provide reasons why actual results may differ.

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 include the following subjects: 

• Overview of Business 

• Overview of Significant Events 

• 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 company primarily engaged in LNG-related businesses. We own and operate the Sabine Pass LNG terminal in Louisiana through our ownership interest in and management agreements with Cheniere Partners, which is a publicly traded limited partnership that we created in 2007. We own 100% of the general partner interest in Cheniere Partners and 80.1% of Cheniere Holdings, which is a publicly traded limited liability company formed in 2013 that owns a 55.9% limited partner interest in Cheniere Partners. We are currently developing and constructing two natural gas liquefaction and export facilities.

The Sabine Pass LNG terminal is located on the Sabine Pass deepwater shipping channel less than four miles from the Gulf Coast. The Sabine Pass LNG terminal has operational regasification facilities owned by Cheniere Partners’ wholly owned subsidiary, SPLNG, that includes existing infrastructure of five LNG storage tanks with capacity of approximately 16.9 Bcfe, two docks that can accommodate vessels with nominal capacity of up to 266,000 cubic meters and vaporizers with regasification capacity of approximately 4.0 Bcf/d. Cheniere Partners is developing and constructing natural gas liquefaction facilities (the “SPL Project”) at the Sabine Pass LNG terminal adjacent to the existing regasification facilities through a wholly owned subsidiary, SPL. Cheniere Partners plans to construct up to six Trains, which are in various stages of development. Each Train is expected to have a nominal production capacity of approximately 4.5 mtpa of LNG. Cheniere Partners also owns a 94-mile pipeline that interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) through a wholly owned subsidiary, CTPL.

We are developing and constructing a second natural gas liquefaction and export facility and pipeline facility on over 1,500 acres of land that we own or control near Corpus Christi, Texas (the “CCL Project”) through wholly owned subsidiaries CCL and CCP, respectively. The Corpus Christi LNG terminal is being developed for up to five Trains, with expected aggregate nominal production capacity of approximately 22.5 mtpa of LNG, four LNG storage tanks with capacity of approximately 13.5 Bcfe and two docks that can accommodate vessels with nominal capacity of up to 266,000 cubic meters. The CCL Project is being developed in stages. 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 and the third stage (“Stage 3”) includes Trains 4 and 5 and one LNG storage tank. The CCL Project also includes a 23-mile, 48” natural gas supply pipeline that will interconnect the Corpus Christi LNG terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline”).

Cheniere Marketing is engaged in the LNG and natural gas marketing business and is seeking to develop a portfolio of long-term, short-term and spot SPAs. Cheniere Marketing has entered into SPAs with SPL and CCL to purchase LNG produced by the SPL Project and the CCL Project.

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We are also in various stages of developing other projects, including a liquid hydrocarbon export project in Texas along the Gulf Coast.

Overview of Significant Events

Our significant accomplishments since January 1, 2015 and through the filing date of this Form 10-Q include the following:  

Cheniere

• We issued an aggregate principal amount of $625.0 million Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) through a registered direct offering. The 2045 Cheniere Convertible Senior Notes were issued with an original issue discount of 20% and accrue interest at a rate of 4.25% per annum, which is payable semi-annually in arrears. The net proceeds of the 2045 Cheniere Convertible Senior Notes are being used for general corporate purposes.

• Cheniere Marketing and CCL received authorization from the DOE to export up to a combined total of the equivalent of 767 Bcf/yr of domestically produced LNG by vessel from the CCL Project to non-FTA countries for a 20-year term.

• CCH entered into a credit facility (the “2015 CCH Credit Facility”) to be used for costs associated with the development, construction, operation and maintenance of the CCL Project, with commitments of $8.4 billion linked to Stage 1 of the CCL Project and the Corpus Christi Pipeline and an additional $3.1 billion linked to Stage 2 of the CCL Project.

• CCH HoldCo II issued $1.0 billion aggregate principal amount of 11% Senior Secured Notes due 2025 (the “2025 CCH HoldCo II Convertible Senior Notes”), which will be used to pay a portion of the capital costs associated with Stage 1 of the CCL Project and the Corpus Christi Pipeline.

• CCL issued a notice to proceed (“NTP”) to Bechtel Oil, Gas and Chemicals, Inc. (“Bechtel”) under the lump sum turnkey contract for the engineering, procurement and construction of Stage 1 of the CCL Project(the “EPC Contract (CCL Stage 1)”).

• We have agreed in principle to partner with Parallax Enterprises, LLC (“Parallax”) to develop up to 11 mtpa of LNG production capacity through Parallax’s two mid-scale natural gas liquefaction projects in Louisiana along the Gulf Coast.

Cheniere Partners

• SPL issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 SPL Senior Notes”). Net proceeds from the offering will be used to pay a portion of the capital costs associated with the construction of the first four Trains of the SPL Project.

• We received authorization from the FERC to site, construct and operate Trains 5 and 6 of the SPL Project.

• SPL received authorization from the DOE to export up to a combined total of the equivalent of 503.3 Bcf/yr of domestically produced LNG by vessel from Trains 5 and 6 of the SPL Project to non-FTA countries for a 20-year term.

• SPL entered into a lump sum turnkey contract for the engineering, procurement and construction of Train 5 of the SPL Project(the “EPC Contract (Train 5)”).

• SPL entered into four credit facilities (collectively, the “2015 SPL Credit Facilities”) totaling $4.6 billion, which replaced its existing credit facilities. The 2015 SPL Credit Facilities will be used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the SPL Project.

• SPL issued an NTP to Bechtel under the EPC Contract (Train 5).

• SPL entered into a $1.2 billion Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “SPL Working Capital Facility”), which replaced the existing Senior Letter of Credit and Reimbursement Agreement that was entered into in April 2014 (the “SPL LC Agreement”). The SPL Working Capital Facility will be used primarily for certain working capital requirements related to developing and placing into operation the SPL Project.

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Liquidity and Capital Resources

Although results are consolidated for financial reporting, Cheniere, Cheniere Holdings, Cheniere Partners, SPL and SPLNG operate with independent capital structures. We expect the cash needs for at least the next twelve months will be met for each of these independent capital structures as follows:

•SPLNG through operating cash flows, existing unrestricted cash and debt offerings or equity contributions;

•SPL through project debt and equity financings and operating cash flows;

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

•Cheniere Holdings through distributions from Cheniere Partners; and

• Cheniere through project financing, existing unrestricted cash, debt and equity offerings by us or our subsidiaries, operating cash flows, services fees from Cheniere Holdings, Cheniere Partners and its other subsidiaries and distributions from our investments in Cheniere Holdings and Cheniere Partners.

As of September 30, 2015, we had cash and cash equivalents of $1,340.3 million available to Cheniere. In addition, we had current and non-current restricted cash of $771.1 million (which included current and non-current restricted cash available to CCH HoldCo II, Cheniere Holdings, Cheniere Partners, SPL and SPLNG) designated for the following purposes: $71.3 million for the CCL Project; $327.2 million for the SPL Project; $11.3 million for CTPL; $129.1 million for interest payments related to the SPLNG Senior Notes described below; and $232.2 million for other restricted purposes.

In November 2014, we issued an aggregate principal amount of $1.0 billion Convertible Unsecured Notes due 2021 (the “2021 Cheniere Convertible Unsecured Notes”). Beginning one year after the closing date, the 2021 Cheniere Convertible Unsecured Notes will be 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 conversion date. The initial conversion price was $93.64 and is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

In March 2015, we issued 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. 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. The conversion rate is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

We receive management fees from CCL and CCP for managing the construction and operation of the CCL Project. For the nine months ended September 30, 2015, we received $1.4 million of management fees from CCL and CCP.

Substantially all of our revenues from external customers and long-lived assets are attributed to or located in the United States.

Cheniere Holdings

Cheniere Holdings was formed by us to hold our Cheniere Partners limited partner interests, thereby allowing us to segregate our lower risk, stable, cash flow generating assets from our higher risk, early stage development projects and marketing activities. As of September 30, 2015, we had an 80.1% direct ownership interest in Cheniere Holdings. We receive dividends on our Cheniere Holdings shares from the distributions that Cheniere Holdings receives from Cheniere Partners, and we receive management fees for managing Cheniere Holdings. For the nine months ended September 30, 2015, we received $11.0 million in dividends on our Cheniere Holdings common shares and $0.8 million of management fees from Cheniere Holdings.

Cheniere Partners

Our ownership interest in the Sabine Pass LNG terminal is held through Cheniere Partners. As of September 30, 2015, we own 80.1% of Cheniere Holdings, which owns a 55.9% limited partner interest in Cheniere Partners in the form of 11,963,488

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common units, 45,333,334 Class B units and 135,383,831 subordinated units. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners.

Prior to the initial public offering by Cheniere Holdings, we received quarterly equity distributions from Cheniere Partners related to our limited partner and 2% general partner interests. We will continue to receive quarterly equity distributions from Cheniere Partners related to our 2% general partner interest, and we receive fees for providing services to Cheniere Partners, SPLNG, SPL and CTPL. During the nine months ended September 30, 2015, we received $1.5 million in distributions on our general partner interest and $66.4 million in total service fees from Cheniere Partners, SPLNG, SPL and CTPL.

Cheniere Partners’ common unit and general partner distributions are being funded from accumulated operating surplus. We have not received distributions on our subordinated units with respect to the quarters ended on or after June 30, 2010. Cheniere Partners will not make distributions on our subordinated units until it generates additional cash flow from the SPL Project, SPLNG’s excess capacity or other new business, which would be used to make quarterly distributions on our subordinated units before any increase in distributions to the common unitholders.

Cheniere Partners’ Class B units are subject to conversion, mandatorily or at the option of the Class B unitholders under specified circumstances, into a number of common units based on the then-applicable conversion value of the Class B units. The Cheniere Partners Class B units are not entitled to cash distributions except in the event of a liquidation of Cheniere Partners, a merger, consolidation or other combination of Cheniere Partners with another person or the sale of all or substantially all of the assets of Cheniere Partners. On a quarterly basis beginning on the initial purchase of the Class B units and ending on the conversion date of the Class B units, the conversion value of the Class B units increases at a compounded rate of 3.5% per quarter, subject to an additional upward adjustment for certain equity and debt financings. The accreted conversion ratio of the Class B units owned by Cheniere Holdings and Blackstone CQP Holdco LP (“Blackstone”) was 1.57 and 1.54, respectively, as of September 30, 2015. We expect the Class B units to mandatorily convert into common units within 90 days of the substantial completion date of Train 3 of the SPL Project, which Cheniere Partners currently expects to occur before April 30, 2017. If the Class B units are not mandatorily converted by July 2019, the holders of the Class B units have the option to convert the Class B units into common units at that time.

LNG Terminal Business

Sabine Pass LNG Terminal

Regasification Facilities

The Sabine Pass LNG terminal has operational regasification capacity of approximately 4.0 Bcf/d and aggregate LNG storage capacity of approximately 16.9 Bcfe. Approximately 2.0 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 Bcf/d of regasification capacity and is obligated to make monthly capacity payments to SPLNG aggregating approximately $125 million annually 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 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, continuing until at least 20 years after SPL delivers its first commercial cargo at the SPL Project.

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

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Liquefaction Facilities

The SPL Project is being developed and constructed at the Sabine Pass LNG terminal adjacent to the existing regasification facilities. We commenced construction of Trains 1 and 2 and the related new facilities needed to treat, liquefy, store and export natural gas in August 2012. Construction of Trains 3 and 4 and the related facilities commenced in May 2013. In April 2015, we received authorization from the FERC to site, construct and operate Trains 5 and 6. In June 2015, we commenced construction of Train 5 and the related facilities.

The DOE has authorized the export of up to a combined total of the equivalent of 16 mtpa (approximately 803 Bcf/yr) of domestically produced LNG by vessel from the Sabine Pass LNG terminal to FTA countries for a 30-year term and to non-FTA countries for a 20-year term. The DOE further issued an order authorizing SPL to export up to the equivalent of approximately 203 Bcf/yr of domestically produced LNG from the Sabine Pass LNG terminal to FTA countries for a 25-year period. SPL’s application for authorization to export that same 203 Bcf/yr of domestically produced LNG from the Sabine Pass LNG terminal to non-FTA countries is currently pending at the DOE. Additionally, the DOE issued orders authorizing SPL to export up to a combined total of 503.3 Bcf/yr of domestically produced LNG from the Sabine Pass LNG terminal to FTA countries and non-FTA countries for a 20-year term. The Sierra Club has requested a rehearing of the non-FTA order pertaining to the 503.3 Bcf/yr, and the DOE has not yet ruled on this request. 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 5 to 10 years from the date the order was issued.

As of September 30, 2015, the overall project completion percentage for Trains 1 and 2 of the SPL Project was approximately 95.2%, which is ahead of the contractual schedule. As of September 30, 2015, the overall project completion percentage for Trains 3 and 4 of the SPL Project was approximately 73.6%, which is also ahead of the contractual schedule. Based on our current construction schedule, we anticipate that Train 1 will produce LNG as early as late 2015, and Trains 2 through 5 are expected to commence operations on a staggered basis thereafter.

Customers

SPL has entered into six fixed price, 20-year SPAs with third parties that in the aggregate equate to approximately 19.75 mtpa of LNG that commence with the date of first commercial delivery for Trains 1 through 5, which are fully permitted. Under these SPAs, the customers will purchase LNG from SPL for a price consisting of a fixed fee plus 115% of Henry Hub per MMBtu of LNG. In certain circumstances, the customers may elect to cancel or suspend deliveries of LNG cargoes, in which case the customers would still be required to pay the fixed fee with respect to cargoes that are not delivered. A portion of the fixed fee will be subject to annual adjustment for inflation. 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 commences upon the start of operations of the specified Train.

In aggregate, the fixed fee portion to be paid by these customers is approximately $2.9 billion annually for Trains 1 through 5, with the applicable fixed fees starting from the commencement of commercial operations of the applicable Train. These fixed fees equal approximately $411 million, $564 million, $650 million, $648 million and $588 million for each of Trains 1 through 5, respectively.

In addition, Cheniere Marketing has entered into an amended and restated SPA with SPL to purchase, at Cheniere Marketing’s option, any LNG produced by SPL in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG.

Natural Gas Transportation and Supply

For SPL’s natural gas feedstock transportation requirements, it has entered into transportation precedent agreements to secure firm pipeline transportation capacity with CTPL and third-party pipeline companies. SPL has also entered into enabling agreements and long-term natural gas purchase agreements with third parties in order to secure natural gas feedstock for the SPL Project. As of September 30, 2015, SPL has secured up to approximately 2,156.6 millionMMBtu of natural gas feedstock through long-term natural gas purchase agreements.

Construction

SPL entered into lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of Trains 1 through 5, under which Bechtel charges a lump sum for all work performed and generally bears project cost risk unless certain

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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 prices of the EPC contract for Trains 1 and 2, EPC contract for Trains 3 and 4 and EPC Contract (Train 5) are approximately $4.1 billion, $3.8 billion and $2.9 billion, respectively, reflecting amounts incurred under change orders through September 30, 2015. Total expected capital costs for Trains 1 through 5 are estimated to be between $12.5 billion and $13.5 billion before financing costs and between $17.0 billion and $18.0 billion after financing costs including, in each case, estimated owner’s costs and contingencies.

Pipeline Facilities

During the third quarter of 2015, CTPL completed construction of certain modifications to allow the Creole Trail Pipeline to be able to transport natural gas to the Sabine Pass LNG terminal.

Final Investment Decision on Train 6

We will contemplate making a final investment decision (“FID”) to commence construction of Train 6 of the SPL Project based upon, among other things, entering into an EPC contract, entering into acceptable commercial arrangements and obtaining adequate financing to construct the Train.

Capital Resources

We currently expect that SPL’s capital resources requirements with respect to Trains 1 through 5 of the SPL Project will be financed through one or more of the following: borrowings, equity contributions from Cheniere Partners and cash flows under the SPAs. We believe that with the net proceeds of borrowings, unfunded commitments under the 2015 SPL Credit Facilities, available commitments under the SPL Working Capital Facility and cash flows from operations, we will have adequate financial resources available to complete Trains 1 through 5 of the SPL Project and to meet its currently anticipated capital, operating and debt service requirements. We currently project that SPL will generate cash flow from the SPL Project by early 2016.

Senior Secured Notes

As of September 30, 2015, Cheniere Partners’ subsidiaries had seven series of senior secured notes outstanding (collectively, the “Senior Notes”):

• $1.7 billion of 7.50% Senior Secured Notes due 2016 issued by SPLNG (the “2016 SPLNG Senior Notes”);

• $0.4 billion of 6.50% Senior Secured Notes due 2020 issued by SPLNG (the “2020 SPLNG Senior Notes” and collectively with the 2016 SPLNG Senior Notes, the “SPLNG Senior Notes”);

• $2.0 billion of 5.625% Senior Secured Notes due 2021 issued by SPL (the “2021 SPL Senior Notes”);

• $1.0 billion of 6.25% Senior Secured Notes due 2022 issued by SPL (the “2022 SPL Senior Notes”);

• $1.5 billion of 5.625% Senior Secured Notes due 2023 issued by SPL (the “2023 SPL Senior Notes”);

• $2.0 billion of 5.75% Senior Secured Notes due 2024 issued by SPL (the “2024 SPL Senior Notes” and collectively with the 2021 SPL Senior Notes, the 2022 SPL Senior Notes, the 2023 SPL Senior Notes and the 2025 SPL Senior Notes, the “SPL Senior Notes”); and

• $2.0 billion of the 2025 SPL Senior Notes.

Interest on the Senior Notes is payable semi-annually in arrears. Subject to permitted liens, the SPLNG Senior Notes are secured on a pari passu first-priority basis by a security interest in all of SPLNG’s equity interests and substantially all of SPLNG’s operating assets. The SPL Senior Notes are secured on a first-priority basis by a security interest in all of the membership interests in SPL and substantially all of SPL’s assets.

SPLNG may redeem all or part of its 2016 SPLNG Senior Notes at any time at a redemption price equal to 100% of the principal plus any accrued and unpaid interest plus the greater of:

• 1.0% of the principal amount of the 2016 SPLNG Senior Notes; or

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• the excess of: (1) the present value at such redemption date of (a) the redemption price of the 2016 SPLNG Senior Notes plus (b) all required interest payments due on the 2016 SPLNG Senior Notes (excluding accrued but unpaid interest to the redemption date), computed using a discount rate equal to the treasury rate as of such redemption date plus 50 basis points; over (2) the principal amount of the 2016 SPLNG Senior Notes, if greater.

SPLNG may redeem all or part of the 2020 SPLNG Senior Notes at any time on or after November 1, 2016 at fixed redemption prices specified in the indenture governing the 2020 SPLNG Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. SPLNG may also, at its option, redeem all or part of the 2020 SPLNG Senior Notes at any time prior to November 1, 2016, at a “make-whole” price set forth in the indenture governing the 2020 SPLNG Senior Notes, plus accrued and unpaid interest, if any, to the date of redemption. At any time before November 1, 2015, SPLNG may redeem up to 35% of the aggregate principal amount of the 2020 SPLNG Senior Notes at a redemption price of 106.5% of the principal amount of the 2020 SPLNG Senior Notes to be redeemed, plus accrued and unpaid interest, if any, to the redemption date, in an amount not to exceed the net proceeds of one or more completed equity offerings as long as SPLNG redeems the 2020 SPLNG Senior Notes within 180 days of the closing date for such equity offering and at least 65% of the aggregate principal amount of the 2020 SPLNG Senior Notes originally issued remains outstanding after the redemption.

At any time prior to three months before the respective dates of maturity for each series of the SPL Senior Notes, SPL may redeem all or part of such series of the SPL Senior Notes at a redemption price equal to the “make-whole” price set forth in the common indenture 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, 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.

Under the indentures governing the SPLNG Senior Notes(the “SPLNG Indentures”), except for permitted tax distributions, SPLNG may not make distributions until, among other requirements, deposits are made into debt service reserve accounts and a fixed charge coverage ratio test of 2:1 is satisfied. Under the common indenture governing the SPL Senior Notes, SPL may not make any distributions until, among other requirements, substantial completion of Trains 1 and 2 has occurred, deposits are made into debt service reserve accounts and a debt service coverage ratio test of 1.25:1.00 is satisfied. During the nine months ended September 30, 2015 and 2014, SPLNG made distributions of $267.9 million and $237.7 million, respectively, after satisfying all the applicable conditions in the SPLNG Indentures.

The SPL Senior Notes are governed by a common indenture with 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, the 2015 SPL Credit Facilities and the SPL Working Capital Facility.

2015 SPL Credit Facilities

In June 2015, SPL entered into the 2015 SPL Credit Facilities with commitments aggregating $4.6 billion. The 2015 SPL Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the SPL Project. Borrowings under the 2015 SPL Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, SPL had $4.3 billion of available commitments and $250.0 million of outstanding borrowings under the 2015 SPL Credit Facilities.

Loans under the 2015 SPL Credit Facilities accrue interest at a variable rate per annum equal to, at SPL’s election, LIBOR or the base rate plus the applicable margin. The applicable margin for LIBOR loans ranges from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period and interest on base rate loans is due and payable at the end of each quarter. In addition, SPL is required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 SPL Credit Facilities. The 2015 SPL Credit Facilities also require SPL to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment, or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 SPL Credit Facility. The principal of the loans made under the 2015 SPL Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the SPL Project. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2015 SPL Credit Facilities.

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The obligations of SPL under the 2015 SPL Credit Facilities are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and SPL Working Capital Facility.

Under the terms of the 2015 SPL Credit Facilities, SPL is required to hedge not less than 65% of the variable interest rate exposure of its projected outstanding borrowings, calculated on a weighted average basis in comparison to its anticipated draw of principal.

2013 SPL Credit Facilities

 In May 2013, SPL entered into four credit facilities aggregating $5.9 billion (collectively, the “2013 SPL Credit Facilities”) to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 4 of the SPL Project. In June 2015, the 2013 SPL Credit Facilities were replaced with the 2015 SPL Credit Facilities.

In March 2015, in conjunction with SPL’s issuance of the 2025 SPL Senior Notes, SPL terminated approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities. This termination and the replacement of the 2013 SPL Credit Facilities with the 2015 SPL Credit Facilities in June 2015 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 SPL Credit Facilities of $96.3 million for the nine months ended September 30, 2015.

CTPL Term Loan

CTPL has a $400.0 million term loan facility (the “CTPL Term Loan”), which was used to fund modifications to the Creole Trail Pipeline and for general business purposes. The CTPL Term Loan matures in 2017 when the full amount of the outstanding principal obligations must be repaid. CTPL’s loan may be repaid, in whole or in part, at any time without premium or penalty. As of September 30, 2015, CTPL had borrowed the full amount of $400.0 million available under the CTPL Term Loan. Borrowings under the CTPL Term Loan accrue interest at a variable rate per annum equal to, at CTPL’s election, LIBOR or the base rate, plus the applicable margin. The applicable margin for LIBOR loans is 3.25%. Interest on LIBOR loans is due and payable at the end of each LIBOR period.

SPL Working Capital Facility

In September 2015, SPL entered into a $1.2 billion SPL Working Capital Facility, which replaced the $325.0 million SPL LC Agreement. The SPL Working Capital Facility is intended to be used for loans to SPL (“Working Capital Loans”), the issuance of letters of credit on behalf of SPL (“Letters of Credit”), as well as for swing line loans to SPL (“Swing Line Loans”), primarily for certain working capital requirements related to developing and placing into operation the SPL Project. SPL may, from time to time, request increases in the commitments under the 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 million. As of September 30, 2015, SPL had $1.1 billion of available commitments, $127.6 million aggregate amount of issued Letters of Credit and noWorking Capital Loans, Swing Line Loans or loans deemed made in connection with a draw upon a Letter of Credit (“LC Loans” and collectively with Working Capital Loans and Swing Line Loans, the “SPL Working Capital Facility Loans”) outstanding under the SPL Working Capital Facility. As of December 31, 2014, SPL had issued letters of credit in an aggregate amount of $9.5 million, and no draws had been made upon any letters of credit issued under the SPL LC Agreement.

SPL Working Capital Facility Loans 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 one month LIBOR plus 0.50%), plus the applicable margin. The applicable margin for LIBOR SPL Working Capital Facility Loans is 1.75% per annum, and the applicable margin for base rate SPL Working Capital Facility Loans is 0.75% per annum. Interest on Swing Line Loans and LC Loans is due and payable on the date the loan becomes due. Interest on LIBOR Working Capital Loans is due and payable at the end of each applicable LIBOR period, and interest on base rate Working Capital Loans is due and payable at the end of each fiscal quarter. However, if such base rate Working Capital Loan is converted into a LIBOR Working Capital Loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date.

SPL incurred $27.5 million of debt issuance costs in connection with the SPL Working Capital Facility. SPL pays (1) a commitment fee on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans in an amount equal to an annual rate of 0.70% and (2) a Letter of Credit

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fee equal to an annual rate of 1.75% of the undrawn portion of all Letters of Credit issued under the SPL Working Capital Facility. If draws are made upon a Letter of Credit issued under the SPL Working Capital Facility and SPL does not elect for such draw (an “LC Draw”) to be deemed an LC Loan, SPL is required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw. An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of September 30, 2015, no LC Draws had been made upon any Letters of Credit issued under the SPL Working Capital Facility.

The SPL Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year. 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 Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. SPL is required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The SPL Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of SPL under the SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and 2015 SPL Credit Facilities.

Corpus Christi LNG Terminal

Liquefaction Facilities

The CCL Project is being developed and constructed on over 1,500 acres of land that we own or control near Corpus Christi, Texas. In December 2014, we received authorization from the FERC to site, construct and operate Stages 1 and 2 of the CCL Project. In May 2015, we made a positive FID with respect to Stage 1 of the CCL Project and issued an NTP to Bechtel under the EPC Contract (CCL Stage 1). We recently began the development of Stage 3 of the CCL Project and commenced the regulatory approval process in June 2015.

The DOE has authorized the export of up to a combined total of the equivalent of 767 Bcf/yr of domestically produced LNG by vessel from the CCL Project to FTA countries for a 25-year term and to non-FTA countries for a 20-year term. The Sierra Club has requested a rehearing of the non-FTA order, and the DOE has not yet ruled on this request. Additionally, the DOE has authorized the export of up to a combined total of the equivalent of 514 Bcf/yr of domestically produced LNG by vessel from Stage 3 of the CCL Project to FTA countries for a 20-year term. 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 7 to 10 years from the date the order was issued.

As of September 30, 2015, the overall project completion percentage for Stage 1 of the CCL Project was approximately 22.8%, with engineering, procurement and construction approximately 82.0%, 32.0% and less than 1% complete, respectively. The construction of the Corpus Christi Pipeline is planned to commence in 2016.

Customers

CCL has entered into eight fixed price, 20-year SPAs with seven third parties that in the aggregate equate to approximately 8.4 mtpa of LNG that commence with the date of first commercial delivery for Trains 1 through 3, which are fully permitted. Under these eight SPAs, the customers will purchase LNG from CCL for a price consisting of a fixed fee of $3.50 plus 115% of Henry Hub per MMBtu of LNG. In certain circumstances, the customers may elect to cancel or suspend deliveries of LNG cargoes, in which case the customers would still be required to pay the fixed fee with respect to cargoes that are not delivered. A portion of the fixed fee will be subject to annual adjustment for inflation. 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 commences upon the start of operations of a specified Train.

In aggregate, the fixed fee portion to be paid by these customers is approximately $1.4 billion annually for Trains 1 and 2, and $1.5 billion if we make a positive FID with respect to Stage 2 of the CCL Project, with the applicable fixed fees starting from the commencement of commercial operations of the applicable Train. These fixed fees equal approximately $619 million, $776 million and $140 million for each of Trains 1 through 3, respectively.

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Natural Gas Transportation and Supply

For its natural gas feedstock transportation requirements, CCL has entered into transportation precedent agreements to secure firm pipeline transportation capacity with third party pipeline companies and CCP. CCL has also entered into enabling agreements with third parties and will continue to enter into such agreements in order to secure natural gas feedstock for the CCL Project.

Construction

CCL entered into separate lump sum turnkey contracts with Bechtel for the engineering, procurement and construction of Stages 1 and 2 of the CCL Project under which Bechtel charges a lump sum for all work performed and generally bears project cost risk 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 of the EPC contracts for Stages 1 and 2, which do not include the Corpus Christi Pipeline, are approximately $7.5 billion and $2.4 billion, respectively, reflecting amounts incurred under change orders through September 30, 2015. Total expected capital costs for Stages 1 and 2 are estimated between $12.0 billion and $13.0 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. Total expected capital costs for Stage 1 only are estimated to be between $9.0 billion and $10.0 billion, before financing costs, and between $11.0 billion and $12.0 billion after financing costs including, in each case, estimated owner’s costs and contingencies.

Pipeline Facilities

On December 30, 2014, the FERC issued a certificate of public convenience and necessity under Section 7(c) of the Natural Gas Act of 1938, as amended, authorizing CCP to construct and operate the Corpus Christi Pipeline. The Corpus Christi Pipeline is designed to transport 2.25 Bcf/d of feed and fuel gas required by the CCL Project from the existing regional natural gas pipeline grid.

Final Investment Decision on Stage 2

We will contemplate making an FID to commence construction of Stage 2 of the CCL Project based upon, among other things, entering into acceptable commercial arrangements.

Capital Resources

We expect to finance the construction costs of the CCL Project from one or more of the following: project financing, existing unrestricted cash, offerings by us or our subsidiaries of debt or equity and operating cash flow.

2025 CCH HoldCo II Convertible Senior Notes

In May 2015, CCH HoldCo II issued $1.0 billion aggregate principal amount of the 2025 CCH HoldCo II Convertible Senior Notes on a private placement basis. The $1.0 billion principal of the 2025 CCH HoldCo II Convertible Senior Notes will be used to partially fund costs associated with Stage 1 of the CCL Project and the Corpus Christi Pipeline. The purchasers have made commitments, which will expire on May 1, 2016, to acquire an additional $500 million of 2025 CCH HoldCo II Convertible Senior Notes(the “Second Phase Funding”) upon satisfaction of incremental customary conditions precedent related to the construction of Stage 2 of the CCL Project. The 2025 CCH HoldCo II Convertible Senior Notes bear interest at a rate of 11.0% per annum, which is payable quarterly in arrears. Prior to the substantial completion of Train 2 of the CCL Project if the Second Phase Funding has not occurred, and to the substantial completion of Train 3 of the CCL Project following the occurrence of the Second Phase Funding, interest on the 2025 CCH HoldCo II Convertible Senior Notes will be paid entirely in kind. Following this date, the interest generally must be paid in cash; however, a portion of the interest may be paid in kind under certain specified circumstances. 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.

At CCH HoldCo II’s option, the outstanding 2025 CCH HoldCo II Convertible Senior Notes are convertible into our common stock on or after the later of (1) 58 months from May 1, 2015, and (2) the substantial completion of Train 2 of the CCL Project and any 2025 CCH HoldCo II Convertible Senior Notes issued in connection with the Second Phase Funding will be convertible

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on or after the substantial completion of Train 3 of the CCL Project(in each case, the “Eligible Conversion Date”). The conversion price for 2025 CCH HoldCo II Convertible Senior Notes converted at CCH HoldCo II’s option is 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. At the option of the holders, the 2025 CCH HoldCo II Convertible Senior Notes are convertible on or after the six-month anniversary of the applicable Eligible Conversion Date at a conversion 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. Conversions are also subject to various limitations and conditions.

2015 CCH Credit Facility

In May 2015, CCH entered into the 2015 CCH Credit Facility, which is being used to fund a portion of the costs associated with the development, construction, operation and maintenance of the CCL Project.  The total commitment under the 2015 CCH Credit Facility is approximately $11.5 billion, comprising approximately $8.4 billion linked to Stage 1 of the CCL Project and the Corpus Christi Pipeline and approximately $3.1 billion linked to Stage 2 of the CCL Project. Borrowings under the 2015 CCH Credit Facility may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, CCH had $6.0 billion of available commitments and $2.4 billion of outstanding borrowings under the 2015 CCH Credit Facility.

The principal of the loans made under the 2015 CCH Credit Facility must be repaid in quarterly installments, commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following project completion and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train 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 project completion and designed to achieve a minimum projected fixed debt service coverage ratio of 1.55:1. Loans under the 2015 CCH Credit Facility accrue interest at a variable rate per annum equal to, at CCH’s election, LIBOR or the base rate, plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period and interest on base rate loans is due and payable at the end of each quarter. The 2015 CCH Credit Facility also requires CCH to pay a commitment fee at a rate per annum equal to 40% of the margin for LIBOR loans, multiplied by the outstanding undrawn debt commitments.

The obligations of CCH under the 2015 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.

Under the terms of the 2015 CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt.

LNG and Natural Gas Marketing Business

Cheniere Marketing is engaged in the LNG and natural gas marketing business and is seeking to develop a portfolio of long-term, short-term and spot LNG purchase and sale agreements. Cheniere Marketing has purchased, transported and unloaded commercial LNG cargoes into the Sabine Pass LNG terminal and has used trading strategies intended to maximize margins on these cargoes. Cheniere Marketing has secured the following rights and obligations to support its business:

• the right to deliver cargoes to the Sabine Pass LNG terminal during the construction of the SPL Project in exchange for payment of 80% of the expected gross margin from each cargo to Cheniere Investments, a wholly owned subsidiary of Cheniere Partners;

• pursuant to an amended and restated SPA with SPL, the right to purchase, at Cheniere Marketing’s option, any LNG produced by SPL in excess of that required for other customers at a price of 115% of Henry Hub plus $3.00 per MMBtu of LNG;

• pursuant to SPAs with CCL, the right to purchase, at Cheniere Marketing’s option, any LNG produced by CCL not required for other customers; and

• a portfolio of LNG vessel time charters.

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In addition, Cheniere Marketing has sold LNG cargoes to be delivered to multiple counterparties between 2016 and 2018, with delivery obligations conditioned on the performance of the SPL Project.  The cargoes have been sold with a portfolio of delivery points, either on a Free on Board basis, delivered to the counterparty at the Sabine Pass LNG terminal, or a Delivered at Terminal (“DAT”) basis, delivered to the counterparty’s LNG receiving terminal. Cheniere Marketing has chartered LNG vessels, as described above, to be utilized in DAT transactions. In addition, Cheniere Marketing has also entered into a long-term agreement to sell LNG cargoes on a DAT basis.  The agreement is conditioned upon the buyer achieving certain milestones, including reaching an FID related to certain projects and obtaining related financing.

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 of developing other projects, including a liquid hydrocarbon export project in Texas along the Gulf Coast. In addition, we have agreed in principle to partner with Parallax to develop up to 11 mtpa of LNG production capacity through Parallax’s two mid-scale natural gas liquefaction projects in Louisiana along the Gulf Coast.

Sources and Uses of Cash

The following table (in thousands) summarizes the sources and uses of our cash and cash equivalents for the nine months ended September 30, 2015 and 2014. 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. 

	Nine Months Ended September 30,
	2015			2014
Sources of cash and cash equivalents
Proceeds from issuances of long-term debt	$	6,178,000		$	2,584,500
Use of restricted cash for the acquisition of property, plant and equipment	5,330,526			1,980,436
Proceeds from exercise of stock options	2,279			9,502
Other	1,424			—
Total sources of cash and cash equivalents	11,512,229			4,574,438
Uses of cash and cash equivalents
Investment in restricted cash	(5,161,701		)	(2,254,733		)
Property, plant and equipment, net	(5,747,596		)	(2,047,957		)
Debt issuance and deferred financing costs	(519,699		)	(94,220		)
Repayments of long-term debt	—			(177,000		)
Distributions and dividends to non-controlling interest	(60,154		)	(59,478		)
Payments related to tax withholdings for share-based compensation	(44,305		)	(44,516		)
Operating cash flow	(274,577		)	(41,050		)
Other	(111,518		)	(24,670		)
Total uses of cash and cash equivalents	(11,919,550		)	(4,743,624		)
Net decrease in cash and cash equivalents	(407,321		)	(169,186		)
Cash and cash equivalents—beginning of period	1,747,583			960,842
Cash and cash equivalents—end of period	$	1,340,262		$	791,656

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Proceeds from Issuances of Long-Term Debt, Debt Issuance and Deferred Financing Costs and Repayments of Long-Term Debt

In March 2015, SPL issued an aggregate principal amount of $2.0 billion of the 2025 SPL Senior Notes. Also in March 2015, we issued an aggregate principal amount of $625.0 million of the 2045 Cheniere Convertible Senior Notes, with an original issue discount of 20%, for net proceeds of $495.7 million. In May 2015, CCH HoldCo II issued an aggregate principal amount of $1.0 billion of the 2025 CCH HoldCo II Convertible Senior Notes. Also in May 2015, CCH entered into the 2015 CCH Credit Facility and borrowed $2.4 billion under this facility during the nine months ended September 30, 2015. In June 2015, SPL entered into the 2015 SPL Credit Facilities aggregating $4.6 billion, which terminated and replaced the 2013 SPL Credit Facilities, and borrowed $250.0 million under this facility during the nine months ended September 30, 2015. Debt issuance and deferred financing costs in the nine months ended September 30, 2015 primarily relate to up-front fees paid upon the closing of these transactions.

In May 2014, SPL issued the 2024 SPL Senior Notes and additional 5.625% Senior Secured Notes due 2023 in an aggregate principal amount of $0.5 billion (the “Additional 2023 SPL Senior Notes”) for total net proceeds of approximately $2.5 billion. Debt issuance and deferred financing costs in the nine months ended September 30, 2014 primarily relate to up-front fees paid upon the closing of this offering in May 2014.

During the nine months ended September 30, 2014, SPL repaid its $177.0 million of borrowings under the 2013 SPL Credit Facilities upon the issuance of the Additional 2023 SPL Senior Notes and the 2024 SPL Senior Notes.

Use of Restricted Cash for the Acquisition of Property, Plant and Equipment and Property, Plant and Equipment, net

During the nine months ended September 30, 2015 and 2014, we used $5,330.5 million and $1,980.4 million, respectively, of restricted cash for investing activities to partially fund $5,747.6 million and $2,048.0 million used for the acquisition of property, plant and equipment during the nine months ended September 30, 2015 and 2014, respectively. These costs primarily related to the construction costs for Trains 1 through 5 of the SPL Project and Stage 1 of the CCL Project and are capitalized as construction-in-process.

Investment in Restricted Cash

In the nine months ended September 30, 2015, we invested $5,161.7 million in restricted cash primarily related to the net proceeds from the 2025 SPL Senior Notes, 2045 Cheniere Convertible Senior Notes, 2025 CCH HoldCo II Convertible Senior Notes and the borrowings under the 2015 SPL Credit Facilities and 2015 CCH Credit Facility, net of deferred financing costs. These proceeds were partially offset by the payment of distributions to non-controlling interest. In the nine months ended September 30, 2014, we invested $2,254.7 million in restricted cash primarily related to the net proceeds from the 2024 SPL Senior Notes and the Additional 2023 SPL Senior Notes issued in May 2014.

Distributions and Dividends to Non-controlling Interest

During the nine months ended September 30, 2015 and 2014, Cheniere Partners and Cheniere Holdings, collectively, made distributions and paid dividends of $60.2 million and $59.5 million, respectively, to non-affiliated common unitholders and common shareholders.

Payments Related to Tax Withholdings for Share-based Compensation

During the nine months ended September 30, 2015 and 2014, we used $44.3 million and $44.5 million, respectively, of cash and cash equivalents to purchase restricted stock that was returned to us by employees to cover taxes related to their restricted stock that vested during such periods.

Operating Cash Flow

We had a cash outflow from operating activities of $274.6 million during the nine months ended September 30, 2015, compared to a cash outflow of $41.1 million during the nine months ended September 30, 2014. This increase in operating cash outflows primarily related to amounts paid upon meeting the contingency related to the interest rate swaps we entered into to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 CCH Credit Facility(“CCH Interest Rate Derivatives”) and settlement of other derivative instruments, the timing of amounts paid to third parties for the construction of the SPL Project and the CCL Project and increased payments made for general and administrative costs.

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Other

Other cash outflows increased from $24.7 million during the nine months ended September 30, 2014 to $111.5 million during the nine months ended September 30, 2015, primarily for payments made to a municipal water district for water system enhancements that will increase potable water supply to our Sabine Pass LNG terminal, advances made under our EPC contracts and investments made in connection with the mid-scale natural gas liquefaction projects being developed with Parallax.

Issuance of Common Stock

 During the nine months ended September 30, 2015 and 2014, we issued 19,000 and 0.5 million shares, respectively, of restricted stock to new and existing employees and members of our board of directors.

Results of Operations

Three Months EndedSeptember 30, 2015 vs. Three Months EndedSeptember 30, 2014

Our consolidated net loss attributable to common stockholders was $297.8 million, or $1.31 per share (basic and diluted), in the three months ended September 30, 2015 compared to a net loss attributable to common stockholders of $89.6 million, or $0.40 per share (basic and diluted), in the three months ended September 30, 2014. This $208.2 million increase in net loss was primarily a result of increased derivative loss, net, increased interest expense, net of amounts capitalized and increased general and administrative expense (“G&A Expense”), which was partially offset by decreased operating and maintenance expense (income).

Derivative loss, net increased $166.9 million from a gain of $5.4 million in the three months ended September 30, 2014 to a loss of $161.5 million in the three months ended September 30, 2015, primarily as a result of a decrease in long-term LIBOR during the three months ended September 30, 2015, as compared to an increase in long-term LIBOR during the three months ended September 30, 2014, as well as an increased notional amount of interest rate derivatives outstanding. Interest expense, net of amounts capitalized increased $46.7 million in the three months ended September 30, 2015, as compared to the three months ended September 30, 2014, primarily as a result of an increase in our indebtedness outstanding as of September 30, 2015 compared to September 30, 2014. For the three months ended September 30, 2015 and 2014, we incurred $286.0 million and $154.8 million of total interest cost, respectively, of which we capitalized and deferred $192.4 million and $107.9 million, respectively, which were directly related to the construction of the SPL Project and CCL Project. G&A Expense increased $23.1 million in the three months ended September 30, 2015, as compared to the three months ended September 30, 2014, primarily due to increased compensation expense as a result of increased headcount.

Partially offsetting the above increase in expenses, operating and maintenance expense (income) decreased $32.2 million due to a $32.2 million increase in fair value for our natural gas purchase agreements recorded for the period, which we recognized following the completion and placement into service of certain modifications to the Creole Trail Pipeline and the resulting development of a market for physical gas delivery at locations specified in a portion of our natural gas purchase agreements. Excluding this amount, operating and maintenance expense would have been $25.9 million during the three months ended September 30, 2015 and 2014, which was a result of the expenses incurred to purchase LNG to maintain the cryogenic readiness of the regasification facilities at the Sabine Pass LNG terminal, which we did not incur during the three months ended September 30, 2015, offset primarily by the increase in expenses related to LNG vessel time charters by Cheniere Marketing during the three months ended September 30, 2015.

Nine Months EndedSeptember 30, 2015 vs. Nine Months EndedSeptember 30, 2014

Our consolidated net loss attributable to common stockholders was $684.0 million, or $3.02 per share (basic and diluted), in the nine months ended September 30, 2015 compared to a net loss attributable to common stockholders of $389.3 million, or $1.74 per share (basic and diluted), in the nine months ended September 30, 2014. This $294.7 million increase in net loss was primarily a result of increased derivative loss, net, increased interest expense, net of amounts capitalized and increased G&A Expense, which was partially offset by decreased operating and maintenance expense.

Derivative loss, net increased $152.9 million during the nine months ended September 30, 2015, as compared to the nine months ended September 30, 2014. The derivative loss recognized during the nine months ended September 30, 2015 was primarily

41

attributable to the loss recognized upon meeting the contingency related to the CCH Interest Rate Derivatives, as well as the loss recognized in March 2015 upon the termination of interest rate swaps associated with approximately $1.8 billion of commitments that were terminated under the 2013 SPL Credit Facilities. Additionally, both the increase to the notional amount of interest rate derivatives outstanding and the decrease in long-term LIBOR during the nine months ended September 30, 2015 that was more significant than the decrease in long-term LIBOR during the nine months ended September 30, 2014 contributed to the increase in derivative loss, net.

Interest expense, net of amounts capitalized increased $107.7 million in the nine months ended September 30, 2015, as compared to the nine months ended September 30, 2014, primarily as a result of an increase in our indebtedness outstanding as of September 30, 2015 compared to September 30, 2014. For the nine months ended September 30, 2015 and 2014, we incurred $707.8 million and $423.8 million of total interest cost, respectively, of which we capitalized and deferred $469.2 million and $292.8 million, respectively, which were directly related to the construction of the SPL Project and CCL Project. G&A Expense increased $47.4 million in the nine months ended September 30, 2015, as compared to the nine months ended September 30, 2014, primarily due to increased professional fees and increased compensation expense as a result of increased headcount.

Partially offsetting the above increase in expenses, operating and maintenance expense decreased $19.9 million due to a $32.2 million increase in fair value for our natural gas purchase agreements recorded for the period, which we recognized following the completion and placement into service of certain modifications to the Creole Trail Pipeline and the resulting development of a market for physical gas delivery at locations specified in a portion of our natural gas purchase agreements. Excluding this amount, operating and maintenance expense would have been $81.5 million during the nine months ended September 30, 2015. The increase of $12.2 million compared to $69.3 million incurred during the nine months ended September 30, 2014 was primarily a result of the increase in expenses related to LNG vessel time charters by Cheniere Marketing in the nine months ended September 30, 2015.

Off-Balance Sheet Arrangements

As of September 30, 2015, 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 results of operations. 

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, 2014.

Recent Accounting Standards

For descriptions of recently issued accounting standards, see Part 1. Financial Information, Item 1. Notes to Consolidated Financial Statements, Note 14—Recent Accounting Standards.

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 to hedge the exposure to price risk attributable to future: (1) sales of our LNG inventory and (2) purchases of natural gas to operate the Sabine Pass LNG terminal (“Natural Gas Derivatives”);

42

• commodity derivatives consisting of natural gas purchase agreements to secure natural gas feedstock for the SPL Project(“Liquefaction Supply Derivatives”); and

• 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”).

We use one-day value at risk (“VaR”) with a 95% confidence interval and other methodologies for market risk measurement and control purposes of our Natural Gas Derivatives. The VaR is calculated using the Monte Carlo simulation method. The VaR related to our Natural Gas Derivatives was $0.2 million as of September 30, 2015.

In order to test the sensitivity of the fair value of the Liquefaction Supply Derivatives to changes in underlying commodity prices, management modeled a 10% change in the basis price for natural gas for each delivery location. As of September 30, 2015, we estimated the fair value of the Liquefaction Supply Derivatives to be $33.8 million. Based on actual derivative contractual volumes, a 10% increase or decrease in underlying basis price would have resulted in a change in the fair value of the Liquefaction Supply Derivatives of $0.9 million as of September 30, 2015.

In order to test the sensitivity of the fair value of the LNG Trading Derivatives to changes in underlying commodity prices, management modeled a 10% change in the basis price for natural gas for each delivery point. As of September 30, 2015, we estimated the fair value of the LNG Trading Derivatives to be $0.1 million. Based on actual derivative contractual volumes, a 10% increase or decrease in underlying basis price would have resulted in a change in the fair value of the LNG Trading Derivatives of $1.0 million as of September 30, 2015.

Interest Rate Risk

SPL has entered into interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 SPL Credit Facilities(“SPL Interest Rate Derivatives”). In order to test the sensitivity of the fair value of the SPL Interest Rate Derivatives to changes in interest rates, management modeled a 10% change in the forward 1-month LIBOR curve across the remaining term of the SPL Interest Rate Derivatives. This 10% change in interest rates would have resulted in a change in the fair value of the SPL Interest Rate Derivatives of $2.6 million as of September 30, 2015.

CCH has entered into the CCH Interest Rate Derivatives to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 CCH Credit Facility. 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 1-month LIBOR curve across the remaining term of the CCH Interest Rate Derivatives. This 10% change in interest rates would have resulted in a change in the fair value of the CCH Interest Rate Derivatives of $52.3 million as of September 30, 2015.

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.

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PART II.    OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

Cheniere may in the future be involved as a party to various legal proceedings, which are incidental to the ordinary course of business. Cheniere regularly analyzes current information and, as necessary, provide accruals for probable liabilities on the eventual disposition of these matters.

Please see Part II, Item 1, “Legal Proceedings” in the Company’s Quarterly Report on Form 10-Q for the period ended March 31, 2015.

ITEM 1A.     RISK FACTORS

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, 2014.

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 September 30, 2015:

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	Maximum Number of Units That May Yet Be Purchased Under the Plans
July 1 - 31, 2015	88,283	$68.26	—	—
August 1 - 31, 2015	465,004	$68.46	—	—
September 1 - 30, 2015	842	$43.30	—	—
Total	554,129	$68.40	—	—

(1) Represents shares surrendered to us by participants in our share-based compensation plans to settle the participants’ personal tax liabilities that resulted from the lapsing of restrictions on shares awarded to the participants under these plans.

(2) The price paid per share was based on the closing trading price of our common stock on the dates on which we repurchased shares from the participants under our share-based compensation plans.

ITEM 5.    OTHER INFORMATION

Compliance Disclosure

Pursuant to Section 13(r) of the Exchange Act, if during the quarter ended September 30, 2015, we or any of our affiliates had engaged in certain transactions with Iran or with persons or entities designated under certain executive orders, we would be required to disclose information regarding such transactions in our Quarterly Report on Form 10-Q as required under Section 219 of the Iran Threat Reduction and Syria Human Rights Act of 2012 (“ITRA”). During the quarter ended September 30, 2015, we did not engage in any transactions with Iran or with persons or entities related to Iran.

44

ITEM 6.    EXHIBITS

Exhibit No.	Description
10.1	Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 2 Liquefaction Facility, dated as of December 20, 2012, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: the Change Order CO-00019 East Meter Piping Tie-ins, dated August 26, 2015 (Incorporated by reference to Exhibit 10.1 to Sabine Pass Liquefaction, LLC’s Quarterly Report on Form 10-Q (SEC File No. 333-192373), filed on October 30, 2015)
10.2	Change order to the Lump Sum Turnkey Agreement for the Engineering, Procurement and Construction of the Sabine Pass LNG Stage 3 Liquefaction Facility, dated as of May 4, 2015, between Sabine Pass Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: the Change Order CO-00002 Credit to EPC Contract Value for TSA Work, dated September 17, 2015 (Incorporated by reference to Exhibit 10.2 to Sabine Pass Liquefaction, LLC’s Quarterly Report on Form 10-Q (SEC File No. 333-192373), filed on October 30, 2015)
10.3	Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement, dated as of September 4, 2015, among Sabine Pass Liquefaction, LLC, as Borrower, The Bank of Nova Scotia, as Senior Issuing Bank 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, Société Générale, as the Common Security Trustee, and the senior lenders party thereto from time to time and for the benefit of HSBC Bank USA, National Association, ING Capital LLC, Morgan Stanley Bank, N.A. and Sumitomo Mitsui Banking Corporation, as Joint Lead Arrangers, Joint Lead Bookrunners, and Co-Documentation Agents, ABN Amro Capital USA LLC, The Bank of Nova Scotia, The Bank of Tokyo-Mitsubishi UFJ, LTD. and Société Générale, as Joint Lead Arrangers, Joint Lead Bookrunners, and Co-Syndication Agents, Industrial and Commercial Bank of China Limited, New York Branch and Lloyds Bank PLC, as Mandated Lead Arrangers, and Landesbank Baden-Württemberg, New York Branch, as Manager (Incorporated by reference to Exhibit 10.1 to the Cheniere Energy Partners, L.P.’s Current Report on Form 8-K (SEC File No. 001-33366), filed on September 11, 2015)
10.4*	Change orders to the Fixed Price Separated Turnkey Agreement for the Engineering, Procurement and Construction of the Corpus Christi Stage 1 Liquefaction Facility, dated as of December 6, 2013, between Corpus Christi Liquefaction, LLC and Bechtel Oil, Gas and Chemicals, Inc.: (1) the Change Order CO-00005 Revised Buildings to Include Jetty and Geo-Tech Impact to Buildings, dated June 4, 2015, (2) the Change Order CO-00006 Marine and Dredging Execution Change, dated June 16, 2015, (3) the Change Order CO-00007 Temporary Laydown Areas, AEP Substation Relocation, Power Monitoring System for Substation, Bollards for Power Line Poles, Multiplex Interface for AEP Hecker Station, dated June 30, 2015, (4) the Change Order CO-00008 West Jetty Shroud and Fencing, Temporary Strainers on Loading Arms, Breasting and Mooring Analysis, Addition of Crossbar from Platform at Ethylene Bullets to Platform for PSV Deck, Reduction of Vapor Fence at Bed 22, Relocation of Gangway Tower, Changes in Dolphin Size, dated July 28, 2015, (5) the Change Order CO-00009 Post FEED Studies, dated July 1, 2015, (6) the Change Order CO-00010 Additional Post FEED Studies, Feed Gas ESD Valve Bypass, Flow Meter on Bog Line, Additional Simulations, FERC #43, dated July 1, 2015, (7) the Change Order CO-00011 Credit to EPC Contract Value for TSA Work, dated July 7, 2015, and (8) the Change Order CO-00012 Reduction of Provisional Sum for Operating Spares, Liquid Condensate Tie-In, Automatic Shut-Off Valve in Condensate Truck Fill Line, Firewater Monitor and Hydrant Coverage Test, dated August 11, 2015 (Portions of this exhibit have been omitted and filed separately with the SEC pursuant to a request for confidential treatment)
10.5*†+	Cheniere Energy, Inc. Retirement Policy
10.6†	Cheniere Energy, Inc. 2015 Employee Inducement Incentive Plan (Incorporated by reference to Exhibit 4.8 to the Company’s Registration Statement on Form S-8 (SEC File No. 333-207651), filed on October 29, 2015)
10.7*†	Form of Cheniere Energy, Inc. 2015 Employee Inducement Incentive Plan Restricted Stock Grant - US Form
10.8*†	Form of Cheniere Energy, Inc. 2015 Employee Inducement Incentive Plan Restricted Stock Grant - UK Form
10.9*	Amendment No. 1 of LNG Sale and Purchase Agreement (FOB), dated July 23, 2015, between Endesa S.A. (Buyer) and Corpus Christi Liquefaction, LLC (Seller)
10.10*	Amendment No. 2 of LNG Sale and Purchase Agreement (FOB), dated July 23, 2015, between Endesa S.A. (Buyer) and Corpus Christi Liquefaction, LLC (Seller)
10.11*	Amendment No. 1 of LNG Sale and Purchase Agreement (FOB), dated July 24, 2015, between Woodside Energy Trading Singapore PTE Ltd (Buyer) and Corpus Christi Liquefaction, LLC (Seller)
10.12*	Amendment No. 2 of LNG Sale and Purchase Agreement, dated July 15, 2015, between Électricité de France, S.A. and Corpus Christi Liquefaction, LLC (Seller)
10.13	Amendment No. 1 of LNG Sale and Purchase Agreement (FOB), dated August 28, 2015, between Sabine Pass Liquefaction, LLC (Seller) and Total Gas & Power North America, Inc. (Buyer) (Incorporated by reference to Exhibit 10.4 to Cheniere Energy Partner, L.P.’s Quarterly Report on Form 10-Q (SEC File No. 001-33366), filed on October 30, 2015)

45

Exhibit No.	Description
10.14	Amendment No. 1 of LNG Sale and Purchase Agreement (FOB), dated September 11, 2015, between Sabine Pass Liquefaction, LLC (Seller) and Centrica plc (Buyer) (Incorporated by reference to Exhibit 10.5 to Cheniere Energy Partner, L.P.’s Quarterly Report on Form 10-Q (SEC File No. 001-33366), filed on October 30, 2015)
10.15	Nomination and Standstill Agreement, dated August 21, 2015, by and between Cheniere Energy, Inc., Icahn Partners Master Fund LP, Icahn Partners LP, Icahn Onshore LP, Icahn Offshore LP, Icahn Capital LP, IPH GP LLC, Icahn Enterprises Holdings LP, Icahn Enterprises G.P. Inc., Beckton Corp., High River Limited Partnership, Hopper Investments LLC, Barberry Corp., Carl C. Icahn, Jonathan Christodoro and Samuel Merksamer (Incorporated by reference to Exhibit 99.1 to the Company’s Current Report on Form 8-K (SEC File No. 001-16383), filed on August 24, 2015)
10.16	Omnibus Amendment, dated as of September 24, 2015, to the Second Amended and Restated Common Terms Agreement among Sabine Pass Liquefaction, LLC, as Borrower, the representatives and agents from time to time parties thereto, and Société Générale, as the Common Security Trustee and Intercreditor Agent (Incorporated by reference to Exhibit 10.6 to Cheniere Energy Partner, L.P.’s Quarterly Report on Form 10-Q (SEC File No. 001-33366), filed on October 30, 2015)
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 of 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
101.SCH*	XBRL Taxonomy Extension Schema Document
101.CAL*	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	XBRL Taxonomy Extension Labels Linkbase Document
101.PRE*	XBRL Taxonomy Extension Presentation Linkbase Document

*	Filed herewith.
**	Furnished herewith.
†	Management contract or compensatory plan or arrangement.
+	This exhibit corrects the exhibit previously filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K, filed on June 17, 2015.

46

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:	October 29, 2015	By:	/s/ Michael J. Wortley
			Michael J. Wortley
			Senior Vice President and Chief Financial Officer
			(on behalf of the registrant and as principal financial officer)
Date:	October 29, 2015	By:	/s/ Leonard Travis
			Leonard Travis
			Vice President and Chief Accounting Officer
			(on behalf of the registrant and as principal accounting officer)

47

EX-10.4

Exhibit 10.4

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Revised Buildings to Include Jetty and Geo-Tech Impact to Buildings

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00005 DATE OF CHANGE ORDER: June 4, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Bechtel will implement design changes to accommodate additional buildings and parking space at Site to support operation and maintenance of the Facility. Changes include the following which are depicted in Exhibits A and A-1(a-d):

a. A new auxiliary material storage warehouse for storage of waste oil and miscellaneous chemicals (Exhibit A.1(a));

b. A new warehouse for GE spare parts (Exhibit A.1(b));

c. An enlarged maintenance building (Exhibit A.1(c));

d. A jetty security building (Exhibit A.1(d));

e. Concrete slabs location shown on (Exhibit A as 1(e));

f. Updated drawings to reflect the revised location of the fuel station location shown on (Exhibit A as 1(f)).

2. Per Article 6.1.B of the Agreement, Parties agree, based on Geotechnical data revealing that new building sites indicate a high potential for soil swell, Bechtel remove soil to a depth of 4-4.5 ft. (depending on building) below existing grade and replace it with structural fill. This change is being made to comply with the 100 year FEMA Base Flood Elevation requirement. Buildings affected by this Change are:

a. Warehouses 1 and 2;

b. Auxiliary Material Storage Shelter;

c. Jetty Security Building;

d. Water Treatment Building.

3. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit B and Milestone adjustments are detailed in Exhibit C.

4. The adjustments to the Aggregate Equipment Price and Aggregate Labor and Skills Price are as follows:

a. The previous Aggregate Equipment Price prior to this Change Order was *** U.S. Dollars (U.S. $***). This Change Order will amend that value and the new value shall be *** U.S. Dollars (U.S. $***).

b. The previous Aggregate Labor and Skills Price prior to this Change Order was *** U.S. Dollars (U.S. $***). This Change Order will amend that value and the new value shall be *** U.S. Dollars (U.S. $***).

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0004)	$	398,313,655
The Contract Price prior to this Change Order was	$	7,479,143,655
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be unchanged by this Change Order in the amount of	$	—
The new Contract Price including this Change Order will be	$	7,526,683,383

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: No

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
5 Aug 2015	01-JUN-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Marine and Dredging Execution Change

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00006 DATE OF CHANGE ORDER: June 16, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. The EPC Agreement stated the execution of the Marine and Dredging scopes of work would be completed by Bechtel subcontractors and was provided for in the Agreement as a Provisional Sum. Per Article 6.1.B of the Agreement, Parties agree Contractor will self-perform the engineering, procurement, and construction of the Marine portion of this work scope. Owner will self-perform the dredging, DMPA management of DMPA 2 (as noted in Attachment Y), dredge slope protection, and navigational aids (offshore) and such Work will be removed from Contractor’s scope.

a. Exhibit A of this Change Order details the Marine drawings used to form the basis of this Change Order.

b. Exhibit B of this Change Order depicts the 120 ft. wide corridor which Contractor will leave for Owner to install and maintain a dredge pipe. This corridor is shown on Exhibit B as the “Restricted Area for Disposal Pipe.”

c. Additional engineering is required to change the slope angle.

d. The cost breakdowns for the scopes of work noted above are detailed in Exhibit C of this Change Order.

e. Milestone payments are amended as presented in Exhibit D.

2. Article 1.1 of the Agreement is hereby modified by:

• Deleting the term and definition of “Marine & Dredging Provisional Sum” from the Definitions section.

3. Article 1.1 of the Agreement is hereby modified by:

• Deleting the term “Marine & Dredging Provisional Sum” from the definition of “Provisional Sum”,

4. Article 6.2.A.12 of the Agreement is hereby deleted.

5. Article 7.1 of the Agreement is hereby amended by deleting the phrase “Marine and Dredging Provisional Sum.”

6. “Marine Facilities” will be removed from list of Major Subcontracts Article 1.3 of Attachment G of the Agreement.

7. The “Marine Facilities” section as well as the listed approved subcontractors will be removed from Article 1.7 of Attachment G of the Agreement.

8. Article 2 of Schedule EE-2 in Attachment EE of the Agreement hereby modified by:

• Deleting the term “Marine & Dredging Provisional Sum” from the Introduction paragraph.

9. Article 2.2 of Schedule EE-2 in Attachment EE of the Agreement will be deleted to remove reference to, and the description of, the “Marine & Dredging Provisional Sum.”

10. The adjustments to the Aggregate Equipment Price, Aggregate Labor and Skills Price, and Aggregate Provisional Sum are as follows:

a. The previous Aggregate Equipment Price prior to this Change Order was *** U.S. Dollars (U.S. $***). This Change Order will amend that value and the new value shall be *** U.S. Dollars (U.S. $***).

b. The previous Aggregate Labor and Skills Price prior to this Change Order was ** U.S. Dollars (U.S. $***). This Change Order will amend that value and the new value shall be *** U.S. Dollars (U.S. $***).

c. The Aggregate Provisional Sum specified in Article 7.1C of the Agreement prior to this Change Order was Five Hundred Sixty Three Million, Nine Hundred Eighty Three Thousand, Twenty Two U.S. Dollars (U.S. $563,983,022). This Change Order will amend that value and the new value shall be Three Hundred Eighty One Million, Nine Hundred Ninety Two Thousand, Four Hundred Forty Six U.S. Dollars (U.S. $381,992,446).

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0005)	$	445,853,383
The Contract Price prior to this Change Order was	$	7,526,683,383
The Aggregate Equipment Price will be decreased by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be decreased by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be decreased by this Change Order in the amount of	$	***
The new Contract Price including this Change Order will be	$	7,503,963,846

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: No

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
9/28/2015	16-Jun-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Temporary Laydown Areas, AEP Substation Relocation, Power Monitoring System for Substation, Bollards for Power Line Poles, Multiplex Interface for AEP Hecker Station

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00007 DATE OF CHANGE ORDER: June 30, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Contractor will design the drainage for the portions of the temporary facilities listed below to meet FEMA-defined 100 year base flood elevation, and this is detailed in Exhibit A:

a. Berryman section (53.86 acres) will drain into La Quinta ditch and Green’s Bayou through 4 new outfalls;

b. The Port Laydown (110 acres) will drain into La Quinta ditch and Green’s Bayou through four (4) new outfalls;

c. The Cotton Warehouse Laydown (25.02 acres) will drain into Green’s Bayou through two (2) new outfalls;

d. Additionally, Contractor will remove the underground piping, electrical, and communication works for the temporary facilities on the 110 acre Port Laydown.

e. Contractor will increase the culvert sizes for culverts 100, 101, 102, and 103 to include headwall structures.

2. Per Article 6.1.B of the Agreement, Parties agree Contractor will extend the overhead transmission line (additional 3,000 LF) to connect the Site to the revised location of the AEP Hecker Station tie-in shown in Exhibit B.

3. Parties agree Contractor will utilize a stand-alone power monitoring system (including an HMI) that will monitor switchgear relays, breaker status, and running amperes. Specifications include:

a. Re-programmable Relays from a remote location;

b. Graphics and power displays available at HMI;

c. Alarms will signal at the HMI;

d. The HMI will be capable of archiving events for a minimum of five (5) years.

4. Parties agree Contractor will install four (4) bollards per pole around the power line poles along La Quinta Rd. Exhibit C of this Change Order depicts the location of this scope.

5. Parties agree Contractor will add two (2) multiplexer (MUX) interfaces to interconnect the Owner and AEP 138kV switchgear to drive the fiber optic lines. This scope includes the addition of equipment and communication technology to provide a fiber optic path between AEP at the Hecker Station and the CCL Site. Contractor will also add an additional pole top Optical Ground Wire with fiber optic cores and associated underground fiber optic lines.

6. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit D.

7. Schedules C-1 and C-3 (Milestone Payment Schedules) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit E of this Change Order.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0006)	$	423,133,846
The Contract Price prior to this Change Order was	$	7,503,963,846
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The new Contract Price including this Change Order will be	$	7,525,376,502

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-0006)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-0006)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. See Attachment E of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Project Manager
Title	Title
11 August 2015	30-June-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

West Jetty Shroud and Fencing, Temporary Strainers on Loading Arms, Breasting and Mooring Analysis, Addition of Crossbar from Platform at Ethylene Bullets to Platform for PSV Deck, Reduction of Vapor Fence at Bed 22, Relocation of Gangway Tower, Changes in Dolphin Size

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00008 DATE OF CHANGE ORDER: July 28, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Contractor will add a shroud over the LNG lines in the jetty area and a vapor fence on the trestle over the water line. The scope includes the shroud, catwalks, catwalk crossovers, vapor fence, and fire and gas detection system for the shroud. This change is based on the FERC/DOT requirements to prevent vapor dispersion from reaching the Owner’s property boundary at a flammable level from a hole in the LNG transfer line that is 1/3 the diameter of the transfer line. Specifics of the shroud include:

a. The shroud will be designed to prevent a jet of LNG from a 10” diameter hole at any angle on the pipe from reaching the waterways;

b. The shroud will be designed to withstand design wind conditions and shall also be designed to be removed for inspection and maintenance of the LNG lines;

c. The shroud will be attached to support columns that are spaced along the length of the shroud to allow air circulation;

d. The jetty vapor fence shall be 12 feet high.

e. Details of this scope change are shown in Exhibit A of this Change Order.

2. Per Article 6.1.B of the Agreement, Parties agree Contractor will install temporary strainers for each of the three (3) LNG transfer arms. The strainers will take the following into consideration:

a. Strainers shall be robust and fit for purpose to avoid damage;

b. Strainers shall be accessible and able to be removed, cleaned, and reinstalled quickly enough to accommodate scheduled ship loading;

c. Contractor to ensure there are facilities for draining, purging, and warming of each section of the line;

d. Suitable pressure gauges shall be installed in appropriate locations to indicate condition of strainers.

e. Details of this scope change are shown in Exhibit B of this Change Order.

3. Per Article 6.1.B of the Agreement, Parties agreed Contractor shall complete an updated Breasting/Mooring analysis to validate FEED layout/mooring equipment for an updated range of sizes in LNG vessels. As a result of changes in vessels, changes to fender specifications and panel size are required. In order to meet the Owner’s requested fender contact pressure of 3.48ksf, Contractor will change the fender system to SCN 2000 E1.2.

4. Per Article 6.1.B of the Agreement, Parties agree Contractor will add a crossover platform from the Ethylene Storage Drum

platform to the PSV platform. This change is depicted in Exhibit C of this Change Order.

5. Per Article 6.1.B of the Agreement, Parties agree Contractor shall remove from its scope of work the requirement for vapor fencing on the Owner’s property line alongside Bed 22. Owner will be responsible for this scope of work. A depiction of this scope change is shown in Exhibit D of this Change Order.

6. Per Article 6.1.B of the Agreement, Parties agree that to avoid clashing between Loading Arm (A) and the Gangway Tower and Loading Arm (D) and the fire monitor tower, Contractor will relocate the gangway tower. Specifications of this relocation are:

a. Gangway central column will be offset by 7 feet 10 inches from the centerline of the turntable. The turntable is 26’7” away from the south edge of the platform (ship side);

b. The turntable will be moved closer to the gangway central column (6’11” instead of 8’9”);

c. Re-orient the gangway access stairs and landing platform 90 degrees for clear access way and to avoid clashing with the dry chemical skid;

d. Move the fire monitor tower 6 feet away from Loading Arm (D).

e. Exhibit E of this Change Order depicts this scope change.

7. Per Article 6.1.B of the Agreement, Parties agree Contractor will increase the size of the Breasting and Mooring dolphins. The dolphin cap sizes will be designed at the following minimums:

a. Breasting Dolphin: 25’ x 28’;

b. Mooring Dolphin: 28’ x 28’;

c. Contractor will also center the mooring hooks and capstan on the dolphins.

d. Exhibit F of this Change Order depicts this scope change.

8. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit G.

9. Schedules C-1 and C-3 (Milestone Payment Schedules) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit H of this Change Order.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0007)	$	444,546,502
The Contract Price prior to this Change Order was	$	7,525,376,502
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be unchanged by this Change Order in the amount of	$	—
The new Contract Price including this Change Order will be	$	7,540,978,278

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-0007)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-0007)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. See Exhibit H of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
11 Aug 2015	28-July-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Post FEED Studies

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00009 DATE OF CHANGE ORDER: July 1, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Contractor will incorporate the following base design changes into its detailed design:

a. The gas turbines will be supplied with a three (3) stage filter arrangement utilizing Camfil filters and include the inlet housing modifications and structural steel required to accommodate the three stage filters. The Camfil filters are preferred by Owner as stated in Exhibit A.

b. An additional backup fuel gas line will be installed from the pipeline inlet to all flare pilots to provide protection in the event of an outage. The details of this scope of work are depicted in Exhibit B of this Change Order.

c. Contractor to install smokeless flares utilizing forced air to comply with TCEQ and EPA requirements as depicted in Exhibit C of this Change Order.

d. Modify the design of the OSBL and Jetty Impoundment Basins to include storm water pumps which will allow for removal of the following:

i. Contents of the basin within four (4) hours;

ii. 25% of the rain flow from a ten (10) year storm, one (1) hour storm, in one (1) hour.

iii. Exhibit D of this Change Order depicts details of this scope of work.

e. Modify the drawings to show isolation of the loading lines at the LNG Transfer Arms as depicted in Exhibit E of this Change Order.

f. Contractor to design 366 feet of additional vapor fencing between the demountable flare and the OSBL rack that runs to the Marine facilities as agreed to with Owner and depicted in Exhibit F.

g. Contractor will space smaller oil-filled transformers (less than 500 gallons of oil) at a minimum distance of 5 feet from each other and from the substation. Larger transformers will be placed at a distance of at least 15 feet from each other and from the substation to facilitate maintenance. The details of this path forward are depicted in Exhibit G.

2. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit H.

3. Schedules C-1 and C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit I of this Change Order.

4. The following Exhibits are incorporated into this Change Order:

Exhibit A - Camfil Approval

Exhibit B - Backup Fuel Gas Line Scope

Exhibit C - Smokeless Air Installation Scope

Exhibit D - Implementation of the OSBL and Jetty Impoundment Scope

Exhibit E - Isolation of Loading Line Scope

Exhibit F - Vapor Fence Additions

Exhibit G - Transformer Spacing Scope

Exhibit H - Cost Breakdown of Change Order

Exhibit I - Adjustment to Payment Schedule

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (00001-00008)	$	460,148,278
The Contract Price prior to this Change Order was	$	7,540,978,278
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be unchanged by this Change Order in the amount of	$	—
The new Contract Price including this Change Order will be	$	7,557,364,259

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-0008)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-0008)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. See Exhibit I of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
11 Aug 2015	01-JUL-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Additional Post FEED Studies, Feed Gas ESD Valve Bypass, Flow Meter on Bog Line, Additional Simulations,

FERC #43

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00010 DATE OF CHANGE ORDER: July 1, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Contractor will incorporate the following base design changes into its detailed design:

a. Implement design changes to route the primary seal gas on each of the refrigerant compressors to the compressor suction making it the primary destination of the seal gas.

b. Implement design changes to remove the current nitrogen generation package and the back-up liquid N2 package from the scope of work. Control valve let-down stations will be required to reduce the Air Liquid nitrogen pressure from the pipeline. Contractor will redesign the Site layout to provide space, tie-in to the N2 pipeline, foundation required for the pressure reducing control valve stations, and temporary use of the 13,000 gallon liquid nitrogen dewar with vaporizer.

c. Implement design changes to provide an on-site aerobic sanitary sewage system. Sludge shall be removed by truck with the layout allowing for a future lift station. The effluent will be routed to the Water Treatment Plant with a backup to the Filtered/RO reject sump.

d. Exhibit A details these scope changes.

2. Per Article 6.1.B of the Agreement, Parties agree Contractor will add a 36” XV valve parallel to the Inlet Feed Gas ESD Valve to avoid a potential trip of three LNG trains when performing the DOT required annual stroke test of the Inlet Feed Gas ESD Valve. Exhibit B details this scope change.

3. Per Article 6.1.B of the Agreement, Parties agree Contractor will add flow and temperature measurement panels for the BOG line from the LNG tanks to comply with FERC requirements. Exhibit C of this Change Order depicts the locations for the measurement panels.

4. Per Article 6.1.B of the Agreement, Parties agree Contractor conducted additional simulations to determine the LNG production for a DLE recycle case run at 98 degrees Fahrenheit. Based on the results, Contractor will run an additional simulation at an agreed-upon temperature with Owner.

5. Per Article 6.1.B of the Agreement, Parties agree Contractor will ensure that the design for piping and piping nipples for hazardous fluids 2 inches or less in diameter will be no less than schedule 160 for carbon steel and no less than schedule 80 for stainless steel and will be designed to withstand external loads, including vibrational loads in the vicinity of rotating equipment and operator live loads in areas accessible by operators. This change is to comply with the FERC Final EIS.

6. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit D.

7. Schedules C-1 and C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit E of this Change Order.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-0009)	$	476,534,259
The Contract Price prior to this Change Order was	$	7,557,364,259
The Aggregate Equipment Price will be changed by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be changed by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be unchanged by this Change Order in the amount of	$	—
The new Contract Price including this Change Order will be	$	7,563,798,282

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-0009)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be changed by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-0009)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be increased by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. Exhibit E of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change

reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
11 Aug 2015	01-JULY-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Credit to EPC Contract Value for TSA Work

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00011 DATE OF CHANGE ORDER: July 7, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.2.B of the Agreement, Parties agree Contractor will credit the EPC contract value for home office professional services and third party engineering work completed under the Bechtel and Cheniere Technical Services Agreement, dated December 21, 2011. Exhibit A provides the backup to support this credit.

2. Schedules C-1 and C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit B of this Change Order.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-00010)	$	482,968,282
The Contract Price prior to this Change Order was	$	7,563,798,282
The Aggregate Equipment Price will be unchanged by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be changed by this Change Order in the amount of	$	***
The Aggregate Provisional Sum will be unchanged by this Change Order in the amount of	$	—
The new Contract Price including this Change Order will be	$	7,499,394,953

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-00010)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be changed by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-00010)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be changed by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. See Exhibit B of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MB Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Maria K. Brady
Owner	Contractor
Ed Lehotsky	Maria K. Brady
Name	Name
VP LNG Projects	Senior Vice President
Title	Title
Aug 14, 2015	07-JULY-2015
Date of Signing	Date of Signing

*** indicates material has been omitted pursuant to a Confidential Treatment Request filed with the Securities and Exchange Commission. A complete copy of this agreement has been filed separately with the Securities and Exchange Commission.

CHANGE ORDER FORM

Reduction of Provisional Sum for Operating Spares, Liquid Condensate Tie-In, Automatic Shut-Off Valve in Condensate Truck Fill Line, Firewater Monitor and Hydrant Coverage Test.

PROJECT NAME:  Corpus Christi Stage 1 Liquefaction Facility OWNER: Corpus Christi Liquefaction, LLC CONTRACTOR: Bechtel Oil, Gas and Chemicals, Inc. DATE OF AGREEMENT: December 6, 2013 CHANGE ORDER NUMBER: CO-00012 DATE OF CHANGE ORDER: August 11, 2015

The Agreement between the Parties listed above is changed as follows: (attach additional documentation if necessary)

1. Per Article 6.1.B of the Agreement, Parties agree Owner, not Contractor, will procure operating spare parts. Accordingly, the Provisional Sum for Spare Parts will be reduced from $12,272,221 to $0.

2. Per Article 6.1.B of the Agreement, Parties agree Contractor will increase the condensate pump head and motor size for the condensate transport line tie-in to the east of the Site. The location of tie-in is depicted in Exhibit A of this Change Order.

3. Per Article 6.1.B of the Agreement, Parties agree Contractor will install an automatic shut-off valve in the condensate truck fill line. The valve will be fire safe with a fail closed position. This change is in response to FERC direction and depicted in Exhibit B of this Change Order.

4. Per Article 6.1.B of the Agreement, Parties agree Contractor will conduct tests for fire water hydrant monitors and fire monitors, including elevated oscillating monitors. The test will verify the coverage of the firewater monitors and the hydrant monitors by testing the elevation and the distance of the water arc in a single, predetermined direction as indicated in Exhibit C of this Change Order.

5. The cost breakdowns for the scopes of work noted above in this Change Order are detailed in Exhibit D.

6. Schedules C-1 and C-3 (Milestone Payment Schedule) of Attachment C of the Agreement will be amended by including the milestone(s) listed in Exhibit E of this Change Order.

Adjustment to Contract Price

The original Contract Price was	$	7,080,830,000
Net change by previously authorized Change Orders (0001-00011)	$	418,564,953
The Contract Price prior to this Change Order was	$	7,499,394,953
The Aggregate Equipment Price will be changed by this Change Order in the amount of	$	***
The Aggregate Labor and Skills Price will be changed by this Change Order in the amount of	$	***
The new Contract Price including this Change Order will be	$	7,487,110,941

Adjustment to Aggregate Equipment Price

The original Aggregate Equipment Price was	$	***
Net change by previously authorized Change Orders (0001-00011)	$	***
The Aggregate Equipment Price prior to this Change Order was	$	***
The Aggregate Equipment Price will be changed by this Change Order in the amount of	$	***
The new Aggregate Equipment Price including this Change Order will be	$	***

Adjustment to Aggregate Labor and Skills Price

The original Aggregate Labor and Skills Price was	$	***
Net change by previously authorized Change Orders (0001-00011)	$	***
The Aggregate Labor and Skills Price prior to this Change Order was	$	***
The Aggregate Labor and Skills Price will be changed by this Change Order in the amount of	$	***
The new Aggregate Labor and Skills Price including this Change Order will be	$	***

Adjustment to Aggregate Provisional Sum

The original Aggregate Provisional Sum was	$	950,561,351
Net change by previously authorized Change Orders (0001-00011)	$	(568,568,905	)
The Aggregate Provisional Sum prior to this Change Order was	$	381,992,446
The Aggregate Provisional Sum will be changed by this Change Order in the amount of	$	(12,272,221	)
The new Aggregate Provisional Sum including this Change Order will be	$	369,720,225

Adjustment to dates in Project Schedule

The following dates are modified (list all dates modified; insert N/A if no dates modified): No impact to Project Schedule.

Adjustment to other Changed Criteria (insert N/A if no changes or impact; attach additional documentation if necessary)

Adjustment to Payment Schedule: Yes. See Exhibit E of this Change Order.

Adjustment to Minimum Acceptance Criteria: N/A

Adjustment to Performance Guarantees: N/A

Adjustment to Design Basis: N/A

Other adjustments to liability or obligation of Contractor or Owner under the Agreement: N/A

Select either A or B:

[A] This Change Order shall constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall be deemed to compensate Contractor fully for such change. Initials:

/s/ MV Contractor /s/ EL Owner

[B] This Change Order shall not constitute a full and final settlement and accord and satisfaction of all effects of the change reflected in this Change Order upon the Changed Criteria and shall not be deemed to compensate Contractor fully for such change. Initials: ____ Contractor ____ Owner

Upon execution of this Change Order by Owner and Contractor, the above-referenced change shall become a valid and binding part of the original Agreement without exception or qualification, unless noted in this Change Order. Except as modified by this and any previously issued Change Orders, all other terms and conditions of the Agreement shall remain in full force and effect. This Change Order is executed by each of the Parties’ duly authorized representatives.

/s/ Ed Lehotsky	/s/ Michael VanderMate
Owner	Contractor
Ed Lehotsky	Michael VanderMate
Name	Name
VP LNG Projects	Project Manager
Title	Title
9/22/2015	11 AUG 2015
Date of Signing	Date of Signing

EX-10.5

Exhibit 10.5

Cheniere Energy, Inc. Retirement Policy

Purpose: This Retirement Policy (this “Policy”) is designed to reward eligible employees of Cheniere Energy, Inc. and its subsidiaries (collectively, the “Company”) for their service and tenure. This Policy is limited to employees located in the United States and certain other jurisdictions. This Policy is not applicable in the United Kingdom or any jurisdictions in which benefits only to retirees would be a violation of applicable laws.

Definition of Qualifying Retirement

A “Qualifying Retirement” is a voluntary resignation by an employee who satisfies the Rule of 72 based on the sum of (i) the employee’s age and (ii) full years of service with the Company and/or its affiliates, provided that the employee also meets the following criteria:

• Employee must be at least age 60 and have at least 4 years of service with the Company and/or its affiliates.

• Employee must provide Human Resources with a written notice of his or her planned retirement date at least three (3) months in advance thereof, but the Company may eliminate, or decrease the length of, the notice period in its sole discretion.

• The Chief Executive Officer of the Company is not eligible for a Qualifying Retirement under this Policy, and accordingly, no retirement by the Chief Executive will be deemed to be a Qualifying Retirement.

• Employees in the United Kingdom are not eligible for Qualifying Retirements under this Policy.

• Employees in jurisdictions in which benefits only to retirees would be a violation of applicable laws (as determined by the Company in its sole discretion) are not eligible for Qualifying Retirements under this Policy.

The determination of whether an employee satisfies the criteria for a Qualifying Retirement shall be determined by the Company in its sole discretion.

Retirement Treatment

The Company will waive the continuous employment vesting provisions for Covered Incentive Awards (as described below) that are held by employees who satisfy the criteria for Qualifying Retirements, as determined by the Company in its sole discretion.

Following a Qualifying Retirement, Covered Incentive Awards will continue to vest on their original schedule notwithstanding any continuous service conditions; however, except as otherwise determined by the Company, Covered Incentive Awards will remain subject to the applicable performance-based vesting conditions, if any.

Notwithstanding anything in the Policy to the contrary, the Company may not waive any performance-based vesting conditions in Covered Incentive Awards for any Employees who could potentially be “Covered Employees” under Section 162(m) of the Internal Revenue Code of 1986, as amended (the “Code”), as determined by the Compensation Committee of the Board of Directors of the Company (the “Committee”) in its sole discretion.

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Covered IncentiveAwards

The Retirement provisions and this Policy will apply to all long-term equity and cash-based awards outstanding on the effective date of this Policy and, except as otherwise provided in this Policy or determined by the Committee, to long-term equity and cash-based awards granted after the effective date of this Policy (collectively, “Covered Incentive Awards”).

The Retirement provisions are intended to be applied only to regular long-term incentive awards and not one-time, special, and/or retention-based awards, subject to the discretion of the Committee. Accordingly, except as otherwise determined by the Committee on a case-by-case basis, this Policy will not apply to, and “Covered Incentive Awards” shall not include, new hire awards or special retention awards or other awards not part of any long-term incentive compensation program or to awards under any annual cash bonus program.

For the avoidance of doubt, the Retirement provisions, and this Policy, will apply to the following awards outstanding on the effective date of this Policy:

• All outstanding Long-Term Cash Awards under Trains 1-2;

• All outstanding Restricted Stock Awards under Trains 1-2;

• All outstanding Restricted Stock Awards under Trains 3-4; and/or

• All outstanding Phantom Unit Awards under the 2014-2018 Long-Term Cash Incentive Program.

In addition, the Retirement provisions, and this Policy, will apply to any long-term cash and/or phantom unit awards granted after the effective date of this Policy under the 2014-2018 Long-Term Cash Incentive Program or any other annual or long-term incentive compensation plan or program adopted after the effective date of this Policy, except as otherwise determined by the Committee on a case-by-case basis or otherwise provided in the applicable plan, program or award agreements.

Conditions to Retirement Treatment

The Company’s waiver of the continuous employment vesting conditions of any Covered Incentive Awards is subject to the employee’s execution and non-revocation of a release of claims in the form provided by the Company at (or within a specified time after) the time of retirement, and continued vesting is subject to compliance with the restrictive covenant provisions described below and any applicable performance vesting conditions that may apply to the Covered Incentive Awards. The restrictive covenant provisions will apply for the duration of the vesting schedule for any unvested Covered Incentive Award(s), and the employee’s failure to comply with the restrictive covenant provisions will result in the immediate forfeiture of any then-outstanding Covered Incentive Awards.

Restrictive Covenants

• If, during employment or subsequent to a Qualifying Retirement, the employee violates any of the restrictions below, he or she will immediately forfeit all unvested Covered Incentive Awards covered by this Policy.

• During employment or subsequent to a Qualifying Retirement, the employee will not, directly or indirectly, do any of the following or assist any other person, firm or entity to do any of the following: (a) solicit on behalf of another person or entity, the employment or services of, or hire or retain, any person who is employed by or is a substantially full-time consultant or independent contractor to

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the Company or any of its subsidiaries or affiliates, or was within six (6) months prior to the action; or (b) otherwise knowingly interfere in any material respect with the business of the Company or any of its subsidiaries or affiliates or the relationship with any vendor or supplier that existed prior to the date of termination of the employee’s employment with the Company.

• During employment or subsequent to a Qualifying Retirement, the employee shall not make or publish any disparaging statements (whether written, electronic or oral) regarding, or otherwise malign the business reputation of, the Company, its present and former owners, officers, employees, shareholders, directors, partners, attorneys, agents and assignees, and all other persons, firms, partnerships, or corporations in control of, under the direction of, or in any way presently or formerly associated with the Company (each, a “Released Party” and collectively the “Released Parties”).

• During employment or subsequent to a Qualifying Retirement, the employee shall maintain the confidentiality of the following information: proprietary technical and business information relating to any Company plans, analyses or strategies concerning international or domestic acquisitions, possible acquisitions or new ventures; development plans or introduction plans for products or services; unannounced products or services; operation costs; pricing of products or services; research and development; personnel information; manufacturing processes; installation, service, and distribution procedures and processes; customer lists; any know-how relating to the design, manufacture, and marketing of any of the Company's services and products, including components and parts thereof; non-public information acquired by the Company concerning the requirements and specifications of any of the Company's agents, vendors, contractors, customers and potential customers; non-public financial information, business and marketing plans, pricing and price lists; non-public matters relating to employee benefit plans; quotations or proposals given to agents or customers or received from suppliers; documents relating to any of the Company's legal rights and obligations; the work product of any attorney employed by or retained by the Company; and any other information which is sufficiently confidential, proprietary, secret to derive economic value from not being generally known including with respect to intellectual property inventions, and work product. The foregoing shall not apply to information that the employee is required to disclose by applicable law, regulation or legal process (provided that the employee provides the Company with prior notice of the contemplated disclosure and cooperates with the Company at its expense in seeking a protective order or other appropriate protection of such information).

• The Committee (in its sole discretion) may elect to subject employees to additional or other restrictive covenants in consideration for the special treatment of their long-term equity and cash awards under this Policy or otherwise. These covenants shall be without limitation to such additional or other restrictions.

Tax Matters; No Guarantee of Tax Consequences

In the event this Policy results in a taxable event for a retiree or eligible employee with respect to Covered Incentive Awards payable in shares of common stock of the Company, then any federal, state and local income, employment and other taxes required to be withheld by the Company in connection with such taxable event, shall be effectuated by withholding delivery of a number of shares of common stock of the Company having a fair market value equal to the minimum amount of such tax withholding obligations, as determined by the Company at the time of taxation, unless the employee requests to satisfy such withholding by other means (such as the employee writing a check to the Company equal to such amount or withholding from other compensation) and the Company agrees.

In the event this Policy results in a taxable event for a retiree or eligible employee with respect to Covered Incentive Awards payable in cash prior to the date that such cash-settled Covered Incentive Awards would

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otherwise be paid in accordance with its terms, then any such federal, state and local income, employment and other taxes required to be withheld by the Company in connection with such taxable event shall be effectuated by the Company accelerating payment of a portion of the Covered Incentive Awards having a net-after tax value equal to the amount of such required taxes (as determined by the Company at the time of taxation), unless the employee requests to satisfy such withholding by other means (such as the employee writing a check to the Company equal to such amount or withholding from other compensation) and the Company agrees.

The Covered Incentive Awards subject to this Policy are subject to all federal, state and local income, employment, and other taxes, and any required withholding in connection with such taxes. This Policy is intended to be exempt from, or to comply with, the requirements of Section 409A of the Code, and this Policy shall be interpreted accordingly; provided that in no event whatsoever shall the Company or any of its Affiliates be liable for any additional tax, interest or penalties that may be imposed on an employee by Code Section 409A or any damages for failing to comply with Code Section 409A or damages for noncompliance. The Company makes no commitment or guarantee to the employee that any federal or state tax treatment will apply or be available to any person eligible for benefits under this Agreement. Notwithstanding anything in this Policy to the contrary, in the event that an employee is deemed to be a “specified employee” within the meaning of Code Section 409A(a)(2)(B)(i), no payments hereunder that are “deferred compensation” subject to Code Section 409A shall be made to the employee prior to the date that is six (6) months after the date of the employee’s “separation from service” (as defined in Section 409A) or, if earlier, the employee’s date of death. Following any applicable six (6) month delay, all such delayed payments will be paid in a single lump sum on the earliest date permitted under Code Section 409A that is also a business day.

Effective Date of Policy

This Policy is effective as of June 11, 2015.

Amendment; Termination

This Policy can be amended, modified, or terminated at any time at the discretion of the Committee or the Board, provided it shall not affect any employees who retire or have previously delivered written notice of retirement prior to such amendment, modification, or termination.

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EX-10.7

Exhibit 10.7

CHENIERE ENERGY, INC.

2015 EMPLOYEE INDUCEMENT INCENTIVE PLAN

RESTRICTED STOCK GRANT

1.Grant of Restricted Shares.   Cheniere Energy, Inc., a Delaware corporation (the “Company”), hereby grants to _________ (“Participant”) all rights, title and interest in the record and beneficial ownership of ___________ (__) shares (the “Restricted Shares”) of common stock, $0.003 par value per share, of the Company (“Common Stock”), under the Company’s 2015 Employee Inducement Incentive Plan (as amended or restated from time to time, the “Plan”), subject to the conditions described in this grant of Restricted Stock (the “Grant”) and the Plan. The Restricted Shares are granted, effective as of the ___ day of ___, 201_ (the “Grant Date”). Unless otherwise defined in this Grant, capitalized terms used herein shall have the meanings assigned to them in the Plan. The grant of Restricted Shares under the Plan and this Grant is intended to qualify as an inducement grant to a new employee under NYSE MKT Company Guide Section 711(a).

2.Effect of the Plan. The Restricted Shares granted to Participant are subject to all of the provisions of the Plan and this Grant, together with all of the rules and determinations from time to time issued by the Committees and by the Board pursuant to the Plan; provided, however, that in the event of a conflict between any provision of the Plan and this Grant document, the provisions of this Grant document shall control but only to the extent such conflict is permitted under the Plan. The Company hereby reserves the right to amend, modify, restate, supplement or terminate the Plan without the consent of Participant, so long as such amendment, modification, restatement or supplement shall not materially reduce the rights and benefits available to Participant hereunder, and this Grant shall be subject, without further action by the Company or Participant, to such amendment, modification, restatement or supplement unless provided otherwise therein.

3.Issuance and Transferability. The Restricted Shares may be evidenced in such manner as the Company shall deem appropriate, including, without limitation, book-entry registration with the Company’s transfer agent or issuance of a stock certificate or certificates. In the event any stock certificate is issued in respect of the Restricted Shares, such certificate shall be registered in the name of the Participant and

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shall bear an appropriate legend referring to the terms, conditions and restrictions applicable to such Restricted Shares and shall be held by the Company or by an escrow agent designated by the Company until the forfeiture restrictions described in Paragraph 4 of this Grant expire and all required withholding obligations as described in Paragraph 11 of this Grant and the provisions of the Plan have been satisfied. The Restricted Shares are not transferable except by will or the laws of descent and distribution or as otherwise permitted under Section 14(f) of the Plan. No right or benefit hereunder shall in any manner be subject to any debts, contracts, liabilities, or torts of Participant or otherwise made subject to execution, attachment or similar process except as provided in Section 14(f) of the Plan.

4.Risk of Forfeiture. Except as otherwise provided herein, Participant shall, without further action of any kind by the Company or Participant, immediately forfeit all rights to any non-vested portion of the Restricted Shares in the event of termination, resignation or removal from employment with the Company. Restricted Shares that are forfeited shall be deemed to be immediately transferred to the Company without any payment by the Company or action by Participant, and the Company shall have the full and absolute right to cancel any evidence of Participant’s ownership of such forfeited Restricted Shares and to take any other action necessary to demonstrate the Participant no longer owns such forfeited Restricted Shares. Following any such forfeiture, Participant shall have no further rights with respect to the forfeited Restricted Shares. Participant, by his or her acceptance of this Grant, irrevocably grants to the Company a power of attorney to transfer Restricted Shares that are forfeited to the Company and agrees to execute any documents requested by the Company in connection with such forfeiture and transfer.

5.Vesting. The Restricted Shares shall vest and (subject to the Company's cash payment election

rights set forth in Paragraph 6 hereof) the forfeiture restrictions shall lapse during Participant’s Continuous Service in four equal annual installments (at the rate of 25 percent per year) as follows: (i) 25 percent of the Restricted Shares will vest on the date that is one year from the first day of the month containing the Grant Date (the “Initial Vesting Date”), (ii) an additional 25 percent of the Restricted Shares will vest on the first anniversary of the Initial Vesting Date, (iii) an additional 25 percent of the Restricted Shares will vest on the second anniversary of the Initial Vesting Date and (iv) the remaining portion of the Restricted Shares will vest on the third anniversary of the Initial Vesting Date. Notwithstanding the foregoing, (a) one half of each tranche of the Restricted Shares not then vested shall vest in full immediately upon the occurrence, during Participant’s Continuous Service, of a Change of Control and the remaining portion shall continue to vest pursuant to the schedule set forth in the immediately preceding sentence, provided

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that such remaining portion of the Restricted Shares not then vested shall vest in full immediately upon termination of Participant’s Continuous Service by the Company without Cause or a termination by Participant because of a “Constructive Termination,” provided, in each case, termination occurs within one year after the Change of Control and (b) any Restricted Shares not then vested shall vest in full immediately upon the death or Disability of Participant while performing Continuous Service. For purposes of this Grant, “Constructive Termination” shall mean that the Company has either (a) reduced Participant’s base salary or (b) relocated Participant to a new workplace that is more than 50 miles from such Participant’s regular workplace without consent from the Participant (such reduction or relocation, a “Termination Event”), Participant provides the Company written notice of termination within 30 days of the Termination Event which identifies and describes the applicable Termination Event (“Written Notice”), the Company does not cure the Termination Event within 30 days of receipt of Written Notice (the “Cure Period”) and Participant terminates Continuous Service within 30 days after expiration of the Cure Period. Except as otherwise provided in the foregoing, if Participant’s Continuous Service is terminated for any reason, any Restricted Shares not then vested shall not vest (except as otherwise provided herein) and shall be forfeited back to the Company.

6.Ownership Rights; Cash Payment Election Rights. Subject to the restrictions set forth in this Grant and the Plan, Participant is entitled to all voting and ownership rights applicable to the Restricted Shares, including the right to receive any cash dividends that may be paid on the Restricted Shares. Notwithstanding the foregoing, (a) any cash dividends with respect to unvested Restricted Shares shall be payable upon and subject to the vesting of the underlying Restricted Shares (and Participant shall forfeit and not be paid any such dividends in respect of Restricted Shares which are forfeited back to the Company); (b) the Committee may direct that from the time of payment of any dividend to the Company's shareholders generally until payment that dividends be (i) held in cash, with or without interest accrual, or (ii) converted into restricted stock units; (c) the dividends may be paid in the form of cash or shares of Common Stock as determined by the Committee; and (d) the dividends are intended to be exempt from Section 409A of the Internal Revenue Code and this Grant shall be interpreted accordingly. Notwithstanding anything in this Agreement to the contrary, at the time any vesting of Restricted Shares occurs pursuant to this Grant, the Company, in its sole discretion, may cancel such Restricted Shares on the applicable vesting date and pay to Participant, in consideration of such cancelation, an amount per cancelled share equal to the Fair Market Value (less applicable withholding) of such share on the applicable vesting date (such payment to be made as soon practicable following the vesting date).

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7.Reorganization of the Company. Subject to Section 13 of the Plan, the existence of this Grant shall not affect in any way the right or power of the Company or its stockholders to make or authorize any or all adjustments, recapitalizations, reorganizations or other changes in the Company’s capital structure or its business; any merger or consolidation of the Company; any issue of bonds, debentures, preferred or prior preference stock ahead of or affecting the Restricted Shares or the rights thereof; the dissolution or liquidation of the Company, or any sale or transfer of all or any part of its assets or business, or any other corporate act or proceeding, whether of a similar character or otherwise.

8.Recapitalization Events. In the event of stock dividends, spin-offs of assets or other extraordinary dividends, stock splits, combinations of shares, recapitalizations, mergers, consolidations, reorganizations, liquidations, issuances of rights or warrants and similar transactions or events involving the Company as contemplated by the Plan (“Recapitalization Events”), adjustments shall be made with respect to the Restricted Shares to the extent provided for in the Plan and then for all purposes references herein to Common Stock or to Restricted Shares shall mean and include all securities or other property (other than cash) that holders of Common Stock of the Company are entitled to receive in respect of Common Stock by reason of each successive Recapitalization Event, which securities or other property (other than cash) shall be treated in the same manner and shall be subject to the same restrictions as the underlying Restricted Shares.

9.Certain Restrictions. By accepting this Grant, Participant acknowledges that he or she has received a copy of the Plan and agrees that Participant will enter into such written representations, warranties and agreements and execute such documents as the Company may reasonably request in order to comply with applicable securities law and other applicable laws, rules or regulations, or with this document or the terms of the Plan.

10.Amendment and Termination; Waiver. This Grant, together with the Plan, constitutes the entire agreement by the Participant and the Company with respect to the subject matter hereof, and supersedes any and all prior agreements or understandings between the Participant and the Company with respect to the subject matter hereof, whether written or oral. Except as provided otherwise in Paragraph 2, no amendment or termination of this Grant shall be made by the Company at any time without the written consent of Participant. Any provision for the benefit of the Company contained in this Grant may be waived

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in writing, either generally or in any particular instance, by the Company. A waiver on one occasion shall not be deemed to be a waiver of the same or any other breach on a future occasion.     

11.Withholding of Taxes. All payments under the terms of the Grant shall be subject to, and reduced by, any amount of federal, state and local income, employment and other taxes required to be withheld by the Company in connection with such payments. Participant agrees that, if he or she makes a timely election under Section 83(b) of the Internal Revenue Code of 1986, as amended, with regard to the Restricted Shares, Participant will so notify the Company in writing at the time Participant makes such election and provide a copy thereof to the Company, so as to enable the Company to timely comply with any applicable governmental reporting requirements and any required withholding obligations. The Company shall have the right to take any action as may be necessary or appropriate to satisfy any required federal, state or local tax withholding obligations, provided, however, that except as otherwise agreed in writing by the Participant and the Company, if Participant is an Executive Officer or an individual subject to Rule 16b-3, such tax withholding obligations will be effectuated by the Company withholding a number of shares of Common Stock from the Grant having a Fair Market Value equal to the amount of such tax withholding obligations (at the minimum withholding tax rate required by the Code). The Company’s obligation to deliver Restricted Shares to Participant upon the vesting of such shares is subject to the satisfaction of any and all applicable federal, state and local income and employment tax withholding requirements.

12.No Guarantee of Tax Consequences. The Grant is intended to be exempt from or to comply with the requirements of Section 409A of the Code and the Grant shall be interpreted accordingly.The Company makes no commitment or guarantee to Participant that any federal or state tax treatment will apply or be available to any person eligible for benefits under this Grant.

13. Severability; Interpretive Matters. In the event that any provision of this Grant shall be held illegal, invalid, or unenforceable for any reason, such provision shall be fully severable and shall not affect the remaining provisions of this Grant, and the Grant shall be construed and enforced as if the illegal, invalid, or unenforceable provision had never been included herein. Whenever required by the context, pronouns and any variation thereof shall be deemed to refer to the masculine, feminine, or neuter, and the singular shall include the plural and vice versa. The captions and headings used in the Grant are inserted for convenience and shall not be deemed a part of the Grant granted hereunder for construction or interpretation.

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14.Crediting Par Value. In connection with the issuance of the Restricted Shares pursuant to this Grant and as a result of the expectations of the Company and Participant of Participant’s performance of future services for the Company or an Affiliate, the Company will transfer from surplus to stated capital the aggregate par value of the Restricted Shares.

15.Governing Law. The Grant shall be construed in accordance with and governed by the laws of the State of Delaware to the extent that federal law does not supersede and preempt Delaware law (in which case such federal law shall apply).

16.No Rights To Continued Employment. Nothing in this Grant shall confer upon the Participant any right to continued employment with the Company (or its Affiliates or their respective successors) or to interfere in any way with the right of the Company (or its Affiliates or their respective successors) to terminate the Participant’s employment at any time.

17.Counterparts. This Grant may be signed in any number of counterparts, each of which will be an original, with the same force and effect as if the signature thereto and hereto were upon the same instrument.

[Remainder of Page Blank - Signature Page Follows]

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IN WITNESS WHEREOF, the Company has executed the Grant as of the date first above written.

CHENIERE ENERGY, INC.
By:
	Ann Raden
	Vice President, Human Resources & Administration

I hereby accept the Grant subject to all of the terms and provisions hereof. I acknowledge and agree that the Grant shall vest and become payable, if at all, only during the period of my continued service with the Company or as otherwise provided in the Grant (not through the act of issuing the Grant).

By:
	Participant

[Signature Page to Restricted Stock Grant under the 2015 Employee Inducement Incentive Plan]

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EX-10.8

Exhibit 10.8

CHENIERE ENERGY, INC.

2015 EMPLOYEE INDUCEMENT INCENTIVE PLAN

RESTRICTED STOCK GRANT

1.Grant of Restricted Shares.   Cheniere Energy, Inc., a Delaware corporation (the “Company”), hereby grants to _________ (“Participant”) all rights, title and interest in the record and beneficial ownership of ___________ (__) shares (the “Restricted Shares”) of common stock, $0.003 par value per share, of the Company (“Common Stock”), under the Company’s 2015 Employee Inducement Incentive Plan (as amended or restated from time to time, the “Plan”), subject to the conditions described in this grant of Restricted Stock (the “Grant”) and the Plan. The Restricted Shares are granted, effective as of the ___ day of ___, 201_ (the “Grant Date”). Unless otherwise defined in this Grant, capitalized terms used herein shall have the meanings assigned to them in the Plan. The grant of Restricted Shares under the Plan and this Grant is intended to qualify as an inducement grant to a new employee under NYSE MKT Company Guide Section 711(a).

2.Effect of the Plan. The Restricted Shares granted to Participant are subject to all of the provisions of the Plan and this Grant, together with all of the rules and determinations from time to time issued by the Committees and by the Board pursuant to the Plan; provided, however, that in the event of a conflict between any provision of the Plan and this Grant document, the provisions of this Grant document shall control but only to the extent such conflict is permitted under the Plan. The Company hereby reserves the right to amend, modify, restate, supplement or terminate the Plan without the consent of Participant, so long as such amendment, modification, restatement or supplement shall not materially reduce the rights and benefits available to Participant hereunder, and this Grant shall be subject, without further action by the Company or Participant, to such amendment, modification, restatement or supplement unless provided otherwise therein.

3.Issuance and Transferability. The Restricted Shares may be evidenced in such manner as the Company shall deem appropriate, including, without limitation, book-entry registration or issuance of a stock certificate or certificates. In the event any stock certificate is issued in respect of the Restricted Shares, such certificate shall be registered in the name of the Participant and shall bear an appropriate legend referring to the terms, conditions and restrictions applicable to such Restricted Shares and shall be

1

held by the Company or by an escrow agent designated by the Company until the forfeiture restrictions described in Paragraph 4 of this Grant expire and all required withholding obligations as described in Paragraph 14 of this Grant and the provisions of the Plan have been satisfied. The Restricted Shares are not transferable except by will or the laws of descent and distribution or as otherwise permitted under Section 14(f) of the Plan. No right or benefit hereunder shall in any manner be subject to any debts, contracts, liabilities, or torts of Participant or otherwise made subject to execution, attachment or similar process except as provided in Section 14(f) of the Plan.

4.Risk of Forfeiture. Except as otherwise provided herein, Participant shall, without further action of any kind by the Company or Participant, immediately forfeit all rights to any non-vested portion of the Restricted Shares in the event of termination, resignation or removal from employment with the Company. Restricted Shares that are forfeited shall be deemed to be immediately transferred to the Company without any payment by the Company or action by Participant, and the Company shall have the full and absolute right to cancel any evidence of Participant’s ownership of such forfeited Restricted Shares and to take any other action necessary to demonstrate the Participant no longer owns such forfeited Restricted Shares. Following any such forfeiture, Participant shall have no further rights with respect to the forfeited Restricted Shares. Participant, by his or her acceptance of this Grant, irrevocably grants to the Company a power of attorney to transfer Restricted Shares that are forfeited to the Company and agrees to execute any documents requested by the Company in connection with such forfeiture and transfer.

5.Vesting. The Restricted Shares shall vest and (subject to the Company's cash payment election rights set forth in Paragraph 6 hereof) the forfeiture restrictions shall lapse during Participant’s Continuous Service in four equal annual installments (at the rate of 25 percent per year) as follows: (i) 25 percent of the Restricted Shares will vest on the date that is one year from the first day of the month containing the Grant Date (the “Initial Vesting Date”), (ii) an additional 25 percent of the Restricted Shares will vest on the first anniversary of the Initial Vesting Date, (iii) an additional 25 percent of the Restricted Shares will vest on the second anniversary of the Initial Vesting Date and (iv) the remaining portion of the Restricted Shares will vest on the third anniversary of the Initial Vesting Date. Notwithstanding the foregoing, (a) one half of each tranche of the Restricted Shares not then vested shall vest in full immediately upon the occurrence, during Participant’s Continuous Service, of a Change of Control and the remaining portion shall continue to vest pursuant to the schedule set forth in the immediately preceding sentence, provided that such remaining portion of the Restricted Shares not then vested shall vest in full immediately upon

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termination of Participant’s Continuous Service by the Company without Cause or a termination by Participant because of a “Constructive Termination,” provided, in each case, termination occurs within one year after the Change of Control and (b) any Restricted Shares not then vested shall vest in full immediately upon the death or Disability of Participant while performing Continuous Service. For purposes of this Grant, “Constructive Termination” shall mean that the Company has either (a) reduced Participant’s base salary or (b) relocated Participant to a new workplace that is more than 50 miles from such Participant’s regular workplace without consent from the Participant (such reduction or relocation, a “Termination Event”), Participant provides the Company written notice of termination within 30 days of the Termination Event which identifies and describes the applicable Termination Event (“Written Notice”), the Company does not cure the Termination Event within 30 days of receipt of Written Notice (the “Cure Period”) and Participant terminates Continuous Service within 30 days after expiration of the Cure Period. Except as otherwise provided in the foregoing, if Participant’s Continuous Service is terminated for any reason, any Restricted Shares not then vested shall not vest (except as otherwise provided herein) and shall be forfeited back to the Company.

6.Ownership Rights; Cash Payment Election Rights. Subject to the restrictions set forth in this Grant and the Plan, Participant is entitled to all voting and ownership rights applicable to the Restricted Shares, including the right to receive any cash dividends that may be paid on the Restricted Shares. Notwithstanding the foregoing, (a) any cash dividends with respect to unvested Restricted Shares shall be payable upon and subject to the vesting of the underlying Restricted Shares (and Participant shall forfeit and not be paid any such dividends in respect of Restricted Shares which are forfeited back to the Company); (b) the Committee may direct that from the time of payment of any dividend to the Company's shareholders generally until payment that dividends be (i) held in cash, with or without interest accrual, or (ii) converted into restricted stock units; (c) the dividends may be paid in the form of cash or shares of Common Stock as determined by the Committee; and (d) the dividends are intended to be exempt from Section 409A of the Internal Revenue Code and this Grant shall be interpreted accordingly. Notwithstanding anything in this Agreement to the contrary, at the time any vesting of Restricted Shares occurs pursuant to this Grant, the Company, in its sole discretion, may cancel such Restricted Shares on the applicable vesting date and pay to Participant, in consideration of such cancelation, an amount per cancelled share equal to the Fair Market Value (less applicable withholding) of such share on the applicable vesting date (such payment to be made as soon practicable following the vesting date).

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7.Limitation on Rights.The Plan has been established voluntarily by the Company, is discretionary in nature and may be modified, suspended or terminated by the Company at any time, as provided in the Plan and this Grant. Participant’s participation in the Plan does not create a right to futher employment with the Company or any of its subsidiaries and does not interfer with the ability of the Company or Participant’s employer to terminate Participant’s employment relationship at any time with or without cause. Participant’s participation in the Plan is voluntary. The future value of the Restricted Shares is unknown and cannot be predicted with certainty. No claim or entitlement to compensation or damages arises from forfeiture or termination of the Restricted Shares or diminution in value of the Restricted Shares and Participant irrevocably releases the Company and Participant’s employer from any such claim that may arise. Except as otherwise provide in Paragraph 5 hereof, in the event of Participant’s termination of employment with the Company or Participant’s employer, Participant’s right to the Restricted Shares under the Plan will terminate effective as of of (i) the date that Participant is no longer employed or (ii) if earlier, the date the Participant gives or receives notice for termination of employment.

8.No Right to Future Grants.This Grant is voluntary and occasional and does not create any contractual or other right to receive future Restricted Shares or other Awards (as defined under the Plan) or benefits in lieu of this Grant even if Restricted Shares or other Awards have been granted repeatedly in the past. All decisions with respect to future grants of Restricted Shares or other Awards, if any, will be at the sole discretion of the Company. The Restricted Shares granted under the Plan are extraordinary items that do not constitute compensation of any kind for services of any kind rendered to the Company and are outside the scope of Participant’s employment contract, if any.

9.Extraordinary Item of Compensation.This Grant is not part of normal or expected compensation or salary for any purposes, including, but not limited to, calculating any severance, resignation, termination, redundancy, end of service payments, bonuses, long-term service awards, pension or retirement benefits or similar payments. Moreover, insofar as Participant is an employee of the Company or any Affiliate, Participant’s participation in the Plan and the rights hereunder are not part of Participant’s employment or contract of employment with the Company or any Affiliate. In the event the Participant is not an employee of the Company, this Grant will not be interpreted to form an employment contract or relationship with the Company; and furthermore, this Grant will not be interpreted to form an employment contract with Participant’s employer or any subsidiary or affiliate of the Company.

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10.    Reorganization of the Company. Subject to Section 13 of the Plan, the existence of this Grant shall not affect in any way the right or power of the Company or its stockholders to make or authorize any or all adjustments, recapitalizations, reorganizations or other changes in the Company’s capital structure or its business; any merger or consolidation of the Company; any issue of bonds, debentures, preferred or prior preference stock ahead of or affecting the Restricted Shares or the rights thereof; the dissolution or liquidation of the Company, or any sale or transfer of all or any part of its assets or business, or any other corporate act or proceeding, whether of a similar character or otherwise.

11Recapitalization Events. In the event of stock dividends, spin-offs of assets or other extraordinary dividends, stock splits, combinations of shares, recapitalizations, mergers, consolidations, reorganizations, liquidations, issuances of rights or warrants and similar transactions or events involving the Company as contemplated by the Plan (“Recapitalization Events”), adjustments shall be made with respect to the Restricted Shares to the extent provided for in the Plan and then for all purposes references herein to Common Stock or to Restricted Shares shall mean and include all securities or other property (other than cash) that holders of Common Stock of the Company are entitled to receive in respect of Common Stock by reason of each successive Recapitalization Event, which securities or other property (other than cash) shall be treated in the same manner and shall be subject to the same restrictions as the underlying Restricted Shares.

12.Certain Restrictions. By accepting this Grant, Participant acknowledges that he or she has received a copy of the Plan and agrees that Participant will enter into such written representations, warranties and agreements and execute such documents as the Company may reasonably request in order to comply with applicable securities law and other applicable laws, rules or regulations, or with this document or the terms of the Plan.

13.Amendment and Termination; Waiver. This Grant, together with the Plan, constitutes the entire agreement by the Participant and the Company with respect to the subject matter hereof, and supersedes any and all prior agreements or understandings between the Participant and the Company with respect to the subject matter hereof, whether written or oral. Except as provided otherwise in Paragraph 2, no amendment or termination of this Grant shall be made by the Company at any time without the written consent of Participant. Any provision for the benefit of the Company contained in this Grant may be waived

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in writing, either generally or in any particular instance, by the Company. A waiver on one occasion shall not be deemed to be a waiver of the same or any other breach on a future occasion.     

14.Tax Reporting and Tax Payment Liability. Regardless of any action the Company or Participant’s employer takes with respect to any or all income tax, social insurance, payroll tax, payment on account or other tax-related withholding (“Tax-Related Items”), the ultimate liability for all Tax-Related Items is and remains Participant’s responsibility and the Company and/or Participant’s employer (a) make no representations or undertakings regarding the treatment of any Tax-Related Items in connection with any aspect of the grant or vesting of the Restricted Shares and the subsequent sale of shares of Common Stock and (b) do not commit to structure the terms of the Grant or any aspect of the Restricted Shares to reduce or eliminate Participant’s liability for Tax-Related Items.

Prior to the each of the grant and vesting of the Restricted Shares, as applicable, Participant shall pay or make adequate arrangements satisfactory to the Company and/or Participant’s employer to satisfy all withholding and payment on account obligations of the Company and/or Participant’s employer. In this regard, Participant authorizes the Company and/or Participant’s employer to withhold all applicable Tax-Related Items legally payable by Participant from Participant’s wages or other cash compensation paid to Participant by the Company and/or Participant’s employer or from proceeds of the sale of shares of Common Stock. Participant shall pay to the Company or Participant’s employer any amount of Tax-Related Items that the Company or the Participant’s employer may be required to withhold as a result of Participant’s participation in the Plan.

If the Company so requires as a condition of the Grant of the Restricted Shares, Participant shall (i) enter into a joint election with his or her employer section 431 of the Income Tax (Earnings and Pensions) Act 2003 in respect of the Restricted Shares within 14 days after the Grant Date and (ii) appoint the Company as his or her attorney to make any joint election and related arrangements under this Paragraph 14. Upon the making of such election, the Company and/or Participant’s employer shall have the right to take any action as may be necessary to comply with related reporting obligations and withholding obligations in respect of income tax and National Insurance Contributions which may arise from the making of such election.

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If the Participant is also subject to US taxes, Participant agrees that (a) if he or she makes a timely election under Section 83(b) of the Internal Revenue Code of 1986, as amended, with regard to the Restricted Shares, Participant will so notify the Company in writing at the time Participant makes such election and provide a copy thereof to the Company, so as to enable the Company to timely comply with any applicable governmental reporting requirements and (b) the Company shall have the right to take any action as may be necessary or appropriate to satisfy any federal, state or local tax withholding obligations, provided, however, that except as otherwise agreed in writing by the Participant and the Company, if Participant is an Executive Officer or an individual subject to Rule 16b-3 such tax withholding obligations will be effectuated by the Company withholding a number of shares of Common Stock from the Grant having a Fair Market Value equal to the amount of such tax withholding obligations (at the minimum tax rate required by the Code). The Company’s obligation to deliver Restricted Shares to Participant upon the vesting of such shares is subject to the satisfaction of any and all applicable federal, state and local income and employment tax withholding requirements.

15.Assumption of Employer NIC Liability.By accepting this Grant, to the extent allowable by applicable law, if the Company so requires, Participant consents to and agrees to satisfy any liability the Company and/or any subsidiary realizes with respect to Secondary Class 1 National Insurance Contribution payments required to be paid by the Company and/or any subsidiary in connection with the vesting of the Restricted Shares or subsequent sale of the underlying Common Stock. Participant authorizes the Company or any subsidiary to withhold any such Secondary Class 1 National Insurance Contributions from the payroll or the sale of a sufficient number of shares of Common Stock upon vesting of the Restricted Shares. In the alternative, Participant agrees to make payment on demand for such contributions by cash or check to the Company or any subsidiary that will remit such contributions to HM Revenue & Customs. If additional consents and/or any elections are required to accomplish the foregoing, Participant agrees to provide them promptly upon request. If the foregoing is not allowed under applicable law, the Company may rescind the grant of Restricted Shares.

16. Authorization of Withholding, Deduction of Payment Within 30 Days.Participant agrees and authorizes that any withholding, deduction or payment indicated in Paragraph 14 or 15 above must occur within 30 days of the grant or vesting of the Restricted Shares, as applicable. Participant acknowledges that failure to withhold, deduct or pay income tax within the 30-day period may result in an additional income tax charge arising.

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17.Data Privacy Consent. Participant explicitly and unambiguously consents to the collection, use and transfer, in electronic or other form, of Participant’s personal data as described in this document by and among, as applicable, Participant’s employer and the Company and any of its subsidiaries for the exclusive purpose of implementing, administering and managing Participant’s participation in the Plan. Participant understands that the Company and Participant’s employer hold certain personal information about Participant, including, but not limited to, Participant’s name, home address and telephone number, date of birth, social insurance number or other identification number, salary, nationality, job title, any shares of stock or directorships held in the Company, details of all Restricted Shares or any other entitlement to shares of Common Stock awarded, canceled, vested, unvested or outstanding in Participant’s favor, for the purpose of implementing, administering and managing the Plan (“Data”). Participant understands that Data may be transferred to any third parties assisting in the implementation, administration and management of the Plan, that these recipients may be located in Participant’s country, or elsewhere, and that the recipient’s country may have different data privacy laws and protections than Participant’s country. Participant understands that he or she may request a list with the names and addresses of any potential recipients of the Data by contacting the Company’s Vice President of Human Resources and Administration. Participant authorizes the recipients to receive, possess, use, retain and transfer the Data, in electronic or other form, for the purposes of implementing, administering and managing Participant’s participation in the Plan, including any requisite transfer of such Data as may be required to a broker or other third party with whom Participant may elect to deposit any shares of Common Stock acquired upon vesting of the Restricted Shares. Participant understands that Data will be held only as long as is necessary to implement, administer and manage Participant’s participation in the Plan. Participant understands that Participant may, at any time, view Data, request additional information about the storage and processing of Data, require any necessary amendments to Data or refuse or withdraw the consents herein, in any case without cost, by contacting in writing the Company’s Vice President of Human Resources and Administration. Participant understands, however, that refusing or withdrawing of consent may affect Participant’s ability to participate in the Plan. For more information on the consequences of Participant’s refusal to consent or withdrawal of consent, Participant may contact the Company’s Vice President of Human Resources and Administration.

18.Severability. In the event that any provision of this Grant shall be held illegal, invalid, or unenforceable for any reason, such provision shall be fully severable and shall not affect the remaining provisions of this Grant, and the Grant shall be construed and enforced as if the illegal, invalid, or

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unenforceable provision had never been included herein. Whenever required by the context, pronouns and any variation thereof shall be deemed to refer to the masculine, feminine, or neuter, and the singular shall include the plural and vice versa. The captions and headings used in the Grant are inserted for convenience and shall not be deemed a part of the Grant granted hereunder for construction or interpretation.

19.Crediting Par Value. In connection with the issuance of the Restricted Shares pursuant to this Grant and as a result of the expectations of the Company and Participant of Participant’s performance of future services for the Company or an Affiliate, the Company will transfer from surplus to stated capital the aggregate par value of the Restricted Shares.

20.Governing Law. The Grant shall be construed in accordance with the laws of the State of Delaware to the extent that federal law does not supersede and preempt Delaware law.

21.Counterparts. This Grant may be signed in any number of counterparts, each of which will be an original, with the same force and effect as if the signature thereto and hereto were upon the same instrument.

[Remainder of Page Blank - Signature Page Follows]

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IN WITNESS WHEREOF, the Company has executed the Grant as of the date first above written.

CHENIERE ENERGY, INC.
By:
	Ann Raden
	Vice President, Human Resources & Administration

I hereby accept the Grant subject to all of the terms and provisions hereof. I acknowledge and agree that the Grant shall vest and become payable, if at all, only during the period of my continued service with the Company or as otherwise provided in the Grant (not through the act of issuing the Grant).

By:
	Participant

[Signature Page to 2015 Employee Inducement Incentive Plan Restricted Stock Grant]

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EX-10.9

Exhibit 10.9

AMENDMENT No. 1 of LNG SALE AND PURCHASE AGREEMENT (FOB)

THIS AMENDMENT NO. 1 OF LNG SALE AND PURCHASE AGREEMENT (FOB) (this “Amendment”), dated 23 July, 2015, is hereby entered into by and between Corpus Christi Liquefaction, LLC, a Delaware limited liability company whose principal place of business is located at 700 Milam St., Suite 1900, Houston, TX 77002 (“Seller” or “CCLNG”), and Endesa S.A. (“Buyer”), a company registered in Spain whose principal place of business is located at Calle Ribera del Loira 60, 28042 Madrid, Spain. Buyer and Seller are sometimes hereinafter referred to individually as a “Party” and collectively as the “Parties”.

WHEREAS, Buyer and Seller entered into that certain LNG Sale and Purchase Agreement (FOB) dated April 7, 2014 (“SPA 2”).

WHEREAS, the Parties wish to ensure conformity of Section 26.1 (Trade Law Compliance) of SPA 2 to the requirements of the applicable orders.

WHEREAS, this Amendment is hereby entered into by the Parties pursuant to Section 24.4 (Amendments and Waiver) of SPA 2.

NOW, THEREFORE, in consideration of the mutual covenants and agreements made herein, the Parties, intending to be legally bound, hereby agree as follows:

AGREEMENT

1. Definitions. Capitalized terms used but not defined herein shall have the meaning provided in SPA 2.

2. Amendment.

Parties agree to delete Section 26.1 (Trade Law Compliance) in its entirety and replace it with the following:

“Buyer acknowledges and agrees that it will resell or transfer LNG purchased hereunder for delivery only to countries identified in Ordering Paragraph B of DOE/FE Order No. 3164, issued October 16, 2012 in FE Docket No. 12-99-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to insure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Alternatively, if Buyer resells or transfers LNG purchased hereunder to countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015 in FE Docket No. 12-97-LNG, Buyer acknowledges and agrees that it may resell or transfer LNG purchased hereunder for delivery only to the countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015, in FE Docket No. 12-97-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to ensure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Each Party agrees to comply with the Export Authorizations. If any Export Authorization requires conditions to be included in this Agreement then, within fifteen (15) days following the issuance of the Export Authorization imposing such condition, the Parties shall discuss the appropriate changes to be made to this Agreement to comply with such Export Authorization and shall amend this Agreement accordingly. Buyer represents and warrants that the final delivery of LNG received pursuant to the terms of this Agreement are

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permitted and lawful under United States of America laws and policies, including the rules, regulations, orders, policies, and other determinations of the United States Department of Energy, the Office of Foreign Assets Control of the United States Department of the Treasury and the Federal Energy Regulatory Commission, and Buyer shall not take any action which would cause any Export Authorization to be withdrawn, revoked, suspended or not renewed. Buyer shall promptly provide to Seller all information required by Seller and Cheniere Marketing, LLC, to comply with the Export Authorizations and shall provide the delivery destination reports (as described in this Section 26.1) for all LNG sold hereunder, to Seller and Cheniere Marketing, LLC, not later than the fifteenth (15th) Day of the Month following the Month in which any relevant LNG is delivered to the country of destination. In addition to the information required pursuant to this Section 26.1, such delivery destination reports shall contain any other information required by the applicable Export Authorization.”

3. Miscellaneous

a. Force and Effect. All provisions of SPA 2 not specifically amended hereby shall remain in full force and effect.

b. Further Assurances. Each Party hereby agrees to take all such action as may be necessary to effectuate fully the purposes of this Amendment, including causing this Amendment or any document contemplated herein to be duly registered, notarized, attested, consularized and stamped in any applicable jurisdiction.

c. Governing Law. This Amendment shall be governed by and construed in accordance with the laws of the State of New York (United States of America) without regard to principles of conflict of laws that would specify the use of other laws.

d. Confidentiality; Dispute Resolution; Immunity. The provisions of Section 19 (Confidentiality), Section 21.1 (Dispute Resolution), and Section 21.4 (Immunity) of SPA 2 shall apply in this Amendment as if incorporated herein mutatis mutandis on the basis that references therein to ‘the Agreement’ are to this Amendment.

e. Entire Agreement. SPA 2, as amended by this Amendment, constitutes the entire agreement between the Parties, and includes all promises and representations, express or implied, and supersedes all other prior agreements and representations, written or oral, between the Parties relating to the subject matter thereof.

f. Amendments and Waiver. This Amendment may not be supplemented, amended, modified or changed except by an instrument in writing signed by all Parties. A Party shall not be deemed to have waived any right or remedy under this Amendment by reason of such Party’s failure to enforce such right or remedy.

g. Successors. The terms and provisions of this Amendment shall inure to the benefit of and shall be binding upon the Parties and their respective successors and permitted assigns.

h. Severability. If a court of competent jurisdiction or arbitral tribunal determines that any clause or provision of this Amendment is void, illegal, or unenforceable, the other clauses and provisions of the Amendment shall remain in full force and effect and the clauses and provisions which are determined to be void, illegal, or unenforceable shall be limited so that they shall remain in effect to the maximum extent permissible by law.

i. No Third Party Beneficiaries. Except as expressly contemplated by SPA 2, nothing in this Amendment shall entitle any party other than the Parties to this Amendment to any claim, cause of action, remedy or right of any kind.

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j. Counterparts. This Amendment may be executed by signing the original or a counterpart thereof (including by facsimile or email transmission). If this Amendment is executed in counterparts, all counterparts taken together shall have the same effect as if the undersigned parties hereto had signed the same instrument.

[Remainder of page intentionally left blank]

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IN WITNESS WHEREOF, each of the undersigned Parties has caused this Amendment to be executed as of the date first above written.

SELLER:		BUYER:
Corpus Christi Liquefaction, LLC		Endesa S.A.
/s/ Grant E. McCracken		/s/ Alberto Hernández
Name:	Grant E. McCracken	Name:	Alberto Hernández
Title:	Vice President, Commercial Operations	Title:	Head of Global Gas

Signature Page to Amendment No. 1 of SPA 2

EX-10.10

Exhibit 10.10

AMENDMENT No. 2 of LNG SALE AND PURCHASE AGREEMENT (FOB)

THIS AMENDMENT NO. 2 OF LNG SALE AND PURCHASE AGREEMENT (FOB) (this “Amendment”), dated 23 July, 2015, is hereby entered into by and between Corpus Christi Liquefaction, LLC, a Delaware limited liability company whose principal place of business is located at 700 Milam St., Suite 1900, Houston, TX 77002 (“Seller” or “CCLNG”), and Endesa S.A. (“Buyer”), a company registered in Spain whose principal place of business is located at Calle Ribera del Loira 60, 28042 Madrid, Spain. Buyer and Seller are sometimes hereinafter referred to individually as a “Party” and collectively as the “Parties”.

WHEREAS, Seller and, Endesa Generación, S.A, an affiliate of Buyer, entered into that certain LNG Sale and Purchase Agreement (FOB) dated April 1, 2014 which was assigned by Endesa Generación, S.A to Buyer by a certain assignment and amendment agreement dated April 7, 2014 between Seller, Endesa Generación, S.A. and Buyer (together, “SPA 1”).

WHEREAS, the Parties wish to ensure conformity of Section 26.1 (Trade Law Compliance) of SPA 1 to the requirements of the applicable orders.

WHEREAS, this Amendment No.2 is hereby entered into by the Parties pursuant to Section 24.4 (Amendments and Waiver) of the Agreement.

NOW, THEREFORE, in consideration of the mutual covenants and agreements made herein, the Parties, intending to be legally bound, hereby agree as follows:

AGREEMENT

1. Definitions. Capitalized terms used but not defined herein shall have the meaning provided in SPA 1.

2. Amendment.

Parties agree to delete Section 26.1 (Trade Law Compliance) in its entirety and replace it with the following:

“Buyer acknowledges and agrees that it will resell or transfer LNG purchased hereunder for delivery only to countries identified in Ordering Paragraph B of DOE/FE Order No. 3164, issued October 16, 2012 in FE Docket No. 12-99-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to insure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Alternatively, if Buyer resells or transfers LNG purchased hereunder to countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015 in FE Docket No. 12-97-LNG, Buyer acknowledges and agrees that it may resell or transfer LNG purchased hereunder for delivery only to the countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015, in FE Docket No. 12-97-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to ensure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Each Party agrees to comply with the Export Authorizations. If any Export Authorization requires conditions to be included in this Agreement then, within fifteen (15) days following the issuance of the Export Authorization imposing such condition, the Parties shall discuss the appropriate changes to be made to this

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Agreement to comply with such Export Authorization and shall amend this Agreement accordingly. Buyer represents and warrants that the final delivery of LNG received pursuant to the terms of this Agreement are permitted and lawful under United States of America laws and policies, including the rules, regulations, orders, policies, and other determinations of the United States Department of Energy, the Office of Foreign Assets Control of the United States Department of the Treasury and the Federal Energy Regulatory Commission, and Buyer shall not take any action which would cause any Export Authorization to be withdrawn, revoked, suspended or not renewed. Buyer shall promptly provide to Seller all information required by Seller and Cheniere Marketing, LLC, to comply with the Export Authorizations and shall provide the delivery destination reports (as described in this Section 26.1) for all LNG sold hereunder, to Seller and Cheniere Marketing, LLC, not later than the fifteenth (15th) Day of the Month following the Month in which any relevant LNG is delivered to the country of destination. In addition to the information required pursuant to this Section 26.1, such delivery destination reports shall contain any other information required by the applicable Export Authorization.”

3. Miscellaneous

a. Force and Effect. All provisions of SPA 1 not specifically amended hereby shall remain in full force and effect.

b. Further Assurances. Each Party hereby agrees to take all such action as may be necessary to effectuate fully the purposes of this Amendment No.2, including causing this Amendment No.2 or any document contemplated herein to be duly registered, notarized, attested, consularized and stamped in any applicable jurisdiction.

c. Governing Law. This Amendment shall be governed by and construed in accordance with the laws of the State of New York (United States of America) without regard to principles of conflict of laws that would specify the use of other laws.

d. Confidentiality; Dispute Resolution; Immunity. The provisions of Section 19 (Confidentiality), Section 21.1 (Dispute Resolution), and Section 21.4 (Immunity) of SPA 1 shall apply in this Amendment as if incorporated herein mutatis mutandis on the basis that references therein to the ‘Agreement’ are to this Amendment.

e. Entire Agreement. SPA 1, as amended by this Amendment, constitutes the entire agreement between the Parties, and includes all promises and representations, express or implied, and supersedes all other prior agreements and representations, written or oral, between the Parties relating to the subject matter thereof.

f. Amendments and Waiver. This Amendment may not be supplemented, amended, modified or changed except by an instrument in writing signed by all Parties. A Party shall not be deemed to have waived any right or remedy under this Amendment by reason of such Party’s failure to enforce such right or remedy.

g. Successors. The terms and provisions of this Amendment shall inure to the benefit of and shall be binding upon the Parties and their respective successors and permitted assigns.

h. Severability. If a court of competent jurisdiction or arbitral tribunal determines that any clause or provision of this Amendment is void, illegal, or unenforceable, the other clauses and provisions of the Amendment shall remain in full force and effect and the clauses and provisions which are determined to be void, illegal, or unenforceable shall be limited so that they shall remain in effect to the maximum extent permissible by law.

i. No Third Party Beneficiaries. Except as expressly contemplated by SPA 1, nothing in this Amendment shall entitle any party other than the Parties to this Amendment to any claim, cause of action, remedy or right of any kind.

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j. Counterparts. This Amendment may be executed by signing the original or a counterpart thereof (including by facsimile or email transmission). If this Amendment is executed in counterparts, all counterparts taken together shall have the same effect as if the undersigned parties hereto had signed the same instrument.

[Remainder of page intentionally left blank]

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IN WITNESS WHEREOF, each of the undersigned Parties has caused this Amendment to be executed as of the date first above written.

SELLER:		BUYER:
Corpus Christi Liquefaction, LLC		Endesa S.A.
/s/ Grant E. McCracken		/s/ Alberto Hernández
Name:	Grant E. McCracken	Name:	Alberto Hernández
Title:	Vice President, Commercial Operations	Title:	Head of Global Gas

Signature Page to Amendment No. 2 of SPA 1

EX-10.11

Exhibit 10.11

AMENDMENT No. 1 of LNG SALE AND PURCHASE AGREEMENT (FOB)

THIS AMENDMENT NO. 1 OF LNG SALE AND PURCHASE AGREEMENT (FOB) (this “Amendment”), dated 24 July, 2015, is hereby entered into by and between Corpus Christi Liquefaction, LLC, a Delaware limited liability company whose principal place of business is located at 700 Milam St., Suite 1900, Houston, TX 77002 (“Seller” or “CCLNG”), and Woodside Energy Trading Singapore PTE Ltd (“Buyer”) a company registered in Singapore whose principal place of business is located at 80 Robinson Road, #02-00, Singapore, 068898. Buyer and Seller are sometimes hereinafter referred to individually as a “Party” and collectively as the “Parties”.

WHEREAS, Buyer and Seller entered into that certain LNG Sale and Purchase Agreement (FOB) dated June 30, 2014 (the “Agreement”).

WHEREAS, the Parties wish to ensure conformity of Section 26.1 (Trade Law Compliance) of the Agreement to the requirements of the applicable orders.

WHEREAS, this Amendment is hereby entered into by the Parties pursuant to Section 24.4 (Amendments and Waiver) of the Agreement.

NOW, THEREFORE, in consideration of the mutual covenants and agreements made herein, the Parties, intending to be legally bound, hereby agree as follows:

AGREEMENT

1. Definitions. Capitalized terms used but not defined herein shall have the meaning provided in the Agreement.

2. Amendment.

Parties agree to delete Section 26.1 in its entirety and replace it with the following:

“Buyer acknowledges and agrees that it will resell or transfer LNG purchased hereunder for delivery only to countries identified in Ordering Paragraph B of DOE/FE Order No. 3164, issued October 16, 2012 in FE Docket No. 12-99-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to insure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Alternatively, if Buyer resells or transfers LNG purchased hereunder to countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015 in FE Docket No. 12-97-LNG, Buyer acknowledges and agrees that it may resell or transfer LNG purchased hereunder for delivery only to the countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015, in FE Docket No. 12-97-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to ensure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Each Party agrees to comply with the Export Authorizations. If any Export Authorization requires conditions to be included in this Agreement then, within fifteen (15) days following the issuance of the Export Authorization imposing such condition, the Parties shall discuss the appropriate changes to be made to this Agreement to comply with such Export Authorization and shall amend this Agreement accordingly. Buyer represents and warrants that the final delivery of LNG received pursuant to the terms of this Agreement are

1

permitted and lawful under United States of America laws and policies, including the rules, regulations, orders, policies, and other determinations of the United States Department of Energy, the Office of Foreign Assets Control of the United States Department of the Treasury and the Federal Energy Regulatory Commission, and Buyer shall not take any action which would cause any Export Authorization to be withdrawn, revoked, suspended or not renewed. Buyer shall promptly provide to Seller all information required by Seller and Cheniere Marketing, LLC, to comply with the Export Authorizations and shall provide the delivery destination reports (as described in this Section 26.1) for all LNG sold hereunder, to Seller and Cheniere Marketing, LLC, not later than the fifteenth (15th) Day of the Month following the Month in which any relevant LNG is delivered to the country of destination. In addition to the information required pursuant to this Section 26.1, such delivery destination reports shall contain any other information required by the applicable Export Authorization.”

3. Miscellaneous

a. Force and Effect. All provisions of the Agreement not specifically amended hereby shall remain in full force and effect.

b. Further Assurances. Each Party hereby agrees to take all such action as may be necessary to effectuate fully the purposes of this Amendment, including causing this Amendment or any document contemplated herein to be duly registered, notarized, attested, consularized and stamped in any applicable jurisdiction.

c. Governing Law. This Amendment shall be governed by and construed in accordance with the laws of the State of New York (United States of America) without regard to principles of conflict of laws that would specify the use of other laws.

d. Confidentiality; Dispute Resolution; Immunity. The provisions of Section 19 (Confidentiality), Section 21.1 (Dispute Resolution), and Section 21.4 (Immunity) of the Agreement shall apply in this Amendment as if incorporated herein mutatis mutandis on the basis that references therein to the Agreement are to this Amendment.

e. Entire Agreement. The Agreement, as amended by this Amendment, constitutes the entire agreement between the Parties, and includes all promises and representations, express or implied, and supersedes all other prior agreements and representations, written or oral, between the Parties relating to the subject matter thereof.

f. Amendments and Waiver. This Amendment may not be supplemented, amended, modified or changed except by an instrument in writing signed by all Parties. A Party shall not be deemed to have waived any right or remedy under this Amendment by reason of such Party’s failure to enforce such right or remedy.

g. Successors. The terms and provisions of this Amendment shall inure to the benefit of and shall be binding upon the Parties and their respective successors and permitted assigns.

h. Severability. If a court of competent jurisdiction or arbitral tribunal determines that any clause or provision of this Amendment is void, illegal, or unenforceable, the other clauses and provisions of the Amendment shall remain in full force and effect and the clauses and provisions which are determined to be void, illegal, or unenforceable shall be limited so that they shall remain in effect to the maximum extent permissible by law.

i. No Third Party Beneficiaries. Except as expressly contemplated by the Agreement, nothing in this Amendment shall entitle any party other than the Parties to this Amendment to any claim, cause of action, remedy or right of any kind.

j. Counterparts. This Amendment may be executed by signing the original or a counterpart thereof (including by facsimile or email transmission). If this Amendment is executed in counterparts, all

2

counterparts taken together shall have the same effect as if the undersigned parties hereto had signed the same instrument.

[Remainder of page intentionally left blank]

3

IN WITNESS WHEREOF, each of the undersigned Parties has caused this Amendment to be executed as of the date first above written.

SELLER:		BUYER:
Corpus Christi Liquefaction, LLC		Woodside Energy Trading Singapore PTE Ltd
/s/ Grant E. McCracken		/s/ Reinhardt Matisons
Name:	Grant E. McCracken	Name:	Reinhardt Matisons
Title:	Vice President, Commercial Operations	Title:	Director

Signature Page to Amendment No. 1 of LNG Sale and Purchase Agreement

EX-10.12

Exhibit 10.12

AMENDMENT No. 2 of LNG SALE AND PURCHASE AGREEMENT

THIS AMENDMENT NO. 2 OF LNG SALE AND PURCHASE AGREEMENT (this “Amendment No.2”), dated July 15th, 2015, is hereby entered into by and between Corpus Christi Liquefaction, LLC, a Delaware limited liability company whose principal place of business is located at 700 Milam St., Suite 1900, Houston, TX 77002 (“Seller” or “CCLNG”), and Electricité de France S.A. (“Buyer”) whose principal place of business is located at 20 Place de la Défense, 92000 Paris La Défense, France. Buyer and Seller are sometimes hereinafter referred to individually as a “Party” and collectively as the “Parties”.

WHEREAS, Buyer and Seller entered into that certain LNG Sale and Purchase Agreement (FOB) dated July 17, 2014, as amended by Amendment No.1 between the Parties dated February 24, 2015 (together, the “Agreement”).

WHEREAS, the Parties wish to ensure conformity of Section 26.1 (Trade Law Compliance) of the Agreement to the requirements of the applicable orders.

WHEREAS, this Amendment No.2 is hereby entered into by the Parties pursuant to Section 24.4 (Amendments and Waiver) of the Agreement.

NOW, THEREFORE, in consideration of the mutual covenants and agreements made herein, the Parties, intending to be legally bound, hereby agree as follows:

AGREEMENT

1. Definitions. Capitalized terms used but not defined herein shall have the meaning provided in the Agreement.

2. Amendment.

Parties agree to delete Section 26.1 (Trade Law Compliance) in its entirety and replace it with the following:

“Buyer acknowledges and agrees that it will resell or transfer LNG purchased hereunder for delivery only to countries identified in Ordering Paragraph B of DOE/FE Order No. 3164, issued October 16, 2012 in FE Docket No. 12-99-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to insure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Alternatively, if Buyer resells or transfers LNG purchased hereunder to countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015 in FE Docket No. 12-97-LNG, Buyer acknowledges and agrees that it may resell or transfer LNG purchased hereunder for delivery only to the countries identified in Ordering Paragraph F of DOE/FE Order No. 3638, issued May 12, 2015, in FE Docket No. 12-97-LNG and/or to purchasers that have agreed in writing to limit their direct or indirect resale or transfer of such LNG to such countries. Buyer further commits to cause a report to be provided to both Cheniere Marketing, LLC and Seller that identifies the country of destination, upon delivery, into which the exported LNG was actually delivered, and to include in any resale contract for such LNG the necessary conditions to ensure that both Cheniere Marketing, LLC and Seller are made aware of all such actual destination countries. Each Party agrees to comply with the Export Authorizations. If any Export Authorization requires conditions to be included in this Agreement then, within fifteen (15) days following the issuance of the Export Authorization imposing such condition, the Parties shall discuss the appropriate changes to be made to this Agreement to comply with such Export Authorization and shall amend this Agreement accordingly. Buyer represents and warrants that the final delivery of LNG received pursuant to the terms of this Agreement are

1

permitted and lawful under United States of America laws and policies, including the rules, regulations, orders, policies, and other determinations of the United States Department of Energy, the Office of Foreign Assets Control of the United States Department of the Treasury and the Federal Energy Regulatory Commission, and Buyer shall not take any action which would cause any Export Authorization to be withdrawn, revoked, suspended or not renewed. Buyer shall promptly provide to Seller all information required by Seller and Cheniere Marketing, LLC, to comply with the Export Authorizations and shall provide the delivery destination reports (as described in this Section 26.1) for all LNG sold hereunder, to Seller and Cheniere Marketing, LLC, not later than the fifteenth (15th) Day of the Month following the Month in which any relevant LNG is delivered to the country of destination. In addition to the information required pursuant to this Section 26.1, such delivery destination reports shall contain any other information required by the applicable Export Authorization.”

3. Miscellaneous

a. Force and Effect. All provisions of the Agreement not specifically amended hereby shall remain in full force and effect.

b. Further Assurances. Each Party hereby agrees to take all such action as may be necessary to effectuate fully the purposes of this Amendment, including causing this Amendment No.2 or any document contemplated herein to be duly registered, notarized, attested, consularized and stamped in any applicable jurisdiction.

c. Governing Law. This Amendment No.2 shall be governed by and construed in accordance with the laws of the State of New York (United States of America) without regard to principles of conflict of laws that would specify the use of other laws.

d. Confidentiality; Dispute Resolution; Immunity. The provisions of Section 19 (Confidentiality), Section 21.1 (Dispute Resolution), and Section 21.4 (Immunity) of the Agreement shall apply in this Amendment No.2 as if incorporated herein mutatis mutandis on the basis that references therein to the Agreement are to this Amendment No.2.

e. Entire Agreement. The Agreement, as amended by this Amendment No.2, constitutes the entire agreement between the Parties, and includes all promises and representations, express or implied, and supersedes all other prior agreements and representations, written or oral, between the Parties relating to the subject matter thereof.

f. Amendments and Waiver. This Amendment No.2 may not be supplemented, amended, modified or changed except by an instrument in writing signed by all Parties. A Party shall not be deemed to have waived any right or remedy under this Amendment No.2 by reason of such Party’s failure to enforce such right or remedy.

g. Successors. The terms and provisions of this Amendment No.2 shall inure to the benefit of and shall be binding upon the Parties and their respective successors and permitted assigns.

h. Severability. If a court of competent jurisdiction or arbitral tribunal determines that any clause or provision of this Amendment No.2 is void, illegal, or unenforceable, the other clauses and provisions of this Amendment No.2 shall remain in full force and effect and the clauses and provisions which are determined to be void, illegal, or unenforceable shall be limited so that they shall remain in effect to the maximum extent permissible by law.

i. No Third Party Beneficiaries. Except as expressly contemplated by the Agreement, nothing in this Amendment No.2 shall entitle any party other than the Parties to this Amendment No.2 to any claim, cause of action, remedy or right of any kind.

j. Counterparts. This Amendment No.2 may be executed by signing the original or a counterpart thereof (including by facsimile or email transmission). If this Amendment No.2 is executed in counterparts,

2

all counterparts taken together shall have the same effect as if the undersigned parties hereto had signed the same instrument.

[Remainder of page intentionally left blank]

3

IN WITNESS WHEREOF, each of the undersigned Parties has caused this Amendment to be executed as of the date first above written.

SELLER:		BUYER:
Corpus Christi Liquefaction, LLC		Electricité de France S.A.
/s/ Grant E. McCracken		/s/ Jacques Schutz
Name:	Grant E. McCracken	Name:	Jacques Schutz
Title:	Vice President, Commercial Operations	Title:	VP Gas Supply

Signature Page to Amendment No. 1 of LNG Sale and Purchase Agreement

EX-31.1

Exhibit 31.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Charif Souki, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cheniere Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)  Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)  Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.  The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a)  All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b)  Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: October 29, 2015

/s/ Charif Souki

Charif Souki

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

PURSUANT TO RULE 13a-14(a) AND 15d-14(a) UNDER THE EXCHANGE ACT

I, Michael J. Wortley, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cheniere Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b)  Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c)  Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.  The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a)  All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b)  Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 Date: October 29, 2015

/s/ Michael J. Wortley

Michael J. Wortley

Chief Financial Officer

EX-32.1

Exhibit 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

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Charif Souki, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: October 29, 2015

/s/ Charif Souki

Charif Souki
Chief Executive Officer

EX-32.2

Exhibit 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

In connection with the quarterly report of Cheniere Energy, Inc. (the “Company”) on Form 10-Q for the period ended September 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael J. Wortley, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, to my knowledge, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: October 29, 2015

/s/ Michael J. Wortley

Michael J. Wortley
Chief Financial Officer

XML

Derivative Instruments - Schedule of Notional Amounts of Outstanding Derivative Positions (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015 USD ($)
SPL Interest Rate Derivatives [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 20.0
Effective Date	Aug. 14, 2012
Maturity Date	Jul. 31, 2019
Weighted Average Fixed Interest Rate Paid	1.98%
Variable Interest Rate Received	One-month LIBOR
SPL Interest Rate Derivatives [Member] | Maximum [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 628.8
CCH Interest Rate Derivatives [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 28.8
Effective Date	May 20, 2015
Maturity Date	May 31, 2022
Weighted Average Fixed Interest Rate Paid	2.29%
Variable Interest Rate Received	One-month LIBOR
CCH Interest Rate Derivatives [Member] | Maximum [Member]
Derivative [Line Items]
Notional Amount of Interest Rate Derivatives	$ 5,500.0

XML

Business Segment Information (Details) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015 USD ($)	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) item	Sep. 30, 2014 USD ($)	Dec. 31, 2014 USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | item				2
Revenues (losses) from external customers	[1]	$ 66,059	$ 66,807	$ 202,453	$ 202,002
Intersegment revenues (losses)	[2]	0	0	0	0
Depreciation expense		21,638	16,189	59,561	48,962
Income (loss) from operations		(52,074)	(61,164)	(208,192)	(171,169)
Interest expense, net of capitalized interest		(93,566)	(46,884)	(238,664)	(130,943)
Loss before income taxes and non-controlling interest	[3]	(307,161)	(102,829)	(784,636)	(505,708)
Share-based compensation		27,451	24,655	114,107	90,972
Goodwill		76,819	76,819	76,819	76,819	$ 76,819
Total assets		18,452,259	11,785,316	18,452,259	11,785,316	$ 12,573,683
Expenditures for additions to long-lived assets		1,451,469	717,540	6,037,674	2,219,987
LNG terminal business [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1]	67,212	66,983	203,324	200,243
Intersegment revenues (losses)	[2]	233	607	827	2,113
Depreciation expense		16,775	14,817	47,787	44,033
Income (loss) from operations		27,072	(28,482)	(15,324)	(56,863)
Interest expense, net of capitalized interest		(67,589)	(46,996)	(169,899)	(131,264)
Loss before income taxes and non-controlling interest	[3]	(196,693)	(64,886)	(507,751)	(376,363)
Share-based compensation		1,316	3,278	30,233	9,840
Goodwill		76,819	76,819	76,819	76,819
Total assets		16,784,317	10,847,861	16,784,317	10,847,861
Expenditures for additions to long-lived assets		1,429,808	695,159	5,964,244	2,164,596
LNG and natural gas marketing business [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1]	(1,557)	(500)	(1,601)	482
Intersegment revenues (losses)	[2]	11,354	17,262	24,725	21,336
Depreciation expense		320	103	764	364
Income (loss) from operations		(27,117)	(6,652)	(58,667)	(33,153)
Interest expense, net of capitalized interest		(14)	0	(14)	0
Loss before income taxes and non-controlling interest	[3]	(27,665)	(7,130)	(59,871)	(34,046)
Share-based compensation		2,051	8,281	12,138	17,212
Goodwill		0	0	0	0
Total assets		552,752	65,536	552,752	65,536
Expenditures for additions to long-lived assets		403	486	2,517	1,271
Corporate and other [Member]
Segment Reporting Information [Line Items]
Revenues (losses) from external customers	[1],[4]	404	324	730	1,277
Intersegment revenues (losses)	[2],[4]	(11,587)	(17,869)	(25,552)	(23,449)
Depreciation expense	[4]	4,543	1,269	11,010	4,565
Income (loss) from operations	[4]	(52,029)	(26,030)	(134,201)	(81,153)
Interest expense, net of capitalized interest	[4]	(25,963)	112	(68,751)	321
Loss before income taxes and non-controlling interest	[3],[4]	(82,803)	(30,813)	(217,014)	(95,299)
Share-based compensation	[4]	24,084	13,096	71,736	63,920
Goodwill	[4]	0	0	0	0
Total assets	[4]	1,115,190	871,919	1,115,190	871,919
Expenditures for additions to long-lived assets	[4]	$ 21,258	$ 21,895	$ 70,913	$ 54,120
Cheniere Partners [Member]
Segment Reporting Information [Line Items]
General Partner Ownership Percentage				100.00%
Cheniere Holdings [Member]
Segment Reporting Information [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		80.10%		80.10%		80.10%
Cheniere Holdings [Member] | Cheniere Partners [Member]
Segment Reporting Information [Line Items]
Limited Partner ownership percentage				55.90%

[1] Substantially all of the LNG terminal revenues relate to regasification capacity reservation fee payments made by Total Gas & Power North America, Inc. and Chevron U.S.A. Inc. LNG and natural gas marketing and trading revenue consists primarily of the domestic marketing of natural gas imported into the Sabine Pass LNG terminal.

[2] Intersegment revenues (losses) related to our LNG and natural gas marketing segment are primarily a result of international revenue allocations using a cost plus transfer pricing methodology. These LNG and natural gas marketing segment intersegment revenues (losses) are eliminated with intersegment revenues (losses) in our Consolidated Statements of Operations.

[3] Items to reconcile loss from operations and loss before income taxes and non-controlling interest include consolidated other income (expense) amounts as presented on our Consolidated Statements of Operations primarily related to our LNG terminal segment.

[4] Includes corporate activities, business development, oil and gas exploration, development and exploitation, strategic activities and certain intercompany eliminations. These activities have been included in the corporate and other column due to the lack of a material impact that these activities have on our Consolidated Financial Statements.

XML

Long-Term Debt - Other (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	May. 31, 2013
Debt Instrument [Line Items]
Interest Costs Incurred	$ 286,000,000	$ 154,800,000	$ 707,800,000	$ 423,800,000
Interest Costs Capitalized	192,400,000	$ 107,900,000	469,200,000	$ 292,800,000
CTPL [Member] | CTPL Term Loan [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity	$ 400,000,000		$ 400,000,000		$ 400,000,000.0

XML

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]
Cash paid during the year for interest, net of amounts capitalized and deferred	$ 48,271	$ 47,152
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	356,306	287,330
Non-cash conveyance of assets	$ 13,169	$ 0

XML

Long-Term Debt - Convertible Notes (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	May. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Nov. 30, 2014
Convertible Notes [Member]
Debt Instrument [Line Items]
Interest per contractual rate	$ 46,782,000	$ 0	$ 97,991,000	$ 0
Amortization of debt discount	7,233,000	0	20,948,000	0
Amortization of debt issuance costs	1,133,000	0	1,748,000	0
Total interest expense related to the Convertible Notes	$ 55,148,000	$ 0	$ 120,687,000	$ 0
2021 Cheniere Convertible Unsecured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount								$ 1,000,000,000.0
Debt Instrument, Interest Rate, Stated Percentage	4.875%		4.875%
Debt Instrument, Convertible, Earliest date of conversion, Period after closing			1 year
Debt Instrument, Convertible, Initial Conversion Price	$ 93.64		$ 93.64
Convertible Debt								808,800,000
Debt Instrument, Convertible, Carrying Amount of Equity Component	$ 196,100,000		$ 196,100,000				$ 191,900,000	$ 191,200,000
Debt Instrument, Interest Rate, Effective Percentage	9.10%		9.10%				9.20%
Debt Instrument, Convertible, Remaining Discount Amortization Period			5 years 8 months 1 day
2025 CCH Holdco II Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	11.00%		11.00%
2025 CCH Holdco II Convertible Senior Notes [Member] | CCH Holdco II [Member]
Debt Instrument [Line Items]
Debt Instrument, Convertible, Collateral Amount, Equity Interest in Subsidiary			100.00%
2045 Cheniere Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount						$ 625,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.25%		4.25%
Debt Instrument, Convertible, Initial Conversion Price	$ 138.38		$ 138.38
Convertible Debt						304,300,000
Debt Instrument, Convertible, Carrying Amount of Equity Component	$ 194,100,000		$ 194,100,000			$ 195,700,000
Debt Instrument, Interest Rate, Effective Percentage	9.40%		9.40%
Debt Instrument, Convertible, Remaining Discount Amortization Period			29 years 6 months 1 day
Debt Instrument, Original Issue Discount	20.00%		20.00%
Debt Instrument, Convertible, Conversion Ratio per $1,000 principal amount, in shares			7.2265
CCH Holdco II [Member] | 2025 CCH Holdco II Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,000,000,000		$ 1,000,000,000		$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	11.00%		11.00%
Debt Instrument, Convertible, Collateral Amount, Equity Interest in Subsidiary			100.00%
CCH Holdco II [Member] | 2025 CCH Holdco II Convertible Senior Notes [Member] | CCH Holdco II [Member]
Debt Instrument [Line Items]
Debt Instrument, Convertible, Earliest date of conversion, Period after closing			58 months
Debt Instrument, Convertible, Percentage of Conversion 1, Discount to VWAP			10.00%
Debt Instrument, Convertible, Consecutive Trading Days to Calculate VWAP			90 days
Debt Instrument, Convertible, Percentage of Conversion 2, Discount to closing price of common stock			10.00%
CCH Holdco II [Member] | 2025 CCH Holdco II Convertible Senior Notes [Member] | Note Holders [Member]
Debt Instrument [Line Items]
Debt Instrument, Convertible, Earliest date of conversion, Period after Eligible Conversion Date			6 months
Debt Instrument, Convertible, Threshold Consecutive Trading Days 2			90 days
CCH Holdco II [Member] | 2025 CCH Holdco II Convertible Senior Notes [Member] | Stage 2 [Member]
Debt Instrument [Line Items]
Debt Instrument, Convertible, Commitment			$ 500,000,000

XML

Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 15,225,250	$ 9,246,753
LNG terminal costs [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(397,758)	(350,497)
Property, plant and equipment, net	15,000,272	9,083,373
LNG terminal [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,478,167	2,269,429
LNG terminal construction-in-process [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	12,887,040	7,155,046
LNG site and related costs, net [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	32,823	9,395
Fixed assets and other [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	(32,083)	(30,169)
Property, plant and equipment, net	224,978	163,380
Computer and office equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	11,197	7,464
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	16,737	10,733
Computer software [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	64,432	46,882
Leasehold improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	38,573	36,067
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	60,984	55,522
Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 65,138	$ 36,881

XML

Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2015

Debt Instrument [Line Items]

Schedule of Long-term Debt Instruments

As of September 30, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands): 

	Interest	September 30,			December 31,
	Rate	2015			2014
Long-term debt
2016 SPLNG Senior Notes	7.500%	$	1,665,500		$	1,665,500
2020 SPLNG Senior Notes	6.500%	420,000			420,000
2021 SPL Senior Notes	5.625%	2,000,000			2,000,000
2022 SPL Senior Notes	6.250%	1,000,000			1,000,000
2023 SPL Senior Notes	5.625%	1,500,000			1,500,000
2024 SPL Senior Notes	5.750%	2,000,000			2,000,000
2025 SPL Senior Notes	5.625%	2,000,000			—
2015 SPL Credit Facilities (1)	(2)	250,000			—
2021 Cheniere Convertible Unsecured Notes	4.875%	1,028,953			1,004,469
2025 CCH HoldCo II Convertible Senior Notes	11.000%	1,003,667			—
2045 Cheniere Convertible Senior Notes	4.250%	625,000			—
CTPL Term Loan (3)	(4)	400,000			400,000
2015 CCH Credit Facility (5)	(6)	2,428,000			—
SPL Working Capital Facility (7)	(8)	—			—
Total long-term debt		16,321,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(5,477		)	(8,998		)
2021 SPL Senior Notes		9,090			10,177
2023 SPL Senior Notes		6,570			7,088
2021 Cheniere Convertible Unsecured Notes		(174,133		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(319,579		)	—
CTPL Term Loan		(1,681		)	(2,435		)
Total long-term debt, net		$	15,835,910		$	9,806,084

(1) Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the SPL Project.

(2) Variable interest rate, at SPL’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

(3) Matures on May 28, 2017 when the full amount of the outstanding principal obligations must be repaid.

(4) Variable interest rate, at CTPL’s election, is LIBOR or the base rate plus the applicable margin. CTPL has historically elected LIBOR loans, for which the applicable margin is 3.25% and is due and payable at the end of each LIBOR period.

(5) Matures on the earlier of May 13, 2022 or the second anniversary of the completion date of the first two Trains of the CCL Project.

(6) Variable interest rate, at CCH’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion of the first two Trains of the CCL Project and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion of the first two Trains of the CCL Project and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period, and interest on base rate loans is due and payable at the end of each quarter.

(7) Matures on December 31, 2020, with various terms for underlying loans, as further described below under SPL Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the SPL Working Capital Facility or the SPL LC Agreement it replaced.

(8) Variable interest rates, based on LIBOR or the base rate, as further described below under SPL Working Capital Facility.

Schedule of Carrying Values and Estimated Fair Values of Debt Instruments

The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:

	September 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,660,023	$	1,684,923	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		410,550		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,090		1,853,386		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		930,000		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,570		1,344,614		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,765,000		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,755,000		—		—
2015 SPL Credit Facilities (2)	250,000		250,000		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	854,820		894,160		814,751		1,025,563
2025 CCH HoldCo II Convertible Senior Notes (3)	1,003,667		900,490		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	305,421		390,263		—		—
CTPL Term Loan, net of discount (2)	398,319		400,000		397,565		400,000
2015 CCH Credit Facility (2)	2,428,000		2,428,000		—		—
SPL Working Capital Facility (2)	—		—		—		—

(1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014, as applicable.

(2) 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. 

(3) 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. 

(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.

Convertible Notes [Member]

Debt Instrument [Line Items]

Schedule of Interest Expense Related to Convertible Notes

Interest expense, before capitalization, related to the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes(together, the “Convertible Notes”) consisted of the following (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Interest per contractual rate	$	46,782	$	—	$	97,991	$	—
Amortization of debt discount	7,233		—		20,948		—
Amortization of debt issuance costs	1,133		—		1,748		—
Total interest expense related to the Convertible Notes	$	55,148	$	—	$	120,687	$	—

XML

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Tax Disclosure [Abstract]
Income tax expense (benefit)	$ (69)	$ 1,971	$ 102	$ 2,147

XML

Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Accrued Liabilities [Abstract]
Interest expense and related debt fees	$ 170,254	$ 112,858
Compensation and benefits	83,581	6,425
LNG liquefaction costs	181,219	22,014
LNG terminal costs	5,987	1,077
Other accrued liabilities	16,860	26,755
Total accrued liabilities	$ 457,901	$ 169,129

XML

Derivative Instruments - Fair Value of Derivative Instruments by Balance Sheet Location (Details) - USD ($) $ in Thousands		Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Non-current derivative assets		$ 30,770	$ 11,744
Derivative liabilities		(33,839)	(23,247)
Non-current derivative liabilities		(125,473)	(267)
Commodity Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		33,238	881
Total derivative liabilities		(482)	(320)
Derivative asset (liability), net		32,756	561
Commodity Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		2,468	295
Commodity Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		30,770	586
Commodity Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(349)	(53)
Commodity Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(133)	(267)
Natural Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets	[1]	97	219
Total derivative liabilities	[1]	0	0
Derivative asset (liability), net	[1]	97	219
Natural Gas Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets	[1]	97	219
Derivative, Collateral, Right to Reclaim Cash		5,600	5,700
Natural Gas Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets	[1]	0	0
Natural Gas Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	[1]	0	0
Natural Gas Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities	[1]	0	0
Liquefaction Supply Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		33,028	662
Total derivative liabilities		(482)	(320)
Derivative asset (liability), net		32,546	342
Liquefaction Supply Derivatives [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		2,371	76
Liquefaction Supply Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		30,657	586
Liquefaction Supply Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(349)	(53)
Liquefaction Supply Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(133)	(267)
LNG Trading Derivative [Member]
Derivatives, Fair Value [Line Items]
Total derivative assets		113	0
Total derivative liabilities		0	0
Derivative asset (liability), net		113	0
LNG Trading Derivative [Member] | Other current assets [Member]
Derivatives, Fair Value [Line Items]
Other current assets		0	0
LNG Trading Derivative [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		113	0
LNG Trading Derivative [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		0	0
LNG Trading Derivative [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		0	0
Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative liabilities		(158,830)	(23,194)
Derivative asset (liability), net		(158,830)	(12,036)
Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		0	11,158
Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(33,490)	(23,194)
Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(125,340)	0
SPL Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative liabilities		(15,738)	(23,194)
Derivative asset (liability), net		(15,738)	(12,036)
SPL Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		0	11,158
SPL Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(7,039)	(23,194)
SPL Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		(8,699)	0
CCH Interest Rate Derivatives [Member]
Derivatives, Fair Value [Line Items]
Total derivative liabilities		(143,092)	0
Derivative asset (liability), net		(143,092)	0
CCH Interest Rate Derivatives [Member] | Non-current derivative assets [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative assets		0	0
CCH Interest Rate Derivatives [Member] | Derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		(26,451)	0
CCH Interest Rate Derivatives [Member] | Non-current derivative liabilities [Member]
Derivatives, Fair Value [Line Items]
Non-current derivative liabilities		$ (116,641)	$ 0

[1] Does not include collateral of $5.6 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014, respectively.

XML

Net Loss Per Share Attributable to Common Stockholders (Details) - $ / shares shares in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Weighted Average Number of Shares Outstanding, Basic		227,126	224,309	226,648	223,710
Dilutive common stock options	[1]	0	0	0	0
Weighted Average Number of Shares Outstanding, Diluted		227,126	224,309	226,648	223,710
Basic and diluted net loss per share attributable to common stockholders		$ (1.31)	$ (0.40)	$ (3.02)	$ (1.74)
Stock options and unvested stock [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of net loss per share, number of shares		8,600	13,000	8,600	12,800
Convertible Debt Securities [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive securities excluded from computation of net loss per share, number of shares		56,200		56,200

[1] Stock options and unvested stock of 8.6 million shares and 13.0 million shares for the three months ended September 30, 2015 and 2014, respectively, and 8.6 million shares and 12.8 million shares for the nine months ended September 30, 2015 and 2014, respectively, representing securities that could potentially dilute basic EPS in the future, were not included in the diluted net loss per share computations because their effect would have been anti-dilutive. In addition, 56.2 million shares in aggregate, issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes, as described in Note 7—Long-Term Debt, were not included in the computation of diluted net loss per share for the three and nine months ended September 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

XML

Long-Term Debt - Working Capital Facility (Details) - USD ($)		9 Months Ended
		Sep. 30, 2015	Dec. 31, 2014	Apr. 30, 2014
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 16,321,120,000	$ 9,989,969,000
SPL Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings	[1],[2]	0	0
SPL [Member] | SPL LC Agreement [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity				$ 325,000,000.0
Letter of Credit, Outstanding Amount			9,500,000
Letter of Credit, Drawn Amount			$ 0
SPL [Member] | SPL Working Capital Facility [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity		1,200,000,000.0
Line of Credit Facility, Remaining Borrowing Capacity		1,100,000,000
Debt Instrument, Fee Amount		$ 27,500,000
Line of Credit Facility, Number of Business Days Notice Required for Repayment of Debt Without Penalty		3 days
SPL [Member] | SPL Working Capital Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Permitted Increase		$ 760,000,000
SPL [Member] | SPL Working Capital Facility [Member] | Completion of Train Six Financing [Member] | Maximum [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Permitted Increase		390,000,000
SPL [Member] | Letter of Credit [Member]
Debt Instrument [Line Items]
Letter of Credit, Outstanding Amount		127,600,000
Letter of Credit, Drawn Amount		$ 0
SPL [Member] | Letter of Credit [Member] | Undrawn Portion [Member]
Debt Instrument [Line Items]
Letter of Credit, Commitment Fee Percentage		1.75%
SPL [Member] | Letter of Credit [Member] | Drawn Portion [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.00%
SPL [Member] | Working Capital Facility Loan [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage, per annum		0.70%
SPL [Member] | Working Capital Facility Loan [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
SPL [Member] | Working Capital Facility Loan [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.75%
SPL [Member] | Working Capital Facility Loan [Member] | Base Rate Determination Federal Funds Rate [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
SPL [Member] | Working Capital Facility Loan [Member] | Base Rate Determination LIBOR [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
SPL [Member] | Working Capital Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
Line of Credit Facility, Annual Temporary Balance Requirement, Outstanding Principal		$ 0
Line of Credit Facility, Annual Temporary Period Requirement, Number of Consecutive Business Days		5 days
SPL [Member] | Swing Line Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
Debt Instrument, Term		15 days
Line of Credit Facility, Minimum Period For Termination Date, Number of Business Days		3 days
SPL [Member] | LC Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Outstanding Borrowings		$ 0
SPL [Member] | LC Loan [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term		1 year

[1] Matures on December 31, 2020, with various terms for underlying loans, as further described below under SPL Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the SPL Working Capital Facility or the SPL LC Agreement it replaced.

[2] Variable interest rates, based on LIBOR or the base rate, as further described below under SPL Working Capital Facility.

XML

Property, Plant and Equipment

9 Months Ended

Sep. 30, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment consists of LNG terminal costs and fixed assets and other, as follows (in thousands):

	September 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,478,167		$	2,269,429
LNG terminal construction-in-process	12,887,040			7,155,046
LNG site and related costs, net	32,823			9,395
Accumulated depreciation	(397,758		)	(350,497		)
Total LNG terminal costs, net	15,000,272			9,083,373
Fixed assets and other
Computer and office equipment	11,197			7,464
Furniture and fixtures	16,737			10,733
Computer software	64,432			46,882
Leasehold improvements	38,573			36,067
Land	60,984			55,522
Other	65,138			36,881
Accumulated depreciation	(32,083		)	(30,169		)
Total fixed assets and other, net	224,978			163,380
Property, plant and equipment, net	$	15,225,250		$	9,246,753

XML

Long-Term Debt - Schedule of Long-term Debt Instruments (Details) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 16,321,120	$ 9,989,969
Total Long-Term Debt, Net		$ 15,835,910	9,806,084
2016 SPLNG Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.50%
Long-term Debt, Gross		$ 1,665,500	1,665,500
Debt Instrument, Unamortized Discount		$ (5,477)	(8,998)
2020 SPLNG Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Long-term Debt, Gross		$ 420,000	420,000
2021 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 2,000,000	2,000,000
Debt Instrument, Unamortized Premium		$ 9,090	10,177
2022 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Long-term Debt, Gross		$ 1,000,000	1,000,000
2023 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 1,500,000	1,500,000
Debt Instrument, Unamortized Premium		$ 6,570	7,088
2024 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%
Long-term Debt, Gross		$ 2,000,000	2,000,000
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
Long-term Debt, Gross		$ 2,000,000	0
2015 SPL Credit Facilities [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1],[2]	$ 250,000	0
Debt Instrument, Description of Variable Rate Basis		LIBOR
2015 SPL Credit Facilities [Member] | LIBOR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.30%
2015 SPL Credit Facilities [Member] | LIBOR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
2015 SPL Credit Facilities [Member] | Base Rate [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.75%
2021 Cheniere Convertible Unsecured Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.875%
Long-term Debt, Gross		$ 1,028,953	1,004,469
Debt Instrument, Unamortized Discount		$ (174,133)	(189,717)
2025 CCH Holdco II Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		11.00%
Long-term Debt, Gross		$ 1,003,667	0
2045 Cheniere Convertible Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.25%
Long-term Debt, Gross		$ 625,000	0
Debt Instrument, Unamortized Discount		(319,579)	0
CTPL Term Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[3],[4]	400,000	400,000
Debt Instrument, Unamortized Discount		$ (1,681)	(2,435)
Debt Instrument, Description of Variable Rate Basis		LIBOR
Debt Instrument, Basis Spread on Variable Rate		3.25%
2015 CCH Credit Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[5],[6]	$ 2,428,000	0
2015 CCH Credit Facility [Member] | LIBOR [Member] | Construction [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.25%
2015 CCH Credit Facility [Member] | LIBOR [Member] | Operations [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.50%
2015 CCH Credit Facility [Member] | Base Rate [Member] | Construction [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.25%
2015 CCH Credit Facility [Member] | Base Rate [Member] | Operations [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.50%
SPL Working Capital Facility [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[7],[8]	$ 0	$ 0

[1] Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the SPL Project.

[2] Variable interest rate, at SPL’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

[3] Matures on May 28, 2017 when the full amount of the outstanding principal obligations must be repaid.

[4] Variable interest rate, at CTPL’s election, is LIBOR or the base rate plus the applicable margin. CTPL has historically elected LIBOR loans, for which the applicable margin is 3.25% and is due and payable at the end of each LIBOR period.

[5] Matures on the earlier of May 13, 2022 or the second anniversary of the completion date of the first two Trains of the CCL Project.

[6] Variable interest rate, at CCH’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion of the first two Trains of the CCL Project and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion of the first two Trains of the CCL Project and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period, and interest on base rate loans is due and payable at the end of each quarter.

[7] Matures on December 31, 2020, with various terms for underlying loans, as further described below under SPL Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the SPL Working Capital Facility or the SPL LC Agreement it replaced.

[8] Variable interest rates, based on LIBOR or the base rate, as further described below under SPL Working Capital Facility.

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Restricted Cash - SPLNG Senior Notes Debt Service Reserve (Details)	9 Months Ended
	Sep. 30, 2015 USD ($) Rate	Dec. 31, 2014 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 652,225,000	$ 481,737,000
Non-current restricted cash	$ 118,909,000	550,811,000
2016 SPLNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.50%
2020 SPLNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
SPLNG [Member] | Sabine Pass LNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Fixed Charge, Coverage Ratio | Rate	2
SPLNG [Member] | 2016 SPLNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount	$ 1,665,500,000
Debt Instrument, Interest Rate, Stated Percentage	7.50%
SPLNG [Member] | 2020 SPLNG Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount	$ 420,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
SPLNG [Member] | Senior Notes Interest Payments [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 53,000,000	15,000,000
SPLNG [Member] | Debt Service Reserve Fund [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 76,100,000	$ 76,100,000

XML

Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2015

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow, Supplemental Disclosures

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

	Nine Months Ended September 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	48,271	$	47,152
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	356,306		287,330
Non-cash conveyance of assets	13,169		—

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Long-Term Debt - Senior Notes (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Mar. 31, 2015
2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.625%
SPLNG [Member]
Debt Instrument [Line Items]
Partners' Capital Account, Distributions	$ 267,900,000	$ 237,700,000
SPL [Member] | 2025 SPL Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 2,000,000,000.0
Debt Instrument, Interest Rate, Stated Percentage	5.625%		5.625%
Debt Instrument, Registration Period	360 days

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Restricted Cash - SPL Reserve (Details) - USD ($)	12 Months Ended
	Dec. 31, 2014	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2013
Restricted Cash Items [Line Items]
Current restricted cash	$ 481,737,000	$ 652,225,000
Non-current restricted cash	550,811,000	$ 118,909,000
2021 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2022 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		6.25%
2023 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
2024 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.75%
2025 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.625%
SPL [Member] | 2013 SPL Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity					$ 5,900,000,000
SPL [Member] | 2015 SPL Credit Facilities [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 4,600,000,000
SPL [Member] | 2021 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount					$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage					5.625%
SPL [Member] | 2022 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount					$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage					6.25%
SPL [Member] | 2023 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount					$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage					5.625%
Debt Instrument, Increase, Net	500,000,000.0
SPL [Member] | 2024 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount	$ 2,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%
SPL [Member] | 2025 SPL Senior Notes [Member]
Restricted Cash Items [Line Items]
Debt Instrument, Face Amount				$ 2,000,000,000.0
Debt Instrument, Interest Rate, Stated Percentage		5.625%		5.625%
SPL [Member] | Payment of Liabilities [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 155,800,000	$ 327,200,000
SPL [Member] | Construction Activities [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 457,100,000	$ 0

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Restricted Cash - CTPL Reserve (Details)	Sep. 30, 2015 USD ($) mi	Dec. 31, 2014 USD ($)	May. 31, 2013 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 652,225,000	$ 481,737,000
Non-current restricted cash	$ 118,909,000	550,811,000
CTPL [Member] | Creole Trail Pipeline [Member]
Restricted Cash Items [Line Items]
Length of Natural Gas Pipeline, in miles | mi	94
CTPL [Member] | CTPL Term Loan [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 400,000,000		$ 400,000,000.0
CTPL [Member] | Payment of Liabilities [Member]
Restricted Cash Items [Line Items]
Current restricted cash	11,300,000	24,900,000
CTPL [Member] | Construction And Interest Payments [Member]
Restricted Cash Items [Line Items]
Non-current restricted cash	$ 0	$ 11,300,000

XML

Restricted Cash

9 Months Ended

Sep. 30, 2015

Cash and Cash Equivalents [Abstract]

Restricted Cash

RESTRICTED CASH

Restricted cash consists of funds that are contractually restricted as to usage or withdrawal and have been presented separately from cash and cash equivalents on our Consolidated Balance Sheets. Restricted cash includes the following:

SPLNG Senior Notes Debt Service Reserve

SPLNG has consummated private offerings of an aggregate principal amount of $1,665.5 million, before discount, of 7.50% Senior Secured Notes due 2016 (the “2016 SPLNG Senior Notes”) and $420.0 million of 6.50% Senior Secured Notes due 2020 (the “2020 SPLNG Senior Notes” and collectively with the 2016 SPLNG Senior Notes, the “SPLNG Senior Notes”). Under the indentures governing the SPLNG Senior Notes (the “SPLNG Indentures”), except for permitted tax distributions, SPLNG may not make distributions until certain conditions are satisfied, including: (1) there must be on deposit in an interest payment account an amount equal to one-sixth of the semi-annual interest payment multiplied by the number of elapsed months since the last semi-annual interest payment, and (2) there must be on deposit in a permanent debt service reserve fund an amount equal to one semi-annual interest payment. Distributions are permitted only after satisfying the foregoing funding requirements, a fixed charge coverage ratio test of 2:1 and other conditions specified in the SPLNG Indentures.

As of September 30, 2015 and December 31, 2014, we classified $53.0 million and $15.0 million, respectively, as current restricted cash for the payment of current interest due. As of both September 30, 2015 and December 31, 2014, we classified the permanent debt service reserve fund of $76.1 million as non-current restricted cash. These cash accounts are controlled by a collateral trustee; therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets.

SPL Reserve

During 2013, SPL entered into four credit facilities aggregating $5.9 billion(collectively, the “2013 SPL Credit Facilities”). In June 2015, SPL entered into four credit facilities aggregating $4.6 billion(collectively, the “2015 SPL Credit Facilities”), which replaced the 2013 SPL Credit Facilities. Under the terms and conditions of the 2015 SPL Credit Facilities (and previously the 2013 SPL Credit Facilities), SPL is required to deposit all cash received into reserve accounts controlled by a collateral trustee. The usage or withdrawal of such cash is restricted to the payment of liabilities related to the natural gas liquefaction facilities that are being developed and constructed in Cameron Parish, Louisiana (the “SPL Project”); therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets.

During 2013, SPL issued an aggregate principal amount of $2.0 billion, before premium, of 5.625% Senior Secured Notes due 2021 (the “2021 SPL Senior Notes”), $1.0 billion of 6.25% Senior Secured Notes due 2022 (the “2022 SPL Senior Notes”) and $1.0 billion of 5.625% Senior Secured Notes due 2023 (the “Initial 2023 SPL Senior Notes”). During 2014, SPL issued an aggregate principal amount of $2.0 billion of 5.75% Senior Secured Notes due 2024 (the “2024 SPL Senior Notes”) and additional 5.625% Senior Secured Notes due 2023 in an aggregate principal amount of $0.5 billion, before premium (the “Additional 2023 SPL Senior Notes” and collectively with the Initial 2023 SPL Senior Notes, the “2023 SPL Senior Notes”). In March 2015, SPL issued an aggregate principal amount of $2.0 billion of 5.625% Senior Secured Notes due 2025 (the “2025 SPL Senior Notes” and collectively with the 2021 SPL Senior Notes, the 2022 SPL Senior Notes, the 2023 SPL Senior Notes and the 2024 SPL Senior Notes, the “SPL Senior Notes”). The use of cash proceeds from the SPL Senior Notes is restricted to the payment of liabilities related to the SPL Project; therefore, these amounts are shown as restricted cash on our Consolidated Balance Sheets. See Note 7—Long-Term Debt for additional details about our long-term debt.

As of September 30, 2015 and December 31, 2014, we classified $327.2 million and $155.8 million, respectively, as current restricted cash held by SPL for the payment of current liabilities, including interest payments, related to the SPL Project and zero and $457.1 million, respectively, as non-current restricted cash held by SPL for future SPL Project construction costs.

CTPL Reserve

In May 2013, CTPL entered into a $400.0 million term loan facility (the “CTPL Term Loan”). As of September 30, 2015 and December 31, 2014, we classified $11.3 million and $24.9 million, respectively, as current restricted cash held by CTPL for the payment of current liabilities and zero and $11.3 million, respectively, as non-current restricted cash held by CTPL, because the usage and withdrawal of such funds is primarily restricted to the payment of liabilities related to modifications of the 94-mile pipeline which interconnects the Sabine Pass LNG terminal with a number of large interstate pipelines (the “Creole Trail Pipeline”) in order to enable bi-directional natural gas flow, and for the payment of interest during construction of such modifications. The restricted cash reserved to pay interest during construction is controlled by a collateral agent, and can only be released by the collateral agent upon satisfaction of certain terms and conditions. CTPL is required to pay annual fees to the administrative and collateral agents.

CCH Reserve

In May 2015, CCH entered into a credit facility agreement for an aggregate commitment of approximately $11.5 billion(the “2015 CCH Credit Facility”), comprising approximately $8.4 billion linked to the first stage (“Stage 1”) of the natural gas liquefaction and export facility and pipeline facility near Corpus Christi, Texas (the “CCL Project”) and approximately $3.1 billion linked to the second stage (“Stage 2”) of the CCL Project. Stage 1 includes Trains 1 and 2, two LNG storage tanks, one complete marine berth and second partial berth and all of the project’s necessary infrastructure facilities. The pipeline facility is a 23-mile, 48” natural gas pipeline that will interconnect the Corpus Christi LNG terminal with several interstate and intrastate natural gas pipelines (the “Corpus Christi Pipeline”). Stage 2 includes Train 3, one LNG storage tank and the completion of the second partial berth. Under the terms and conditions of the 2015 CCH Credit Facility, all cash reserved to pay interest during construction is controlled by a collateral agent. These funds can only be released by the collateral agent upon satisfaction of certain terms and conditions and are classified as restricted on our Consolidated Balance Sheets. CCH is required to pay annual fees to the administrative and collateral agents. As of September 30, 2015, we classified $35.6 million and $35.7 million as current restricted cash and non-current restricted cash, respectively, held by CCH.

Other Restricted Cash

As of September 30, 2015 and December 31, 2014, $171.4 million and $250.1 million, respectively, of cash was held by SPLNG, Cheniere Partners and Cheniere Holdings that was restricted to Cheniere.  In addition, as of September 30, 2015 and December 31, 2014, $53.7 million and $35.9 million, respectively, had been classified as current restricted cash, and as of September 30, 2015 and December 31, 2014, $7.1 million and $6.3 million, respectively, had been classified as non-current restricted cash on our Consolidated Balance Sheets due to various other contractual restrictions.

XML

Restricted Cash - CCH Reserve and Other (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2015 USD ($) item mi in	May. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Restricted Cash Items [Line Items]
Current restricted cash	$ 652,225		$ 481,737
Non-current restricted cash	118,909		550,811
Subsidiary Cash [Member]
Restricted Cash Items [Line Items]
Current restricted cash	171,400		250,100
Other Contractual Restrictions [Member]
Restricted Cash Items [Line Items]
Current restricted cash	53,700		35,900
Non-current restricted cash	$ 7,100		$ 6,300
CCH [Member] | Stage 1 [Member]
Restricted Cash Items [Line Items]
Number Of LNG Storage Tanks | item	2
Number Of Complete Marine Berths | item	1
Number Of Partial Marine Berths | item	1
CCH [Member] | Stage 2 [Member]
Restricted Cash Items [Line Items]
Number Of LNG Storage Tanks | item	1
Number Of Partial Marine Berths | item	1
CCH [Member] | Corpus Christi Pipeline [Member]
Restricted Cash Items [Line Items]
Length of Natural Gas Pipeline, in miles | mi	23
Diameter of Natural Gas Pipeline, in inches | in	48
CCH [Member] | 2015 CCH Credit Facility [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 11,500,000
CCH [Member] | 2015 CCH Credit Facility [Member] | Stage 1 [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		8,400,000
CCH [Member] | 2015 CCH Credit Facility [Member] | Stage 2 [Member]
Restricted Cash Items [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 3,100,000
CCH [Member] | Construction And Interest Payments [Member]
Restricted Cash Items [Line Items]
Current restricted cash	$ 35,600
Non-current restricted cash	$ 35,700

XML

Derivative Instruments - Derivative Net Presentation on Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Natural Gas Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	$ 513	$ 223
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	(416)	(4)
Derivative Assets (Liabilities), at Fair Value, Net	97	219
Liquefaction Supply Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	33,028	662
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	33,028	662
Liquefaction Supply Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(482)	(320)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(482)	(320)
LNG Trading Derivative Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized	113
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets	0
Derivative Assets (Liabilities), at Fair Value, Net	113
SPL Interest Rate Derivatives Asset [Member]
Derivative [Line Items]
Derivative Asset, Gross Amounts Recognized		11,158
Derivative Asset, Gross Amounts Offset in the Consolidated Balance Sheets		0
Derivative Assets (Liabilities), at Fair Value, Net		11,158
SPL Interest Rate Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(15,738)	(23,194)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0	0
Derivative Assets (Liabilities), at Fair Value, Net	(15,738)	$ (23,194)
CCH Interest Rate Derivatives Liability [Member]
Derivative [Line Items]
Derivative Liability, Gross Amounts Recognized	(143,092)
Derivative Liability, Gross Amounts Offset in the Consolidated Balance Sheets	0
Derivative Assets (Liabilities), at Fair Value, Net	$ (143,092)

XML

Commitments and Contingencies (Details) shares in Millions		3 Months Ended
	Feb. 01, 2013 shares	Sep. 30, 2014 item	Sep. 30, 2015 USD ($) shares	Dec. 31, 2014 USD ($)	Jan. 31, 2013 shares
Commitments and Contingencies [Line Items]
Loss Contingency, New Claims Filed, Number | item		4
Guarantee Obligations [Member]
Commitments and Contingencies [Line Items]
Liabilities recognized under guarantee arrangements | $			$ 0	$ 0
2011 Incentive Plan [Member]
Commitments and Contingencies [Line Items]
Number of Shares Authorized	35.0		35.0		10.0
Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized	25.0

XML

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 1,340,262	$ 1,747,583
Restricted cash	652,225	481,737
Accounts and interest receivable	6,645	4,419
LNG inventory	9,032	4,294
Other current assets	78,108	20,844
Total current assets	2,086,272	2,258,877
Non-current restricted cash	118,909	550,811
Property, plant and equipment, net	15,225,250	9,246,753
Debt issuance costs, net	640,399	242,323
Non-current derivative assets	30,770	11,744
Goodwill	76,819	76,819
Other non-current assets	273,840	186,356
Total assets	18,452,259	12,573,683
Current liabilities
Accounts payable	11,558	13,426
Accrued liabilities	457,901	169,129
Deferred revenue	26,653	26,655
Derivative liabilities	33,839	23,247
Other current liabilities	268	18
Total current liabilities	530,219	232,475
Long-term debt, net	15,835,910	9,806,084
Non-current deferred revenue	10,500	13,500
Non-current derivative liabilities	125,473	267
Other non-current liabilities	$ 85,226	$ 19,840
Commitments and contingencies (see Note 11)
Stockholders’ equity
Preferred stock, $0.0001 par value, 5.0 million shares authorized, none issued	$ 0	$ 0
Common stock, $0.003 par value, Authorized: 480.0 million shares at September 30, 2015 and December 31, 2014; Issued and outstanding: 236.0 million and 236.7 million shares at September 30, 2015 and December 31, 2014, respectively	708	712
Treasury stock: 11.2 million shares and 10.6 million shares at September 30, 2015 and December 31, 2014, respectively, at cost	(337,057)	(292,752)
Additional paid-in-capital	3,029,317	2,776,702
Accumulated deficit	(3,332,851)	(2,648,839)
Total stockholders’ deficit	(639,883)	(164,177)
Non-controlling interest	2,504,814	2,665,694
Total equity	1,864,931	2,501,517
Total liabilities and equity	$ 18,452,259	$ 12,573,683

XML

Long-Term Debt - Credit Facilities (Details)		1 Months Ended		3 Months Ended		9 Months Ended
		Mar. 31, 2015 USD ($)	May. 31, 2014 USD ($)	Sep. 30, 2015 USD ($)	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) Rate	Sep. 30, 2014 USD ($)	Jun. 30, 2015 USD ($)	May. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings				$ 16,321,120,000		$ 16,321,120,000				$ 9,989,969,000
Losses on Extinguishment of Debt				0	$ 0	96,273,000	$ 114,335,000
2015 SPL Credit Facilities [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings	[1],[2]			250,000,000		$ 250,000,000				0
Debt Instrument, Description of Variable Rate Basis						LIBOR
2015 SPL Credit Facilities [Member] | SPL [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								$ 4,600,000,000
Line of Credit Facility, Remaining Borrowing Capacity				4,300,000,000		$ 4,300,000,000
Long-term Debt, Outstanding Borrowings				250,000,000		250,000,000
Debt Instrument, Fee Amount				$ 88,200,000		$ 88,200,000
Line Of Credit Facility Insurance Premium Percentage Of Drawn Amount, per annum						0.45%
Line Of Credit Facility, Unused Capacity, Commitment Fee Percentage Of Margin On Undrawn Commitment, per annum						40.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage, per annum						0.70%
Line of Credit Facility, Amortization Period						18 years
2015 SPL Credit Facilities [Member] | SPL [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives				65.00%		65.00%
2013 SPL Credit Facilities [Member] | SPL [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity											$ 5,900,000,000
Long-term Debt, Outstanding Borrowings										0
Line of Credit Facility, Decrease, Net		$ 1,800,000,000	$ 2,100,000,000
Losses on Extinguishment of Debt						$ 96,300,000
2015 CCH Credit Facility [Member]
Line of Credit Facility [Line Items]
Long-term Debt, Outstanding Borrowings	[3],[4]			$ 2,428,000,000		2,428,000,000				$ 0
2015 CCH Credit Facility [Member] | CCH [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity									$ 11,500,000,000
Line of Credit Facility, Remaining Borrowing Capacity				$ 6,000,000,000		$ 6,000,000,000
Debt Instrument, Fee Amount									289,800,000
Debt Instrument, Description of Variable Rate Basis						LIBOR
Line Of Credit Facility, Unused Capacity, Commitment Fee Percentage Of Margin On Undrawn Commitment, per annum						40.00%
Line of Credit Facility, Amortization Period						19 years
Debt Instrument, Fixed Charge, Coverage Ratio | Rate						1.55
2015 CCH Credit Facility [Member] | CCH [Member] | Stage 1 [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity									8,400,000,000
2015 CCH Credit Facility [Member] | CCH [Member] | Stage 2 [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity									$ 3,100,000,000
2015 CCH Credit Facility [Member] | CCH [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Percentage of Debt Hedged by Interest Rate Derivatives				65.00%		65.00%

[1] Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the SPL Project.

[2] Variable interest rate, at SPL’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

[3] Matures on the earlier of May 13, 2022 or the second anniversary of the completion date of the first two Trains of the CCL Project.

[4] Variable interest rate, at CCH’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion of the first two Trains of the CCL Project and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion of the first two Trains of the CCL Project and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period, and interest on base rate loans is due and payable at the end of each quarter.

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Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities
Net loss	$ (784,738)	$ (507,855)
Adjustments to reconcile net loss to net cash used in operating activities:
Non-cash LNG inventory write-downs	17,826	23,505
Depreciation expense	59,561	48,962
Share-based compensation	90,412	84,449
Amortization of debt issuance costs and discount (premium)	36,782	10,971
Loss on early extinguishment of debt	96,273	114,335
Total losses on derivatives, net	208,769	89,286
Net cash used for settlement of derivative instruments	(94,170)	(19,745)
Other	1,406	(1,975)
Changes in restricted cash for certain operating activities	92,589	102,851
Changes in operating assets and liabilities:
Accounts and interest receivable	(2,226)	(18,899)
LNG inventory	(22,564)	(26,908)
Accounts payable and accrued liabilities	10,656	62,797
Deferred revenue	(3,003)	(2,955)
Other, net	17,850	131
Net cash used in operating activities	(274,577)	(41,050)
Cash flows from investing activities
Property, plant and equipment, net	(5,747,596)	(2,047,957)
Use of restricted cash for the acquisition of property, plant and equipment	5,330,526	1,980,436
Other	(111,518)	(24,113)
Net cash used in investing activities	(528,588)	(91,634)
Cash flows from financing activities
Proceeds from issuances of long-term debt	6,178,000	2,584,500
Repayments of long-term debt	0	(177,000)
Debt issuance and deferred financing costs	(519,699)	(94,220)
Investment in restricted cash	(5,161,701)	(2,254,733)
Distributions and dividends to non-controlling interest	(60,154)	(59,478)
Proceeds from exercise of stock options	2,279	9,502
Payments related to tax withholdings for share-based compensation	(44,305)	(44,516)
Other	1,424	(557)
Net cash provided by (used in) financing activities	395,844	(36,502)
Net decrease in cash and cash equivalents	(407,321)	(169,186)
Cash and cash equivalents—beginning of period	1,747,583	960,842
Cash and cash equivalents—end of period	$ 1,340,262	$ 791,656

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Derivative Instruments - Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Natural Gas Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 97	$ 219
Natural Gas Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Natural Gas Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	97	219
Natural Gas Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Liquefaction Supply Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	32,546	342
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
Liquefaction Supply Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	32,546	342
LNG Trading Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	113	0
LNG Trading Derivative [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
LNG Trading Derivative [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	113	0
LNG Trading Derivative [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
SPL Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(15,738)	(12,036)
SPL Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
SPL Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(15,738)	(12,036)
SPL Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
CCH Interest Rate Derivatives [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(143,092)	0
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	0	0
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	(143,092)	0
CCH Interest Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net	$ 0	$ 0

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Property, plant and equipment consists of LNG terminal costs and fixed assets and other, as follows (in thousands):

	September 30,			December 31,
	2015			2014
LNG terminal costs
LNG terminal	$	2,478,167		$	2,269,429
LNG terminal construction-in-process	12,887,040			7,155,046
LNG site and related costs, net	32,823			9,395
Accumulated depreciation	(397,758		)	(350,497		)
Total LNG terminal costs, net	15,000,272			9,083,373
Fixed assets and other
Computer and office equipment	11,197			7,464
Furniture and fixtures	16,737			10,733
Computer software	64,432			46,882
Leasehold improvements	38,573			36,067
Land	60,984			55,522
Other	65,138			36,881
Accumulated depreciation	(32,083		)	(30,169		)
Total fixed assets and other, net	224,978			163,380
Property, plant and equipment, net	$	15,225,250		$	9,246,753

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Derivative Instruments - Fair Value Inputs - Quantitative Information (Details) - Liquefaction Supply Derivatives [Member] - USD ($)	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$ 32,546,000	$ 342,000
Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Net Fair Value Asset	$ 32,546,000	$ 342,000
Valuation Technique	Income Approach
Significant Unobservable Input	Basis Spread
Minimum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Inputs Range	$ (0.350)
Maximum [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Significant Unobservable Inputs Range	$ 0.050

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Accrued Liabilities (Tables)

9 Months Ended

Sep. 30, 2015

Accrued Liabilities [Abstract]

Schedule of Accrued Liabilities

As of September 30, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	170,254	$	112,858
Compensation and benefits	83,581		6,425
Liquefaction Project costs	181,219		22,014
LNG terminal costs	5,987		1,077
Other accrued liabilities	16,860		26,755
Total accrued liabilities	$	457,901	$	169,129

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Basis of Presentation

9 Months Ended

Sep. 30, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.

Results of operations for the three and nine months ended September 30, 2015 are not necessarily indicative of the results of operations that will be realized for the year ending December 31, 2015.

For further information, refer to the Consolidated Financial Statements and accompanying notes included in our Annual Report on Form 10-K for the year ended December 31, 2014.

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Consolidated Balance Sheets Parentheticals - $ / shares shares in Thousands	Sep. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Preferred Stock, Par Value	$ 0.0001	$ 0.0001
Preferred Stock, Shares Authorized	5,000	5,000
Preferred Stock, Shares Issued	0	0
Common Stock, Par Value Per Share	$ 0.003	$ 0.003
Common Stock, Shares Authorized	480,000	480,000
Common Stock, Shares, Issued	236,044	236,745
Common Stock, Shares, Outstanding	236,044	236,745
Treasury Stock, Shares	11,248	10,596

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Legal Proceedings

During the second quarter of 2014, four lawsuits were filed in the Court of Chancery of the State of Delaware (the “Court”) against us and/or certain of our present and former officers and directors that challenged the manner in which abstentions were treated in connection with the stockholder vote on Amendment No. 1 to the 2011 Plan(“Amendment No. 1”), pursuant to which, among other things, the number of shares of common stock available for issuance under the 2011 Plan was increased from 10.0 million to 35.0 million shares. The lawsuits contended that abstentions should have been counted as “no” votes in tabulating the outcome of the vote and that the stockholders did not approve Amendment No. 1 when abstentions are counted as such. The lawsuits further contended that portions of the Amended and Restated Bylaws of Cheniere Energy, Inc. adopted on April 3, 2014 were invalid and that certain disclosures relating to these matters made by us were misleading. The lawsuits asserted claims for breach of contract and breach of fiduciary duty (both on a class and a derivative basis) and claims for unjust enrichment (on a derivative basis). The lawsuits sought, among other things, a declaration that the February 1, 2013 stockholder vote on Amendment No. 1 was void, disgorgement of all compensation distributed as a result of Amendment No. 1, voiding the awards made from the shares reserved pursuant to Amendment No. 1 and monetary damages. On June 16, 2014, we filed a verified application with the Court pursuant to 8 Del. C. § 205 (the “Section 205 Action”) in which we asked the Court to declare valid the issuance, pursuant to the 2011 Plan, of the 25.0 million additional shares of our common stock covered by Amendment No. 1, whether occurring in the past or the future.

The parties to the above-referenced lawsuits and the Section 205 Action entered into a Stipulation and Agreement of Compromise, Settlement and Release dated December 12, 2014, subject to its terms and conditions, including receipt, among other things, of Court approval, to resolve the litigation. On March 16, 2015, the Court approved the settlement of the litigation and awarded plaintiffs’ counsel fees, which were paid by our insurers in April 2015.

Obligations under Certain Guarantee Contracts

Cheniere and certain of its subsidiaries enter into guarantee arrangements in the normal course of business to facilitate transactions with third parties. These arrangements include financial guarantees, letters of credit and debt guarantees. As of September 30, 2015 and December 31, 2014, there were no liabilities recognized under these guarantee arrangements.

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Document and Entity Information Document - shares	9 Months Ended
	Sep. 30, 2015	Oct. 20, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	CHENIERE ENERGY INC
Entity Central Index Key	0000003570
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		236,032,655

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Business Segment Information

9 Months Ended

Sep. 30, 2015

Segment Reporting [Abstract]

Business Segment Information

BUSINESS SEGMENT INFORMATION

We have two reportable segments: LNG terminal segment and LNG and natural gas marketing segment. We determine our reportable segments by identifying each segment that engaged in business activities from which it may earn revenues and incur expenses, had operating results regularly reviewed by the entities’ chief operating decision maker for purposes of resource allocation and performance assessment, and had discrete financial information. Substantially all of our revenues from external customers are attributed to the United States. Substantially all of our long-lived assets are located in the United States.

Our LNG terminal segment consists of the Sabine Pass and Corpus Christi LNG terminals. We own and operate the Sabine Pass LNG terminal located on the Sabine Pass shipping channel in Louisiana through our ownership interest in and management agreements with Cheniere Partners. We own 100% of the general partner interest in Cheniere Partners and 80.1% of the common shares of Cheniere Holdings, which owns a 55.9% limited partner interest in Cheniere Partners. We are also developing and constructing a natural gas liquefaction facility near Corpus Christi, Texas.

Our LNG and natural gas marketing segment consists of LNG and natural gas marketing activities by Cheniere Marketing. Cheniere Marketing is developing a platform for LNG sales to international markets with professional staff based in the United States, United Kingdom, Singapore and Chile.

The following table (in thousands) summarizes revenues (losses), loss from operations and total assets for each of our reporting segments: 

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	67,212		$	(1,557	)	$	404		$	66,059
Intersegment revenues (losses) (3)	233			11,354			(11,587		)	—
Depreciation expense	16,775			320			4,543			21,638
Income (loss) from operations	27,072			(27,117		)	(52,029		)	(52,074		)
Interest expense, net of capitalized interest	(67,589		)	(14		)	(25,963		)	(93,566		)
Loss before income taxes and non-controlling interest (4)	(196,693		)	(27,665		)	(82,803		)	(307,161		)
Share-based compensation	1,316			2,051			24,084			27,451
Goodwill	76,819			—			—			76,819
Total assets	16,784,317			552,752			1,115,190			18,452,259
Expenditures for additions to long-lived assets	1,429,808			403			21,258			1,451,469
As of or for the Three Months Ended September 30, 2014
Revenues (losses) from external customers (2)	$	66,983		$	(500	)	$	324		$	66,807
Intersegment revenues (losses) (3)	607			17,262			(17,869		)	—
Depreciation expense	14,817			103			1,269			16,189
Loss from operations	(28,482		)	(6,652		)	(26,030		)	(61,164		)
Interest expense, net of capitalized interest	(46,996		)	—			112			(46,884		)
Loss before income taxes and non-controlling interest (4)	(64,886		)	(7,130		)	(30,813		)	(102,829		)
Share-based compensation	3,278			8,281			13,096			24,655
Goodwill	76,819			—			—			76,819
Total assets	10,847,861			65,536			871,919			11,785,316
Expenditures for additions to long-lived assets	695,159			486			21,895			717,540
For the Nine Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	203,324		$	(1,601	)	$	730		$	202,453
Intersegment revenues (losses) (3)	827			24,725			(25,552		)	—
Depreciation expense	47,787			764			11,010			59,561
Loss from operations	(15,324		)	(58,667		)	(134,201		)	(208,192		)
Interest expense, net of capitalized interest	(169,899		)	(14		)	(68,751		)	(238,664		)
Loss before income taxes and non-controlling interest (4)	(507,751		)	(59,871		)	(217,014		)	(784,636		)
Share-based compensation	30,233			12,138			71,736			114,107
Expenditures for additions to long-lived assets	5,964,244			2,517			70,913			6,037,674
For the Nine Months Ended September 30, 2014
Revenues from external customers (2)	$	200,243		$	482		$	1,277		$	202,002
Intersegment revenues (losses) (3)	2,113			21,336			(23,449		)	—
Depreciation expense	44,033			364			4,565			48,962
Loss from operations	(56,863		)	(33,153		)	(81,153		)	(171,169		)
Interest expense, net of capitalized interest	(131,264		)	—			321			(130,943		)
Loss before income taxes and non-controlling interest (4)	(376,363		)	(34,046		)	(95,299		)	(505,708		)
Share-based compensation	9,840			17,212			63,920			90,972
Expenditures for additions to long-lived assets	2,164,596			1,271			54,120			2,219,987

(1) Includes corporate activities, business development, oil and gas exploration, development and exploitation, strategic activities and certain intercompany eliminations. These activities have been included in the corporate and other column due to the lack of a material impact that these activities have on our Consolidated Financial Statements.

(2) Substantially all of the LNG terminal revenues relate to regasification capacity reservation fee payments made by Total Gas & Power North America, Inc. and Chevron U.S.A. Inc. LNG and natural gas marketing and trading revenue consists primarily of the domestic marketing of natural gas imported into the Sabine Pass LNG terminal.

(3) Intersegment revenues (losses) related to our LNG and natural gas marketing segment are primarily a result of international revenue allocations using a cost plus transfer pricing methodology. These LNG and natural gas marketing segment intersegment revenues (losses) are eliminated with intersegment revenues (losses) in our Consolidated Statements of Operations.

(4) Items to reconcile loss from operations and loss before income taxes and non-controlling interest include consolidated other income (expense) amounts as presented on our Consolidated Statements of Operations primarily related to our LNG terminal segment.

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Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues
LNG terminal revenues		$ 67,212	$ 66,983	$ 202,698	$ 200,243
Marketing and trading revenues (losses)		(1,557)	(499)	(1,601)	482
Other		404	323	1,356	1,277
Total revenues	[1]	66,059	66,807	202,453	202,002
Operating costs and expenses
Operating and maintenance expense (income)		(6,251)	25,908	49,319	69,262
Depreciation expense		21,638	16,189	59,561	48,962
Development expense		4,935	11,544	37,640	38,919
General and administrative expense		97,332	74,255	263,205	215,783
Other		479	75	920	245
Total operating costs and expenses		118,133	127,971	410,645	373,171
Loss from operations		(52,074)	(61,164)	(208,192)	(171,169)
Other income (expense)
Interest expense, net of capitalized interest		(93,566)	(46,884)	(238,664)	(130,943)
Loss on early extinguishment of debt		0	0	(96,273)	(114,335)
Derivative gain (loss), net		(161,482)	5,379	(242,123)	(89,222)
Other income (expense)		(39)	(160)	616	(39)
Total other expense		(255,087)	(41,665)	(576,444)	(334,539)
Loss before income taxes and non-controlling interest	[2]	(307,161)	(102,829)	(784,636)	(505,708)
Income tax benefit (expense)		69	(1,971)	(102)	(2,147)
Net loss		(307,092)	(104,800)	(784,738)	(507,855)
Less: net loss attributable to non-controlling interest		(9,284)	(15,219)	(100,726)	(118,536)
Net loss attributable to common stockholders		$ (297,808)	$ (89,581)	$ (684,012)	$ (389,319)
Net loss per share attributable to common stockholders—basic and diluted		$ (1.31)	$ (0.40)	$ (3.02)	$ (1.74)
Weighted average number of common shares outstanding—basic and diluted		227,126	224,309	226,648	223,710

[1] Substantially all of the LNG terminal revenues relate to regasification capacity reservation fee payments made by Total Gas & Power North America, Inc. and Chevron U.S.A. Inc. LNG and natural gas marketing and trading revenue consists primarily of the domestic marketing of natural gas imported into the Sabine Pass LNG terminal.

[2] Items to reconcile loss from operations and loss before income taxes and non-controlling interest include consolidated other income (expense) amounts as presented on our Consolidated Statements of Operations primarily related to our LNG terminal segment.

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Accrued Liabilities

9 Months Ended

Sep. 30, 2015

Accrued Liabilities [Abstract]

Accrued Liabilities

ACCRUED LIABILITIES

As of September 30, 2015 and December 31, 2014, accrued liabilities consisted of the following (in thousands): 

	September 30,		December 31,
	2015		2014
Interest expense and related debt fees	$	170,254	$	112,858
Compensation and benefits	83,581		6,425
Liquefaction Project costs	181,219		22,014
LNG terminal costs	5,987		1,077
Other accrued liabilities	16,860		26,755
Total accrued liabilities	$	457,901	$	169,129

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Non-Controlling Interest

9 Months Ended

Sep. 30, 2015

Noncontrolling Interest [Abstract]

Non-Controlling Interest

NON-CONTROLLING INTEREST

Cheniere Holdings was formed by us to hold our limited partner interest in Cheniere Partners and in December 2013, completed its initial public offering. Additionally, in November 2014, Cheniere Holdings sold 10.1 million common shares at $22.76 per common share to redeem from us the same number of common shares. As of both September 30, 2015 and December 31, 2014, our ownership interest in Cheniere Holdings was 80.1%, with the remaining non-controlling interest held by the public. Cheniere Holdings owns a 55.9% limited partner interest in Cheniere Partners in the form of 12.0 million common units, 45.3 million Class B units and 135.4 million subordinated units, with the remaining non-controlling interest held by Blackstone CQP Holdco LP and the public. We also own 100% of the general partner interest and the incentive distribution rights in Cheniere Partners.

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Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2015

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Assets and Liabilities

The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2015										December 31, 2014
	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
Natural Gas Derivatives asset	$	—	$	97		$	—	$	97		$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset	—		—			32,546		32,546			—		—			342		342
LNG Trading Derivatives asset	—		113			—		113			—		—			—		—
SPL Interest Rate Derivatives liability	—		(15,738		)	—		(15,738		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives liability	—		(143,092		)	—		(143,092		)	—		—			—		—

Fair Value Inputs, Assets, Quantitative Information

The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2015:

	Net Fair Value Asset (in thousands)	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$32,546	Income Approach	Basis Spread	$ (0.350) - $0.050

Derivative Net Presentation on Consolidated Balance Sheets

The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:

	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 September 30, 2015
Natural Gas Derivatives	$	513		$	(416	)	$	97
Liquefaction Supply Derivatives	33,028			—			33,028
Liquefaction Supply Derivatives	(482		)	—			(482		)
LNG Trading Derivatives	113			—			113
SPL Interest Rate Derivatives	(15,738		)	—			(15,738		)
CCH Interest Rate Derivatives	(143,092		)	—			(143,092		)
As of December 31, 2014
Natural Gas Derivatives	223			(4		)	219
Liquefaction Supply Derivatives	662			—			662
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	11,158			—			11,158
SPL Interest Rate Derivatives	(23,194		)	—			(23,194		)

Commodity Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Fair Value of Derivative Instruments by Balance Sheet Location

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

	September 30, 2015										December 31, 2014
	Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total
Balance Sheet Location
Other current assets	$	97	$	2,371		$	—	$	2,468		$	219	$	76		$	—	$	295
Non-current derivative assets	—		30,657			113		30,770			—		586			—		586
Total derivative assets	97		33,028			113		33,238			219		662			—		881
Derivative liabilities	—		(349		)	—		(349		)	—		(53		)	—		(53		)
Non-current derivative liabilities	—		(133		)	—		(133		)	—		(267		)	—		(267		)
Total derivative liabilities	—		(482		)	—		(482		)	—		(320		)	—		(320		)
Derivative asset, net	$	97	$	32,546		$	113	$	32,756		$	219	$	342		$	—	$	561

(1) Does not include collateral of $5.6 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014, respectively.

Derivative Instruments, Gain (Loss)

The following table (in thousands) shows the changes in the fair value and settlements and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

		Three Months Ended September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives loss	Marketing and trading revenues (losses)	$	(152	)	$	(525	)	$	(260	)	$	(155	)
Natural Gas Derivatives gain (loss)	Operating and maintenance expense (income)	857			194			1,317			(64		)
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense (income)	32,103			—			32,184			—
LNG Trading Derivatives gain	Marketing and trading revenues (losses)	113			—			113			—

(1) There were no physical settlements during the reporting period.

Interest Rate Derivatives [Member]

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Schedule of Notional Amounts of Outstanding Derivative Positions

As of September 30, 2015, we had the following Interest Rate Derivatives outstanding:

	Initial Notional Amount	Maximum Notional Amount	Effective Date	Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
SPL Interest Rate Derivatives	$20.0 million	$628.8 million	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
CCH Interest Rate Derivatives	$28.8 million	$5.5 billion	May 20, 2015	May 31, 2022	2.29%	One-month LIBOR

Fair Value of Derivative Instruments by Balance Sheet Location

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

	September 30, 2015									December 31, 2014
	SPL Interest Rate Derivatives			CCH Interest Rate Derivatives			Total			SPL Interest Rate Derivatives			CCH Interest Rate Derivatives		Total
Balance Sheet Location
Non-current derivative assets	$	—		$	—		$	—		$	11,158		$	—	$	11,158
Derivative liabilities	(7,039		)	(26,451		)	(33,490		)	(23,194		)	—		(23,194		)
Non-current derivative liabilities	(8,699		)	(116,641		)	(125,340		)	—			—		—
Total derivative liabilities	(15,738		)	(143,092		)	(158,830		)	(23,194		)	—		(23,194		)
Derivative liability, net	$	(15,738	)	$	(143,092	)	$	(158,830	)	$	(12,036	)	$	—	$	(12,036	)

Derivative Instruments, Gain (Loss)

The following table (in thousands) shows the changes in the fair value and settlements of the Interest Rate Derivatives, including contingency and syndication premiums related to the CCH Interest Rate Derivatives, recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2015			2014		2015			2014
SPL Interest Rate Derivatives gain (loss)	$	(10,872	)	$	5,379	$	(46,541	)	$	(89,222	)
CCH Interest Rate Derivatives loss	(150,610		)	—		(195,582		)	—

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Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2015

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information

SUPPLEMENTAL CASH FLOW INFORMATION

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

	Nine Months Ended September 30,
	2015		2014
Cash paid during the year for interest, net of amounts capitalized and deferred	$	48,271	$	47,152
Balance in property, plant and equipment, net funded with accounts payable and accrued liabilities	356,306		287,330
Non-cash conveyance of assets	13,169		—

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Share-Based Compensation

9 Months Ended

Sep. 30, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Share-Based Compensation

SHARE-BASED COMPENSATION

We have granted stock, restricted stock, phantom units and options to purchase common stock to employees, outside directors and a consultant under the Cheniere Energy, Inc. Amended and Restated 1997 Stock Option Plan (the “1997 Plan”), Amended and Restated 2003 Stock Incentive Plan, as amended (the “2003 Plan”), 2011 Incentive Plan, as amended (the “2011 Plan”), and the 2014-2018 Long-Term Cash Incentive Program (the “2014-2018 LTIP”).

The 1997 Plan provides for the issuance of stock options to purchase up to 5.0 million shares of our common stock, all of which have been granted. Non-qualified stock options were granted to employees, contract service providers and outside directors. The 2003 Plan and 2011 Plan provide for the issuance of 21.0 million shares and 35.0 million shares, respectively, of our common stock that may be in the form of non-qualified stock options, incentive stock options, purchased stock, restricted (non-vested) stock, bonus (unrestricted) stock, stock appreciation rights, phantom units and other share-based performance awards deemed by the compensation committee of our board of directors (the “Compensation Committee”) to be consistent with the purposes of the 2003 Plan and the 2011 Plan. As of September 30, 2015, all of the shares under the 2003 Plan have been granted and 26.9 million shares, net of cancellations, have been granted under the 2011 Plan.

In April 2015, the Compensation Committee recommended and our board of directors approved the Company’s 2015 Long-Term Cash Incentive Plan, including its sub-plan, the 2014-2018 LTIP. The 2014-2018 LTIP consists of phantom units settled in cash with five consecutive annual performance periods commencing on November 1 and ending on October 31 of each year through October 31, 2018. Awards under the 2014-2018 LTIP will be subject to a three-year vesting schedule, with one third of the phantom units vesting and becoming payable on each of the first, second and third anniversaries of the date of the grant (with the exception of the initial grant for the 2014 performance period, which will vest and become payable on each of February 1, 2016, February 1, 2017 and February 1, 2018). The 2014-2018 LTIP is 100% performance-based and will reward long-term performance measured against growth in the Company’s market capitalization, referred to in the plan documents as total shareholder value (“TSV”), above certain thresholds. Under the 2014-2018 LTIP, the general pool is targeted to be awarded between 2% and 4% of the growth in TSV and the senior executive pool is capped at 2% of the growth in TSV, with the Chief Executive Officer’s compensation targeted at 50% of the senior executive pool, subject to adjustment at the discretion of the Compensation Committee. The number of phantom units comprising the senior executive pool has also been capped, and cannot exceed an amount equal to 1.5% of the shares of our common stock outstanding in any one year.

Phantom units are share-based awards granted to employees over a vesting period that entitle the grantee to receive the cash equivalent to the value of a share of our common stock upon each vesting. Phantom units are not eligible to receive quarterly distributions. The Company initially measures compensation cost based on the Company’s stock price on the grant date, which is included in accrued liabilities on our Consolidated Balance Sheets, and is adjusted quarterly for any changes in the Company’s stock price and period of service rendered. During the three and nine months ended September 30, 2015, we granted 0.1 million and 5.7 million phantom units, respectively, to employees, including units awarded under the 2014-2018 LTIP. We did not grant any phantom units to employees during the three and nine months ended September 30, 2014.

For the three months ended September 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $26.2 million and $22.5 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $1.3 million and $2.2 million, respectively. For the nine months ended September 30, 2015 and 2014, the total share-based compensation expense, net of capitalization, recognized in our net loss was $92.6 million and $84.4 million, respectively, and for the same periods we capitalized as part of the cost of capital assets $21.5 million and $6.6 million, respectively.

The total unrecognized compensation cost at September 30, 2015 relating to non-vested share-based compensation arrangements was $316.2 million, which is expected to be recognized over a weighted average period of 2.3 years.

We received $0.4 million and $3.1 million in the three months ended September 30, 2015 and 2014, respectively, and $2.3 million and $9.5 million in the nine months ended September 30, 2015 and 2014, respectively, of proceeds from the exercise of stock options.

During the three and nine months ended September 30, 2014, we recognized zero and $10.8 million, respectively, of share-based compensation expense related to the modification of long-term commercial bonus awards resulting from an employee termination. We did not recognize any share-based compensation expense related to such modifications in the three and nine months ended September 30, 2015.

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Long-Term Debt

9 Months Ended

Sep. 30, 2015

Debt Disclosure [Abstract]

Long-Term Debt

LONG-TERM DEBT

As of September 30, 2015 and December 31, 2014, our long-term debt consisted of the following (in thousands): 

	Interest	September 30,			December 31,
	Rate	2015			2014
Long-term debt
2016 SPLNG Senior Notes	7.500%	$	1,665,500		$	1,665,500
2020 SPLNG Senior Notes	6.500%	420,000			420,000
2021 SPL Senior Notes	5.625%	2,000,000			2,000,000
2022 SPL Senior Notes	6.250%	1,000,000			1,000,000
2023 SPL Senior Notes	5.625%	1,500,000			1,500,000
2024 SPL Senior Notes	5.750%	2,000,000			2,000,000
2025 SPL Senior Notes	5.625%	2,000,000			—
2015 SPL Credit Facilities (1)	(2)	250,000			—
2021 Cheniere Convertible Unsecured Notes	4.875%	1,028,953			1,004,469
2025 CCH HoldCo II Convertible Senior Notes	11.000%	1,003,667			—
2045 Cheniere Convertible Senior Notes	4.250%	625,000			—
CTPL Term Loan (3)	(4)	400,000			400,000
2015 CCH Credit Facility (5)	(6)	2,428,000			—
SPL Working Capital Facility (7)	(8)	—			—
Total long-term debt		16,321,120			9,989,969
Long-term debt premium (discount)
2016 SPLNG Senior Notes		(5,477		)	(8,998		)
2021 SPL Senior Notes		9,090			10,177
2023 SPL Senior Notes		6,570			7,088
2021 Cheniere Convertible Unsecured Notes		(174,133		)	(189,717		)
2045 Cheniere Convertible Senior Notes		(319,579		)	—
CTPL Term Loan		(1,681		)	(2,435		)
Total long-term debt, net		$	15,835,910		$	9,806,084

(1) Matures on the earlier of December 31, 2020 or the second anniversary of the completion date of Trains 1 through 5 of the SPL Project.

(2) Variable interest rate, at SPL’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans range from 1.30% to 1.75%, depending on the applicable 2015 SPL Credit Facility, and the applicable margin for base rate loans is 1.75%. Interest on LIBOR loans is due and payable at the end of each LIBOR period, and interest on base rate loans is due and payable at the end of each quarter.

(3) Matures on May 28, 2017 when the full amount of the outstanding principal obligations must be repaid.

(4) Variable interest rate, at CTPL’s election, is LIBOR or the base rate plus the applicable margin. CTPL has historically elected LIBOR loans, for which the applicable margin is 3.25% and is due and payable at the end of each LIBOR period.

(5) Matures on the earlier of May 13, 2022 or the second anniversary of the completion date of the first two Trains of the CCL Project.

(6) Variable interest rate, at CCH’s election, is LIBOR or the base rate plus the applicable margin. The applicable margins for LIBOR loans are 2.25% prior to completion of the first two Trains of the CCL Project and 2.50% on completion and thereafter. The applicable margins for base rate loans are 1.25% prior to completion of the first two Trains of the CCL Project and 1.50% on completion and thereafter. Interest on LIBOR loans is due and payable at the end of each applicable interest period, and interest on base rate loans is due and payable at the end of each quarter.

(7) Matures on December 31, 2020, with various terms for underlying loans, as further described below under SPL Working Capital Facility. As of September 30, 2015 and December 31, 2014, no loans were outstanding under the SPL Working Capital Facility or the SPL LC Agreement it replaced.

(8) Variable interest rates, based on LIBOR or the base rate, as further described below under SPL Working Capital Facility.

For the three months ended September 30, 2015 and 2014, we incurred $286.0 million and $154.8 million of total interest cost, respectively, of which we capitalized and deferred $192.4 million and $107.9 million, respectively, including amortization of debt issuance costs, primarily related to the construction of the SPL Project in both periods and additionally the CCL Project in 2015. For the nine months ended September 30, 2015 and 2014, we incurred $707.8 million and $423.8 million of total interest cost, respectively, of which we capitalized and deferred $469.2 million and $292.8 million, respectively, including amortization of debt issuance costs, primarily related to this construction.

SPLNG Senior Notes

Under the SPLNG Indentures, except for permitted tax distributions, SPLNG may not make distributions until certain conditions are satisfied as described in Note 2—Restricted Cash. During the nine months ended September 30, 2015 and 2014, SPLNG made distributions of $267.9 million and $237.7 million, respectively, after satisfying all the applicable conditions in the SPLNG Indentures.

SPL Senior Notes

In March 2015, SPL issued an aggregate principal amount of $2.0 billion of the 2025 SPL Senior Notes, for which borrowings accrue interest at a fixed rate of 5.625%. The terms of the 2025 SPL Senior Notes are governed by the same common indenture with the other SPL Senior Notes. In connection with the closing of the sale of the 2025 SPL Senior Notes, SPL entered into a Registration Rights Agreement dated March 3, 2015 (the “2025 SPL Registration Rights Agreement”). Under the terms of the 2025 SPL Registration Rights Agreement, SPL has agreed, and any future guarantors of the 2025 SPL Senior Notes will agree, to use commercially reasonable efforts to file with the SEC and cause to become effective a registration statement within 360 days after March 3, 2015 with respect to an offer to exchange any and all of the 2025 SPL Senior Notes for a like aggregate principal amount of debt securities of SPL with terms identical in all material respects to the respective 2025 SPL Senior Notes sought to be exchanged (other than with respect to restrictions on transfer or to any increase in annual interest rate), and that are registered under the Securities Act of 1933, as amended (the “Securities Act”). Under specified circumstances, SPL has also agreed, and any future guarantors will also agree, to use commercially reasonable efforts to cause to become effective a shelf registration statement relating to resales of the 2025 SPL Senior Notes. SPL will be obligated to pay additional interest if it fails to comply with its obligations to register the 2025 SPL Senior Notes within the specified time period.

2015 SPL Credit Facilities

In June 2015, SPL entered into the 2015 SPL Credit Facilities with commitments aggregating $4.6 billion. The 2015 SPL Credit Facilities are being used to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 5 of the SPL Project. Borrowings under the 2015 SPL Credit Facilities may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, SPL had $4.3 billion of available commitments and $250.0 million of outstanding borrowings under the 2015 SPL Credit Facilities.

SPL incurred $88.2 million of debt issuance costs in connection with the 2015 SPL Credit Facilities. In addition to interest, SPL is required to pay insurance/guarantee premiums of 0.45% per annum on any drawn amounts under the covered tranches of the 2015 SPL Credit Facilities.  The 2015 SPL Credit Facilities also require SPL to pay a quarterly commitment fee calculated at a rate per annum equal to either: (1) 40% of the applicable margin, multiplied by the average daily amount of the undrawn commitment, or (2) 0.70% of the undrawn commitment, depending on the applicable 2015 SPL Credit Facility. The principal of the loans made under the 2015 SPL Credit Facilities must be repaid in quarterly installments, commencing with the earlier of June 30, 2020 and the last day of the first full calendar quarter after the completion date of Trains 1 through 5 of the SPL Project. Scheduled repayments are based upon an 18-year amortization profile, with the remaining balance due upon the maturity of the 2015 SPL Credit Facilities.

The 2015 SPL Credit Facilities contain conditions precedent for borrowings, as well as customary affirmative and negative covenants. The obligations of SPL under the 2015 SPL Credit Facilities are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and the Amended and Restated Senior Working Capital Revolving Credit and Letter of Credit Reimbursement Agreement (the “SPL Working Capital Facility”) described below.

Under the terms of the 2015 SPL Credit Facilities, SPL is required to hedge not less than 65% of the variable interest rate exposure of its projected outstanding borrowings, calculated on a weighted average basis in comparison to its anticipated draw of principal.

2013 SPL Credit Facilities

 In May 2013, SPL entered into the 2013 SPL Credit Facilities to fund a portion of the costs of developing, constructing and placing into operation Trains 1 through 4 of the SPL Project. As of December 31, 2014, SPL had no outstanding borrowings under the 2013 SPL Credit Facilities. In June 2015, the 2013 SPL Credit Facilities were replaced with the 2015 SPL Credit Facilities.

In March 2015, in conjunction with SPL’s issuance of the 2025 SPL Senior Notes, SPL terminated approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities. This termination and the replacement of the 2013 SPL Credit Facilities with the 2015 SPL Credit Facilities in June 2015 resulted in a write-off of debt issuance costs and deferred commitment fees associated with the 2013 SPL Credit Facilities of $96.3 million for the nine months ended September 30, 2015.

Convertible Notes

2021 Cheniere Convertible Unsecured Notes

In November 2014, we issued an aggregate principal amount of $1.0 billion Convertible Unsecured Notes due 2021 (the “2021 Cheniere Convertible Unsecured Notes”) on a private placement basis in reliance on the exemption from registration provided for under section 4(a)(2) of the Securities Act and Regulation S promulgated thereunder. The 2021 Cheniere Convertible Unsecured Notes accrue interest at a rate of 4.875% per annum, which is payable in kind semi-annually in arrears by increasing the principal amount of the 2021 Cheniere Convertible Unsecured Notes outstanding. One year after the closing date, the 2021 Cheniere Convertible Unsecured Notes will be 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 conversion date. The initial conversion price was $93.64 and is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

Under GAAP, certain convertible debt instruments that may be settled in cash upon conversion are required to be separately accounted for as liability (debt) and equity (conversion option) components of the instrument in a manner that reflects the issuer’s non-convertible debt borrowing rate. We determined that the fair value of the debt component was $808.8 million and the residual value of the equity component was $191.2 million as of the issuance date. As of September 30, 2015 and December 31, 2014, the carrying value of the equity component was $196.1 million and $191.9 million, respectively. The debt component is accreted to the total principal amount due at maturity by amortizing the debt discount. The effective rate of interest to amortize the debt discount was approximately 9.1% and 9.2% as of September 30, 2015 and December 31, 2014, respectively, and the remaining period over which the debt discount will be amortized was 5.7 years as of September 30, 2015. As of September 30, 2015, the if-converted value of the 2021 Cheniere Convertible Unsecured Notes did not exceed the principal balance.

2025 CCH HoldCo II Convertible Senior Notes

In May 2015, CCH HoldCo II issued $1.0 billion aggregate principal amount of 11% Senior Secured Notes due 2025 (the “2025 CCH HoldCo II Convertible Senior Notes”) on a private placement basis in reliance on the exemption from registration provided for under section 4(a)(2) of the Securities Act. The 2025 CCH HoldCo II Convertible Senior Notes were issued pursuant to the amended and restated note purchase agreement entered into among CCH HoldCo II, EIG Management Company, LLC, The Bank of New York Mellon, the Company and the note purchasers. The $1.0 billion principal of the 2025 CCH HoldCo II Convertible Senior Notes will be used to partially fund costs associated with Stage 1 of the CCL Project and the Corpus Christi Pipeline. The purchasers have made commitments, which will expire on May 1, 2016, to acquire an additional $500 million of 2025 CCH HoldCo II Convertible Senior Notes(the “Second Phase Funding”) upon satisfaction of incremental customary conditions precedent related to the construction of Stage 2 of the CCL Project. The 2025 CCH HoldCo II Convertible Senior Notes bear interest at a rate of 11.0% per annum, which is payable quarterly in arrears. Prior to the substantial completion of Train 2 of the CCL Project, if the Second Phase Funding has not occurred, and to the substantial completion of Train 3 of the CCL Project following the occurrence of the Second Phase Funding, interest on the 2025 CCH HoldCo II Convertible Senior Notes will be paid entirely in kind. Following this date, the interest generally must be paid in cash; however, a portion of the interest may be paid in kind under certain specified circumstances. 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.

At CCH HoldCo II’s option, the outstanding 2025 CCH HoldCo II Convertible Senior Notes are convertible into our common stock on or after the later of (1) 58 months from May 1, 2015, and (2) the substantial completion of Train 2 of the CCL Project and any 2025 CCH HoldCo II Convertible Senior Notes issued in connection with the Second Phase Funding will be convertible on or after the substantial completion of Train 3 of the CCL Project(in each case, the “Eligible Conversion Date”). The conversion price for 2025 CCH HoldCo II Convertible Senior Notes converted at CCH HoldCo II’s option is 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. At the option of the holders, the 2025 CCH HoldCo II Convertible Senior Notes are convertible on or after the six-month anniversary of the applicable Eligible Conversion Date at a conversion 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. Conversions are also subject to various limitations and conditions. As of September 30, 2015, the value of the 2025 CCH HoldCo II Convertible Senior Notes if converted at the holders’ option did not exceed the principal balance.

2045 Cheniere Convertible Senior Notes

In March 2015, we issued $625.0 million aggregate principal amount of 4.25% Convertible Senior Notes due 2045 (the “2045 Cheniere Convertible Senior Notes”) to certain investors through a registered direct offering. The 2045 Cheniere Convertible Senior Notes were issued with an original issue discount of 20% and accrue interest at a rate of 4.25% per annum, which is payable semi-annually in arrears. 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 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. 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. The conversion rate is subject to adjustment upon the occurrence of certain specified events. We have the option to satisfy the conversion obligation with cash, common stock or a combination thereof.

We determined that the fair value of the debt component of the 2045 Cheniere Convertible Senior Notes was $304.3 million and the residual value of the equity component was $195.7 million as of the issuance date, excluding debt issuance costs. As of September 30, 2015, the carrying value of the equity component was $194.1 million. The debt component is accreted to the total principal amount due at maturity by amortizing the debt discount. The effective rate of interest to amortize the debt discount was approximately 9.4% as of September 30, 2015, and the remaining period over which the debt discount will be amortized was 29.5 years. As of September 30, 2015, the if-converted value of the 2045 Cheniere Convertible Senior Notes did not exceed the principal balance.

Interest expense, before capitalization, related to the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes(together, the “Convertible Notes”) consisted of the following (in thousands):

	Three Months Ended September 30,				Nine Months Ended September 30,
	2015		2014		2015		2014
Interest per contractual rate	$	46,782	$	—	$	97,991	$	—
Amortization of debt discount	7,233		—		20,948		—
Amortization of debt issuance costs	1,133		—		1,748		—
Total interest expense related to the Convertible Notes	$	55,148	$	—	$	120,687	$	—

CTPL Term Loan

As of September 30, 2015, CTPL had borrowed the full amount of $400.0 million available under the CTPL Term Loan. The outstanding balance may be repaid, in whole or in part, at any time without premium or penalty.

2015 CCH Credit Facility

In May 2015, CCH entered into the 2015 CCH Credit Facility, which is being used to fund a portion of the costs associated with the development, construction, operation and maintenance of the CCL Project.  The total commitment under the 2015 CCH Credit Facility is approximately $11.5 billion, comprising approximately $8.4 billion linked to Stage 1 of the CCL Project and the Corpus Christi Pipeline and approximately $3.1 billion linked to Stage 2 of the CCL Project. Borrowings under the 2015 CCH Credit Facility may be refinanced, in whole or in part, at any time without premium or penalty; however, interest rate hedging and interest rate breakage costs may be incurred. As of September 30, 2015, CCH had $6.0 billion of available commitments and $2.4 billion of outstanding borrowings under the 2015 CCH Credit Facility.

CCH incurred $289.8 million of debt issuance costs in connection with the 2015 CCH Credit Facility. In addition to interest, CCH will incur a commitment fee at a rate per annum equal to 40% of the margin for LIBOR loans, multiplied by the outstanding undrawn debt commitments. The principal of the loans made under the 2015 CCH Credit Facility must be repaid in quarterly installments, commencing on the earlier of (1) the first quarterly payment date occurring more than three calendar months following project completion and (2) a set date determined by reference to the date under which a certain LNG buyer linked to the last Train 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 project completion and designed to achieve a minimum projected fixed debt service coverage ratio of 1.55:1.

The 2015 CCH Credit Facility contains conditions precedent for borrowings, as well as customary affirmative and negative covenants. The obligations of CCH under the 2015 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.

Under the terms of the 2015 CCH Credit Facility, CCH is required to hedge not less than 65% of the variable interest rate exposure of its senior secured debt.

SPL Working Capital Facility

In September 2015, SPL entered into a $1.2 billionSPL Working Capital Facility, which replaced the $325.0 million Senior Letter of Credit and Reimbursement Agreement that was entered into in April 2014 (the “SPL LC Agreement”). The SPL Working Capital Facility is intended to be used for loans to SPL (“Working Capital Loans”), the issuance of letters of credit on behalf of SPL (“Letters of Credit”), as well as for swing line loans to SPL (“Swing Line Loans”), primarily for certain working capital requirements related to developing and placing into operation the SPL Project. SPL may, from time to time, request increases in the commitments under the 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 million. As of September 30, 2015, SPL had $1.1 billion of available commitments, $127.6 million aggregate amount of issued Letters of Credit and noWorking Capital Loans, Swing Line Loans or loans deemed made in connection with a draw upon a Letter of Credit (“LC Loans” and collectively with Working Capital Loans and Swing Line Loans, the “SPL Working Capital Facility Loans”) outstanding under the SPL Working Capital Facility. As of December 31, 2014, SPL had issued letters of credit in an aggregate amount of $9.5 million, and no draws had been made upon any letters of credit issued under the SPL LC Agreement.

SPL Working Capital Facility Loans 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 one month LIBOR plus 0.50%), plus the applicable margin. The applicable margin for LIBOR SPL Working Capital Facility Loans is 1.75% per annum, and the applicable margin for base rate SPL Working Capital Facility Loans is 0.75% per annum. Interest on Swing Line Loans and LC Loans is due and payable on the date the loan becomes due. Interest on LIBOR Working Capital Loans is due and payable at the end of each applicable LIBOR period, and interest on base rate Working Capital Loans is due and payable at the end of each fiscal quarter. However, if such base rate Working Capital Loan is converted into a LIBOR Working Capital Loan, interest is due and payable on that date. Additionally, if the loans become due prior to such periods, the interest also becomes due on that date.

SPL incurred $27.5 million of debt issuance costs in connection with the SPL Working Capital Facility. SPL pays (1) a commitment fee on the average daily amount of the excess of the total commitment amount over the principal amount outstanding without giving effect to any outstanding Swing Line Loans in an amount equal to an annual rate of 0.70% and (2) a Letter of Credit fee equal to an annual rate of 1.75% of the undrawn portion of all Letters of Credit issued under the SPL Working Capital Facility. If draws are made upon a Letter of Credit issued under the SPL Working Capital Facility and SPL does not elect for such draw (an “LC Draw”) to be deemed an LC Loan, SPL is required to pay the full amount of the LC Draw on or prior to the business day following the notice of the LC Draw. An LC Draw accrues interest at an annual rate of 2.0% plus the base rate. As of September 30, 2015, noLC Draws had been made upon any Letters of Credit issued under the SPL Working Capital Facility.

The SPL Working Capital Facility matures on December 31, 2020, and the outstanding balance may be repaid, in whole or in part, at any time without premium or penalty upon three business days’ notice. LC Loans have a term of up to one year. 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 Swing Line Loan is made and (3) the first borrowing date for a Working Capital Loan or Swing Line Loan occurring at least three business days following the date the Swing Line Loan is made. SPL is required to reduce the aggregate outstanding principal amount of all Working Capital Loans to zero for a period of five consecutive business days at least once each year.

The SPL Working Capital Facility contains conditions precedent for extensions of credit, as well as customary affirmative and negative covenants. The obligations of SPL under the SPL Working Capital Facility are secured by substantially all of the assets of SPL as well as all of the membership interests in SPL on a pari passu basis with the SPL Senior Notes and 2015 SPL Credit Facilities.

Fair Value Disclosures

The following table (in thousands) shows the carrying amount and estimated fair value of our long-term debt:

	September 30, 2015				December 31, 2014
	Carrying Amount		Estimated Fair Value		Carrying Amount		Estimated Fair Value
2016 SPLNG Senior Notes, net of discount (1)	$	1,660,023	$	1,684,923	$	1,656,502	$	1,718,621
2020 SPLNG Senior Notes (1)	420,000		410,550		420,000		428,400
2021 SPL Senior Notes, net of premium (1)	2,009,090		1,853,386		2,010,177		1,985,050
2022 SPL Senior Notes (1)	1,000,000		930,000		1,000,000		1,020,000
2023 SPL Senior Notes, net of premium (1)	1,506,570		1,344,614		1,507,089		1,476,947
2024 SPL Senior Notes (1)	2,000,000		1,765,000		2,000,000		1,970,000
2025 SPL Senior Notes (1)	2,000,000		1,755,000		—		—
2015 SPL Credit Facilities (2)	250,000		250,000		—		—
2021 Cheniere Convertible Unsecured Notes, net of discount (3)	854,820		894,160		814,751		1,025,563
2025 CCH HoldCo II Convertible Senior Notes (3)	1,003,667		900,490		—		—
2045 Cheniere Convertible Senior Notes, net of discount (4)	305,421		390,263		—		—
CTPL Term Loan, net of discount (2)	398,319		400,000		397,565		400,000
2015 CCH Credit Facility (2)	2,428,000		2,428,000		—		—
SPL Working Capital Facility (2)	—		—		—		—

(1) The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014, as applicable.

(2) 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. 

(3) 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. 

(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.

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Income Taxes

9 Months Ended

Sep. 30, 2015

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

We are not presently a taxpayer for federal or state income tax purposes and have not recorded a net liability for federal or state income taxes in any of the periods included in the accompanying Consolidated Financial Statements. However, we are presently an international taxpayer and have recorded a net (benefit) of $(0.1) million and a net expense of $2.0 million for the three months ended September 30, 2015 and 2014, respectively, and a net expense of $0.1 million and $2.1 million for the nine months ended September 30, 2015 and 2014, respectively, for international income taxes.

We experienced an ownership change within the provisions of Internal Revenue Code (“IRC”) Section 382 in 2008, 2010 and 2012. An analysis of the annual limitation on the utilization of our net operating losses (“NOLs”) was performed in accordance with IRC Section 382. It was determined that IRC Section 382 will not limit the use of our NOLs in full over the carryover period. We will continue to monitor trading activity in our shares which may cause an additional ownership change which could ultimately affect our ability to fully utilize our existing tax NOL carryforwards.

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Net Loss Per Share Attributable to Common Stockholders

9 Months Ended

Sep. 30, 2015

Earnings Per Share [Abstract]

Net Loss Per Share Attributable to Common Stockholders

NET LOSS PER SHARE ATTRIBUTABLE TO COMMON STOCKHOLDERS

Basic net loss per share attributable to common stockholders (“EPS”) excludes dilution and is computed by dividing net 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 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 following table (in thousands, except for loss per share) reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	227,126			224,309			226,648			223,710
Dilutive common stock options (1)	—			—			—			—
Diluted	227,126			224,309			226,648			223,710
Basic and diluted net loss per share attributable to common stockholders	$	(1.31	)	$	(0.40	)	$	(3.02	)	$	(1.74	)

(1) Stock options and unvested stock of 8.6 million shares and 13.0 million shares for the three months ended September 30, 2015 and 2014, respectively, and 8.6 million shares and 12.8 million shares for the nine months ended September 30, 2015 and 2014, respectively, representing securities that could potentially dilute basic EPS in the future, were not included in the diluted net loss per share computations because their effect would have been anti-dilutive. In addition, 56.2 million shares in aggregate, issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes, as described in Note 7—Long-Term Debt, were not included in the computation of diluted net loss per share for the three and nine months ended September 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

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Derivative Instruments - Narrative (Details) MMBTU in Millions	1 Months Ended			3 Months Ended		9 Months Ended
	May. 31, 2015 USD ($)	Mar. 31, 2015 USD ($)	May. 31, 2014 USD ($)	Sep. 30, 2015 USD ($) MMBTU	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) MMBTU	Sep. 30, 2014 USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Asset transfers into level 3				$ 0	$ 0	$ 0	$ 0
Asset transfers out of level 3				$ 0	$ 0	$ 0	$ 0
Energy Units Secured Through Long-Term Purchase Agreements | MMBTU				2,156.6		2,156.6
Liquefaction Supply Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Notional Amount | MMBTU				1,244.1		1,244.1
Liquefaction Supply Derivatives [Member] | Minimum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract						1 year
Liquefaction Supply Derivatives [Member] | Maximum [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract						7 years
SPL [Member] | 2013 SPL Credit Facilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Line of Credit Facility, Decrease, Net		$ 1,800,000,000	$ 2,100,000,000
SPL [Member] | SPL Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Loss, Net		$ 34,700,000	$ 9,300,000
CCH [Member] | CCH Interest Rate Derivatives [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Term of Contract						7 years
Contingency and syndication premiums	$ 50,100,000

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Share-Based Compensation (Details) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015 USD ($) shares	Sep. 30, 2014 USD ($) shares	Sep. 30, 2015 USD ($) Installment_vestings annual_performance_periods shares	Sep. 30, 2014 USD ($) shares	Feb. 01, 2013 shares	Jan. 31, 2013 shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation, net of capitalization | $	$ 26,200	$ 22,500	$ 92,600	$ 84,449
Share-based compensation capitalized during period | $	1,300	2,200	21,500	6,600
Share-based compensation, unrecognized compensation | $	316,200		$ 316,200
Share-based compensation, unrecognized compensation, period for recognition			2 years 3 months 1 day
Proceeds from exercise of stock options | $	400	3,100	$ 2,279	9,502
Share-based compensation plan modification, incremental compensation cost | $	$ 0	$ 0	$ 0	$ 10,800
Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in Period, number of units	100	0	5,677	0
1997 Stock Option Plan [Member] | Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Shares Authorized	5,000		5,000
Number of Shares Granted Plan-to-Date, Net of Cancellations	5,000		5,000
2003 Stock Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Shares Authorized	21,000		21,000
Number of Shares Granted Plan-to-Date, Net of Cancellations	21,000		21,000
2011 Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Shares Authorized	35,000		35,000		35,000	10,000
Number of Shares Granted Plan-to-Date, Net of Cancellations	26,900		26,900
2014-2018 Long-Term Cash Incentive Program [Domain] | Phantom Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of consecutive annual performance periods | annual_performance_periods			5
Number of vesting installments | Installment_vestings			3
Percentage of award that is performance-based			100.00%
2014-2018 Long-Term Cash Incentive Program [Domain] | Phantom Units [Member] | Senior Executive Pool [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocation percentage to Chief Executive Officer			50.00%
Percentage of outstanding stock maximum			1.50%
2014-2018 Long-Term Cash Incentive Program [Domain] | Minimum [Member] | Phantom Units [Member] | General Pool [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocation percentage of total shareholder value			2.00%
2014-2018 Long-Term Cash Incentive Program [Domain] | Maximum [Member] | Phantom Units [Member] | General Pool [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocation percentage of total shareholder value			4.00%
2014-2018 Long-Term Cash Incentive Program [Domain] | Maximum [Member] | Phantom Units [Member] | Senior Executive Pool [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocation percentage of total shareholder value			2.00%

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Basis of Presentation (Policies)

9 Months Ended

Sep. 30, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation, Policy

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. In our opinion, all adjustments, consisting only of normal recurring adjustments necessary for a fair presentation, have been included. Certain reclassifications have been made to conform prior period information to the current presentation.  The reclassifications had no effect on our overall consolidated financial position, results of operations or cash flows.

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Net Loss Per Share Attributable to Common Stockholders (Tables)

9 Months Ended

Sep. 30, 2015

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The following table (in thousands, except for loss per share) reconciles basic and diluted weighted average common shares outstanding for the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2015			2014			2015			2014
Weighted average common shares outstanding:
Basic	227,126			224,309			226,648			223,710
Dilutive common stock options (1)	—			—			—			—
Diluted	227,126			224,309			226,648			223,710
Basic and diluted net loss per share attributable to common stockholders	$	(1.31	)	$	(0.40	)	$	(3.02	)	$	(1.74	)

(1) Stock options and unvested stock of 8.6 million shares and 13.0 million shares for the three months ended September 30, 2015 and 2014, respectively, and 8.6 million shares and 12.8 million shares for the nine months ended September 30, 2015 and 2014, respectively, representing securities that could potentially dilute basic EPS in the future, were not included in the diluted net loss per share computations because their effect would have been anti-dilutive. In addition, 56.2 million shares in aggregate, issuable upon conversion of the 2021 Cheniere Convertible Unsecured Notes, the 2025 CCH HoldCo II Convertible Senior Notes and the 2045 Cheniere Convertible Senior Notes, as described in Note 7—Long-Term Debt, were not included in the computation of diluted net loss per share for the three and nine months ended September 30, 2015 because the computation of diluted net loss per share utilizing the “if-converted” method would be anti-dilutive.

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Long-Term Debt - Schedule of Carrying Values and Estimated Fair Values of Debt Instruments (Details) - USD ($) $ in Thousands		Sep. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		$ 15,835,910	$ 9,806,084
2016 SPLNG Senior Notes, net of discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		1,660,023	1,656,502
2016 SPLNG Senior Notes, net of discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,684,923	1,718,621
2020 SPLNG Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		420,000	420,000
2020 SPLNG Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	410,550	428,400
2021 SPL Senior Notes, net of premium [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		2,009,090	2,010,177
2021 SPL Senior Notes, net of premium [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,853,386	1,985,050
2022 SPL Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		1,000,000	1,000,000
2022 SPL Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	930,000	1,020,000
2023 SPL Senior Notes, net of premium [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		1,506,570	1,507,089
2023 SPL Senior Notes, net of premium [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,344,614	1,476,947
2024 SPL Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		2,000,000	2,000,000
2024 SPL Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,765,000	1,970,000
2025 SPL Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		2,000,000	0
2025 SPL Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes Payable, Fair Value Disclosure	[1]	1,755,000	0
2015 SPL Credit Facilities [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		250,000	0
2015 SPL Credit Facilities [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[2]	250,000	0
2021 Cheniere Convertible Unsecured Notes, net of discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		854,820	814,751
2021 Cheniere Convertible Unsecured Notes, net of discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Convertible Debt, Fair Value Disclosures	[3]	894,160	1,025,563
2025 CCH Holdco II Convertible Senior Notes [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		1,003,667	0
2025 CCH Holdco II Convertible Senior Notes [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Convertible Debt, Fair Value Disclosures	[3]	900,490	0
2045 Cheniere Convertible Senior Notes, net of discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		305,421	0
2045 Cheniere Convertible Senior Notes, net of discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Convertible Debt, Fair Value Disclosures	[4]	390,263	0
CTPL Term Loan, net of discount [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		398,319	397,565
CTPL Term Loan, net of discount [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Loans Payable, Fair Value Disclosure	[2]	400,000	400,000
2015 CCH Credit Facility [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		2,428,000	0
2015 CCH Credit Facility [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[2]	2,428,000	0
SPL Working Capital Facility [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying Amount, Long-term debt		0	0
SPL Working Capital Facility [Member] | Estimated Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Lines of Credit, Fair Value Disclosure	[2]	$ 0	$ 0

[1] The Level 2 estimated fair value was based on quotations obtained from broker-dealers who make markets in these and similar instruments based on the closing trading prices on September 30, 2015 and December 31, 2014, as applicable.

[2] 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.

[3] 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.

[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.

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Non-Controlling Interest (Details) - $ / shares	1 Months Ended	9 Months Ended
	Nov. 30, 2014	Sep. 30, 2015	Dec. 31, 2014
Cheniere Partners [Member]
Noncontrolling Interest [Line Items]
General Partner Ownership Percentage		100.00%
Cheniere Holdings [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent		80.10%	80.10%
Cheniere Holdings [Member]
Noncontrolling Interest [Line Items]
Issuance of Stock, Shares	10,100,000.0
Shares Issued, Price Per Share	$ 22.76
Cheniere Holdings [Member] | Cheniere Partners [Member]
Noncontrolling Interest [Line Items]
Limited Partner ownership percentage		55.90%
Cheniere Holdings [Member] | Cheniere Partners [Member] | Common Units [Member]
Noncontrolling Interest [Line Items]
Partners Capital Account, Units, Units Held		12,000,000
Cheniere Holdings [Member] | Cheniere Partners [Member] | Capital Unit, Class B [Member]
Noncontrolling Interest [Line Items]
Partners Capital Account, Units, Units Held		45,300,000
Cheniere Holdings [Member] | Cheniere Partners [Member] | Subordinated Units [Member]
Noncontrolling Interest [Line Items]
Partners Capital Account, Units, Units Held		135,400,000

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Consolidated Statement of Stockholders' Equity - 9 months ended Sep. 30, 2015 - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Accumulated Deficit	Non-controlling Interest
Common Stock, Shares, Outstanding, Beginning of Period at Dec. 31, 2014	236,745	236,745
Treasury Stock, Shares, Beginning of Period at Dec. 31, 2014	10,596		10,596
Stockholders' Equity, Beginning of Period at Dec. 31, 2014	$ 2,501,517	$ 712	$ (292,752)	$ 2,776,702	$ (2,648,839)	$ 2,665,694
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of stock options, shares		67	0
Exercise of stock options	2,279	$ 0	$ 0	2,279	0	0
Issuances of restricted stock, shares		19	0
Issuances of restricted stock	0	$ 0	$ 0	0	0	0
Forfeitures of restricted stock, shares		(152)	17
Forfeitures of restricted stock	0	$ 1	$ 0	1	0	0
Share-based compensation	50,582	$ 0	$ 0	50,582	0	0
Shares repurchased related to share-based compensation, shares		(635)	635
Shares repurchased related to share-based compensation	44,305	$ 3	$ 44,305	3	0	0
Excess tax benefit from share-based compensation	1,424	0	0	1,424	0	0
Equity portion of issuance of convertible notes, net	198,326	0	0	198,326	0	0
Loss attributable to non-controlling interest	(100,726)	0	0	0	0	(100,726)
Distributions to non-controlling interest	(60,154)	0	0	0	0	(60,154)
Net loss	$ (684,012)	$ 0	$ 0	0	(684,012)	0
Common Stock, Shares, Outstanding, End of Period at Sep. 30, 2015	236,044	236,044
Treasury Stock, Shares, End of Period at Sep. 30, 2015	11,248		11,248
Stockholders' Equity, End of Period at Sep. 30, 2015	$ 1,864,931	$ 708	$ (337,057)	$ 3,029,317	$ (3,332,851)	$ 2,504,814

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Derivative Instruments

9 Months Ended

Sep. 30, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

DERIVATIVE INSTRUMENTS

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

• commodity derivatives to hedge the exposure to price risk attributable to future: (1) sales of our LNG inventory and (2) purchases of natural gas to operate the Sabine Pass LNG terminal (“Natural Gas Derivatives”);

• commodity derivatives consisting of natural gas purchase agreements and associated economic hedges to secure natural gas feedstock for the SPL Project(“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”);

• interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 SPL Credit Facilities (and previously the 2013 SPL Credit Facilities) (“SPL Interest Rate Derivatives”); and

• interest rate swaps to hedge the exposure to volatility in a portion of the floating-rate interest payments under the 2015 CCH Credit Facility(“CCH Interest Rate Derivatives” and, collectively with the SPL Interest Rate Derivatives, the “Interest Rate Derivatives”).

None of our derivative instruments are designated as cash flow hedging instruments, and changes in fair value are recorded within our Consolidated Statements of Operations.

The following table (in thousands) shows the fair value of our derivative instruments that are required to be measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014, which are classified as other current assets, non-current derivative assets, derivative liabilities or non-current derivative liabilities in our Consolidated Balance Sheets.

	Fair Value Measurements as of
	September 30, 2015										December 31, 2014
	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
Natural Gas Derivatives asset	$	—	$	97		$	—	$	97		$	—	$	219		$	—	$	219
Liquefaction Supply Derivatives asset	—		—			32,546		32,546			—		—			342		342
LNG Trading Derivatives asset	—		113			—		113			—		—			—		—
SPL Interest Rate Derivatives liability	—		(15,738		)	—		(15,738		)	—		(12,036		)	—		(12,036		)
CCH Interest Rate Derivatives liability	—		(143,092		)	—		(143,092		)	—		—			—		—

The estimated fair values of our Natural Gas Derivatives and the economic hedges related to the LNG Trading Derivatives are the amounts at which the instruments could be exchanged currently between willing parties. We value these derivatives using observable commodity price curves and other relevant data. We value the Interest Rate Derivatives using valuations based on the initial trade prices. Using an income-based approach, subsequent valuations are based on observable inputs to the valuation model including interest rate curves, risk adjusted discount rates, credit spreads and other relevant data.

The fair value of substantially all of the Liquefaction Supply Derivatives is developed through the use of internal models which are impacted by inputs that are unobservable in the marketplace. As a result, the fair value of the Liquefaction Supply Derivatives is designated as Level 3 within the valuation hierarchy. The curves used to generate the fair value of the Liquefaction Supply Derivatives are based on basis adjustments applied to forward curves for a liquid trading point. In addition, there may be observable liquid market basis information in the near term, but terms of a particular Liquefaction Supply Derivatives contract may exceed the period for which such information is available, resulting in a Level 3 classification. In these instances, the fair value of the contract incorporates extrapolation assumptions made in the determination of the market basis price for future delivery periods in which applicable commodity basis prices were either not observable or lacked corroborative market data. Internal fair value models that include contractual pricing with a fixed basis include fixed basis amounts for delivery at locations for which no market currently exists. Internal fair value models also include conditions precedent to the respective long-term natural gas purchase agreements. As of September 30, 2015 and December 31, 2014, some of the Liquefaction Supply Derivatives existed within markets for which the pipeline infrastructure has not been developed to accommodate marketable physical gas flow. In the absence of infrastructure to accommodate marketable physical gas flow, our internal fair value models are based on a market price that equates to our own contractual pricing due to: (1) the inactive and unobservable market and (2) conditions precedent and their impact on the uncertainty in the timing of our actual receipt of the physical volumes associated with each forward. The fair value of the Liquefaction Supply Derivatives is predominantly driven by market commodity basis prices and our assessment of the associated conditions precedent, including evaluating whether the respective market is available as pipeline infrastructure is developed. Upon the completion and placement into service of relevant pipeline infrastructure to accommodate marketable physical gas flow, we recognize a gain or loss based on the fair value of the respective natural gas purchase agreements as of the reporting date.

There were no transfers into or out of Level 3 Liquefaction Supply Derivatives for the three and nine months ended September 30, 2015 and 2014. As all of the physical Liquefaction Supply Derivatives are either purely index-priced or index-priced with a fixed basis, we do not believe that a significant change in market commodity prices would have a material impact on our Level 3 fair value measurements. The following table includes quantitative information for the unobservable inputs for the Level 3 Liquefaction Supply Derivatives as of September 30, 2015:

	Net Fair Value Asset (in thousands)	Valuation Technique	Significant Unobservable Input	Significant Unobservable Inputs Range
Liquefaction Supply Derivatives	$32,546	Income Approach	Basis Spread	$ (0.350) - $0.050

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 net settlement. 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.

Commodity Derivatives

We recognize all commodity derivative instruments, including our Natural Gas Derivatives, Liquefaction Supply Derivatives and LNG Trading Derivatives(collectively, “Commodity Derivatives”), as either assets or liabilities and measure those instruments at fair value.  Changes in the fair value of our Commodity Derivatives are reported in earnings.

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

	September 30, 2015										December 31, 2014
	Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total			Natural Gas Derivatives (1)		Liquefaction Supply Derivatives			LNG Trading Derivatives		Total
Balance Sheet Location
Other current assets	$	97	$	2,371		$	—	$	2,468		$	219	$	76		$	—	$	295
Non-current derivative assets	—		30,657			113		30,770			—		586			—		586
Total derivative assets	97		33,028			113		33,238			219		662			—		881
Derivative liabilities	—		(349		)	—		(349		)	—		(53		)	—		(53		)
Non-current derivative liabilities	—		(133		)	—		(133		)	—		(267		)	—		(267		)
Total derivative liabilities	—		(482		)	—		(482		)	—		(320		)	—		(320		)
Derivative asset, net	$	97	$	32,546		$	113	$	32,756		$	219	$	342		$	—	$	561

(1) Does not include collateral of $5.6 million and $5.7 million deposited for such contracts, which is included in other current assets in our Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014, respectively.

The following table (in thousands) shows the changes in the fair value and settlements and location of our Commodity Derivatives recorded on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

		Three Months Ended September 30,						Nine Months Ended September 30,
	Statement of Operations Location	2015			2014			2015			2014
Natural Gas Derivatives loss	Marketing and trading revenues (losses)	$	(152	)	$	(525	)	$	(260	)	$	(155	)
Natural Gas Derivatives gain (loss)	Operating and maintenance expense (income)	857			194			1,317			(64		)
Liquefaction Supply Derivatives gain (1)	Operating and maintenance expense (income)	32,103			—			32,184			—
LNG Trading Derivatives gain	Marketing and trading revenues (losses)	113			—			113			—

(1) There were no physical settlements during the reporting period.

Natural Gas Derivatives

Our Natural Gas Derivatives are executed through over-the-counter contracts which are subject to nominal credit risk as these transactions are settled on a daily margin basis with investment grade financial institutions. We are required by these financial institutions to use margin deposits as credit support for our Natural Gas Derivatives activities.

Liquefaction Supply Derivatives

SPL has entered into index-based physical natural gas supply contracts and associated economic hedges to secure natural gas feedstock for the SPL Project. The terms of the physical contracts range from approximately one to seven years and commence upon the occurrence of conditions precedent, including the date of first commercial operation of specified Trains of the SPL Project. We recognize the Liquefaction Supply Derivatives as either assets or liabilities and measure those instruments at fair value. Changes in the fair value of the Liquefaction Supply Derivatives are reported in earnings. As of September 30, 2015, SPL has secured up to approximately 2,156.6 millionMMBtu of natural gas feedstock through long-term natural gas purchase agreements, of which the forward notional natural gas buy position of the Liquefaction Supply Derivatives was approximately 1,244.1 millionMMBtu, which were recorded as derivatives due to minimum purchase requirements.

LNG Trading Derivatives

As of September 30, 2015, we have entered into certain LNG Trading Derivatives representing a short position of 1.5 million MMBtu, and we may from time to time enter into certain financial 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 such LNG transactions.

Interest Rate Derivatives

SPL Interest Rate Derivatives

SPL has entered into SPL Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2015 SPL Credit Facilities. The SPL Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 SPL Credit Facilities.

In March 2015, SPL settled a portion of the SPL Interest Rate Derivatives and recognized a derivative loss of $34.7 million within our Consolidated Statements of Operations in conjunction with the termination of approximately $1.8 billion of commitments under the 2013 SPL Credit Facilities as discussed in Note 7—Long-Term Debt. In May 2014, SPL settled a portion of the SPL Interest Rate Derivatives and recognized a derivative loss of $9.3 million within our Consolidated Statements of Operations in conjunction with the early termination of approximately $2.1 billion of commitments under the 2013 SPL Credit Facilities.

CCH Interest Rate Derivatives

In February 2015, CCH entered into CCH Interest Rate Derivatives to protect against volatility of future cash flows and hedge a portion of the variable interest payments on the 2015 CCH Credit Facility. The CCH Interest Rate Derivatives hedge a portion of the expected outstanding borrowings over the term of the 2015 CCH Credit Facility. The CCH Interest Rate Derivatives have a seven-year term and were contingent upon reaching a final investment decision with respect to the CCL Project, which was reached in May 2015. Upon meeting the contingency related to the CCH Interest Rate Derivatives in May 2015, we paid $50.1 million related to contingency and syndication premiums, which is included in derivative gain (loss), net on our Consolidated Statements of Operations.

As of September 30, 2015, we had the following Interest Rate Derivatives outstanding:

	Initial Notional Amount	Maximum Notional Amount	Effective Date	Maturity Date	Weighted Average Fixed Interest Rate Paid	Variable Interest Rate Received
SPL Interest Rate Derivatives	$20.0 million	$628.8 million	August 14, 2012	July 31, 2019	1.98%	One-month LIBOR
CCH Interest Rate Derivatives	$28.8 million	$5.5 billion	May 20, 2015	May 31, 2022	2.29%	One-month LIBOR

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

	September 30, 2015									December 31, 2014
	SPL Interest Rate Derivatives			CCH Interest Rate Derivatives			Total			SPL Interest Rate Derivatives			CCH Interest Rate Derivatives		Total
Balance Sheet Location
Non-current derivative assets	$	—		$	—		$	—		$	11,158		$	—	$	11,158
Derivative liabilities	(7,039		)	(26,451		)	(33,490		)	(23,194		)	—		(23,194		)
Non-current derivative liabilities	(8,699		)	(116,641		)	(125,340		)	—			—		—
Total derivative liabilities	(15,738		)	(143,092		)	(158,830		)	(23,194		)	—		(23,194		)
Derivative liability, net	$	(15,738	)	$	(143,092	)	$	(158,830	)	$	(12,036	)	$	—	$	(12,036	)

The following table (in thousands) shows the changes in the fair value and settlements of the Interest Rate Derivatives, including contingency and syndication premiums related to the CCH Interest Rate Derivatives, recorded in derivative gain (loss), net on our Consolidated Statements of Operations during the three and nine months ended September 30, 2015 and 2014:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2015			2014		2015			2014
SPL Interest Rate Derivatives gain (loss)	$	(10,872	)	$	5,379	$	(46,541	)	$	(89,222	)
CCH Interest Rate Derivatives loss	(150,610		)	—		(195,582		)	—

Balance Sheet Presentation

Our Commodity Derivatives and Interest Rate Derivatives are presented on a net basis on our Consolidated Balance Sheets as described above. The following table (in thousands) shows the fair value of our derivatives outstanding on a gross and net basis:

	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 September 30, 2015
Natural Gas Derivatives	$	513		$	(416	)	$	97
Liquefaction Supply Derivatives	33,028			—			33,028
Liquefaction Supply Derivatives	(482		)	—			(482		)
LNG Trading Derivatives	113			—			113
SPL Interest Rate Derivatives	(15,738		)	—			(15,738		)
CCH Interest Rate Derivatives	(143,092		)	—			(143,092		)
As of December 31, 2014
Natural Gas Derivatives	223			(4		)	219
Liquefaction Supply Derivatives	662			—			662
Liquefaction Supply Derivatives	(320		)	—			(320		)
SPL Interest Rate Derivatives	11,158			—			11,158
SPL Interest Rate Derivatives	(23,194		)	—			(23,194		)

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Business Segment Information (Tables)

9 Months Ended

Sep. 30, 2015

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

The following table (in thousands) summarizes revenues (losses), loss from operations and total assets for each of our reporting segments: 

	Segments
	LNG Terminal			LNG & Natural Gas Marketing			Corporate and Other (1)			Total Consolidation
As of or for the Three Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	67,212		$	(1,557	)	$	404		$	66,059
Intersegment revenues (losses) (3)	233			11,354			(11,587		)	—
Depreciation expense	16,775			320			4,543			21,638
Income (loss) from operations	27,072			(27,117		)	(52,029		)	(52,074		)
Interest expense, net of capitalized interest	(67,589		)	(14		)	(25,963		)	(93,566		)
Loss before income taxes and non-controlling interest (4)	(196,693		)	(27,665		)	(82,803		)	(307,161		)
Share-based compensation	1,316			2,051			24,084			27,451
Goodwill	76,819			—			—			76,819
Total assets	16,784,317			552,752			1,115,190			18,452,259
Expenditures for additions to long-lived assets	1,429,808			403			21,258			1,451,469
As of or for the Three Months Ended September 30, 2014
Revenues (losses) from external customers (2)	$	66,983		$	(500	)	$	324		$	66,807
Intersegment revenues (losses) (3)	607			17,262			(17,869		)	—
Depreciation expense	14,817			103			1,269			16,189
Loss from operations	(28,482		)	(6,652		)	(26,030		)	(61,164		)
Interest expense, net of capitalized interest	(46,996		)	—			112			(46,884		)
Loss before income taxes and non-controlling interest (4)	(64,886		)	(7,130		)	(30,813		)	(102,829		)
Share-based compensation	3,278			8,281			13,096			24,655
Goodwill	76,819			—			—			76,819
Total assets	10,847,861			65,536			871,919			11,785,316
Expenditures for additions to long-lived assets	695,159			486			21,895			717,540
For the Nine Months Ended September 30, 2015
Revenues (losses) from external customers (2)	$	203,324		$	(1,601	)	$	730		$	202,453
Intersegment revenues (losses) (3)	827			24,725			(25,552		)	—
Depreciation expense	47,787			764			11,010			59,561
Loss from operations	(15,324		)	(58,667		)	(134,201		)	(208,192		)
Interest expense, net of capitalized interest	(169,899		)	(14		)	(68,751		)	(238,664		)
Loss before income taxes and non-controlling interest (4)	(507,751		)	(59,871		)	(217,014		)	(784,636		)
Share-based compensation	30,233			12,138			71,736			114,107
Expenditures for additions to long-lived assets	5,964,244			2,517			70,913			6,037,674
For the Nine Months Ended September 30, 2014
Revenues from external customers (2)	$	200,243		$	482		$	1,277		$	202,002
Intersegment revenues (losses) (3)	2,113			21,336			(23,449		)	—
Depreciation expense	44,033			364			4,565			48,962
Loss from operations	(56,863		)	(33,153		)	(81,153		)	(171,169		)
Interest expense, net of capitalized interest	(131,264		)	—			321			(130,943		)
Loss before income taxes and non-controlling interest (4)	(376,363		)	(34,046		)	(95,299		)	(505,708		)
Share-based compensation	9,840			17,212			63,920			90,972
Expenditures for additions to long-lived assets	2,164,596			1,271			54,120			2,219,987

(1) Includes corporate activities, business development, oil and gas exploration, development and exploitation, strategic activities and certain intercompany eliminations. These activities have been included in the corporate and other column due to the lack of a material impact that these activities have on our Consolidated Financial Statements.

(2) Substantially all of the LNG terminal revenues relate to regasification capacity reservation fee payments made by Total Gas & Power North America, Inc. and Chevron U.S.A. Inc. LNG and natural gas marketing and trading revenue consists primarily of the domestic marketing of natural gas imported into the Sabine Pass LNG terminal.

(3) Intersegment revenues (losses) related to our LNG and natural gas marketing segment are primarily a result of international revenue allocations using a cost plus transfer pricing methodology. These LNG and natural gas marketing segment intersegment revenues (losses) are eliminated with intersegment revenues (losses) in our Consolidated Statements of Operations.

(4) Items to reconcile loss from operations and loss before income taxes and non-controlling interest include consolidated other income (expense) amounts as presented on our Consolidated Statements of Operations primarily related to our LNG terminal segment.

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Derivative Instruments - Derivative Instruments, Gain (Loss) (Details) - USD ($)		3 Months Ended		9 Months Ended
		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Natural Gas Derivatives [Member] | Marketing and trading revenues (losses) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ (152,000)	$ (525,000)	$ (260,000)	$ (155,000)
Natural Gas Derivatives [Member] | Operating and maintenance expense (income) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		857,000	194,000	1,317,000	(64,000)
Liquefaction Supply Derivatives [Member] | Operating and maintenance expense (income) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	[1]	32,103,000	0	32,184,000	0
Settlements during the period		0	0	0	0
LNG Trading Derivative [Member] | Marketing and trading revenues (losses) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		113,000	0	113,000	0
SPL Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		(10,872,000)	5,379,000	(46,541,000)	(89,222,000)
CCH Interest Rate Derivatives [Member] | Derivative gain (loss), net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ (150,610,000)	$ 0	$ (195,582,000)	$ 0

[1] There were no physical settlements during the reporting period.

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Recent Accounting Standards

9 Months Ended

Sep. 30, 2015

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Recent Accounting Standards

RECENT ACCOUNTING STANDARDS

In May 2014, the Financial Accounting Standards Board (the “FASB”) amended its guidance on revenue recognition. The core principle of this amendment is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Earlier adoption is permitted as of annual reporting periods beginning after December 15, 2016. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.

In August 2014, the FASB issued authoritative guidance that requires an entity’s management to evaluate, for each reporting period, whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued. Additional disclosures are required if management concludes that conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. This guidance is effective for annual reporting periods ending after December 15, 2016, and for annual periods and interim periods thereafter, with earlier adoption permitted. The adoption of this guidance is not expected to have an impact on our Consolidated Financial Statements or related disclosures.

In February 2015, the FASB amended its guidance on consolidation analysis. This amendment primarily affects asset managers and reporting entities involved with limited partnerships or similar entities, but the analysis is relevant in the evaluation of any reporting organization’s requirement to consolidate a legal entity. This guidance changes (1) the identification of variable interests, (2) the variable interest entity characteristics for a limited partnership or similar entity and (3) the primary beneficiary determination. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance may be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.

In April 2015, the FASB issued authoritative guidance that requires debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the debt liability rather than as an asset. In August 2015, the FASB further issued guidance clarifying the SEC staff’s position on presentation and subsequent measurement of debt issuance costs incurred in connection with line of credit arrangements. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance must be adopted retrospectively to each prior reporting period presented and disclosures will be required for a change in accounting principles. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Balance Sheets.

In April 2015, the FASB issued authoritative guidance that clarifies the circumstances under which a cloud computing customer would account for the arrangement as a license of internal-use software. This guidance is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period, with earlier adoption permitted. This guidance may be adopted either retrospectively or prospectively to arrangements entered into, or materially modified, after the effective date. The adoption of this guidance is not expected to have an impact on our Consolidated Financial Statements or related disclosures.

In July 2015, the FASB issued revised guidance related to the measurement of inventory. Inventory would be measured at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. This guidance is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period, with earlier adoption permitted. This guidance should be adopted prospectively. We are currently evaluating the impact of the provisions of this guidance on our Consolidated Financial Statements and related disclosures.